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179-021
mtvErVEDSTATE OF ALASKA ` GE • WE•ALASKA OIL AND GAS CONSERVATION COM ON OMPLETION OR RECOMPLETION REI AND LOG ,MAR 2 4 2018 la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned IZI Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero De AGG +'. tory �I Service Stratigraphic Test t 2. Operator Name: 6. Date Comp.,Sus �rAband) 14.Permit to DrillN mber/Sund BP Exploration(Alaska),Inc 2/24/2018 4 179-021 • 317-547 3. Address: 7. Date Spudded: 15 API Number: P.O.Box 196612 Anchorage,AK 99519-6612 8/8/1979 50-029-20361-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 9/1/1979 PBU 03-10 • Surface: 2134'FSL,638'FWL,Sec.11,T1ON,R15E,UM • 9 Ref Elevations KB 64.00 - 17. Field/Pool(s): Top of Productive Interval: I 3914'FSL,1406'FWL,Sec.11,T1ON,R15E,UM GL 27.00 • BF 27.77 • PRUDHOE BAY,PRUDHOE OIL Total Depth: 3916'FSL,1407'FWL,Sec.11,T1ON,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9275'/8741' ADL 028327 • • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 713875 • y- 5938191 • Zone - ASP 4 ' 978V/9246' • 74-017 TPI: x- 714590 y- 5939992 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 714591 y- 5939995 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No I I 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MDTTVD: 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,calipe/, 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/SP/BHCS/GR,FDC/CNL/CAL/GR,FRT,DM,GR/CCL/CNL,GR/CCL/CBL/VDL/Signature Log,CBL,Temp,Svy 23. CASING,LINER AND CEMENTING RECORD I CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNIf FT. PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 37' 118' 37' 118' 24" 170 sx AS II 13-3/8" 72# L-80 36' 2737' 36' 2737' 17-1/2" 500 sx Fondu,4000 sx AS II 9-5/8" 47# L-80/S-95 34' 9067' 34' 8533' 12-1/4" 800 sx Class'G',300 sx AS II - 4-1/2" 12.6# L-80 9310' 9344' 8776' 8810' 9453' 9531' 8919' 8997' 7" 29# L-80 8745' 9775' 8212' 9241' 8-1/2" 270 sx Class'G' 24. Open to production or injection? Yes 0 No m 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TVSize and Number): - 5-1/2"17#L-80 8854' 8399'/7867' A n't���S x 4-1/2"12.6#L-80 8567/8034' T�pr�w 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes ❑ No L• I-N*14 )1?) Per 20 AAC 25.283(i)(2)attach electronic and printed information k 't i SCANNED CANS JUN 1 L�l U Ma DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED �r9275' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Injection 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(corn): Press 24 Hour Rate �♦ Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only / G fr Nit r'-' : 3 2718 .i,z./9� 28. CORE DATA Conventional Core(s) Yes 0 No IZI • Sidewall Cores Yes 0 No 0 If Yes to either question,list formations and in ervals cored(MD+TVD of top and bottom of each),and summanze lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes 0 No Q Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9185' 8651' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 9185' 8651' CGL-Zone 3 9354' 8820' Base CGL-Zone 2 9452' 8918' Zone 1 9612' 9078' Base of Sadlerochit-Kavik 9660' 9126' Formation at total depth: Kavik 9660' 9126' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Ciolkosz,Ryan R Authorized Title: SIM ist \i0(.... .ate: Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: 3/j / Contact Phone: +1 907 564 5977 INSTRUCTIONS General:This form is designee • ubmitting 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 5/2017 Submit ORIGINAL Only Daily Report of Well Operations 3/10/2018 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL***(ctd) DRIFTED W/20' x 3.70 DUMMY WHIPSTOCK&4-1/2" TEL, LOCATED TT @ 8,809' SLM (+28' correction to elmd) TAGGED @ 9,339' ELMD, SAMPLE OF SCHMOO 2/9/2018 ***WELL LEFT S/I, DSO NOTIFIED*** ***WELL S/I ON ARRIVAL***(ctd) RIGGED UP SWCP 4521 AND STAND BY FOR HIGH WINDS MAKE UP 40 ARM PDS CALIPER 2/10/2018 ***WSR CONTINUED ON 2/11/18*** ***WSR CONTINUED FROM 2/10/18*** (ctd) RAN 40 ARM CALIPER FROM 9310' SLM UP TO 8450' SLM PER PROGRAM 2/11/2018 ***JOB COMPLETE, WELL LEFT S/I*** ***WELL S/I ON ARRIVAL*** (SLB ELINE SET WHIPSTOCK W/GYRO) INITIAL T/I/O = 0/0/0. MIRU, LPT/HPT= PASS. RIH W/GYRO/4.5"X 7" BAKER DELTA WHIPSTOCK. OAL = 64', OAW= 750 LBS, MAX O.D. = 3.635" SET WHIPSTOCK AT 9275' TOWS, 7 DEGREES AZIMUTH (REFERENCE TRUE NORTH). TAG WS, POOH. LOG CORRELATED TO DRESSER ATLAS ACOUSTIC CEMENT BOND LOG DATED 23- JULY-1986 RDMO. WELL LEFT S/I ON DEPARTURE. FINAL TI/I/O = 0/0/0. 2/15/2018 ***JOB COMPLETE 15-FEBRUARY-2018*** T/I/O = ??Nac/0+. Temp = SI. WHPs (Pre Rig). Wellhouse, scaffold & Injection lines removed. OA cemented to surface. Unable to verify SV position due to no scaffolding. 2/20/2018 SV= ?. WV= C. SSV, MV= O. IA, OA= OTG. 16:40 T/I/O=0/0/0 Set 6" CIW"J"TWC#423 through tree. tagged @ 140" using lubricator#68- 839. Removed upper tree, installed CDR Tree#1, installed Kill line#3. Torqued to API specs. PT'd through tree cap jewelry against TWC 300/Iow..5000/high.. 5 min. Pass. see 2/22/2018 "Field Charted Tests" Installed CDR wing platform. FWP's TWC/0/0 see log for details. . • • North America-ALASKA-BP Page 1rY 0,2 oiC Operation Summary Report Common Well Name:03-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/22/2018 End Date:2/28/2018 X3-018R6-C:(1,828,344 00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:8/8/1979 12:00:00AM Rig Release:2/28/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001377 Active datum:KB Q64.00usft(above Mean Sea Level) Date From Hrs Task Code NPT Total Depth Phase ' Description of Operations (hr) (usft) 2/22/2018 15:00 15:30 I 0.50 RIGD P PRE RIG RELEASED,PREP TO MOVE 15:30 - 15:50 0.33 RIGD P PRE PRE JOB SAFETY MEETING WITH CREWAND TRUCK DRIVERS. -EMPHASIS ON GOOD COMMUNICATION, VERIFY STOP COMMAND. -STOP BLOCK IN PLACE TO PREVENT RIG FROM ROLLING BACKWARDS INTO WELL. -VALVES ON TREE SHUT IN AND ALL ANNULUS PRESSURES LESS THAN 50 PSI. -DRILL SITE OPERATOR NOTIFIED AND DECLINED WITNESSING RIG MOVE OFF OF WELL. ANYONE CAN STOP THE JOB AT ANYTIME.BE WATCHFUL 15:50 - 16:20 0.50 RIGU P PRE MOVE PIT SUB AND HOOK UP JEEP 16:20 - 16:40 0.33 RIGU P PRE MOVE MAIN SUB OFF WELL 16:40 - 17:00 0.33 RIGU P PRE INSTALL JEEP ON MAIN SUB 17:00 - 18:00 1.00 RIGU P PRE MOVE RIG TO DS3 18:00 - 20:00 2.00 RIGU P PRE RIG ON DS3 PRE JOB SAFETY MEETING WITH CREW AND TRUCK DRIVERS. --EMPHASIS ON GOOD COMMUNICATION, VERIFY STOP COMMAND. -STOP BLOCK IN PLACE TO PREVENT RIG FROM ROLLING BACKWARDS INTO WELL. -VALVES ON TREE SHUT IN AND ALL ANNULUS PRESSURES LESS THAN 50 PSI. -DRILL SITE OPERATOR NOTIFIED AND DECLINED WITNESSING RIG MOVE OVER WELL. -ANYONE CAN STOP THE JOB AT ANYTIME.BE WATCHFUL -SPOT MAIN&PIT SUBS 20:00 - 21:00 1.00 RIGU P PRE ISUBS SPOTTED,ACCEPT RIG AND START MIRU OPS 21:00 - 21:30 0.50 RIGU P PRE RU TEST HOSE AND LTT MASTER&SWAB 21 30 - 00:00 2.50 RIGU P PRE GOOD LTT,RU MP LINE 2/23/2018 00:00 - 01:30 1.50 RIGU P PRE RU AND NU COMPLETE,FLUID PACK STACK TO TEST BOPE 01 30 - 02:00 0.50 RIGU P PRE REMOVE TREE CAP TO NU BOPE 102:00 - 05:00 3.00 BOPSUR P PRE NU BOPE....CONFIGURATION AS FOLLOWS: F/TOP DOWN. -7 1/16"X 5M ANNULAR PREVENTOR,BLIND/SHEAR RAMS-2 3/8" PIPE/SLIPS,MUD CROSS,2 3/8"X 3 1/2" VARIABLE RAMS-2 3/8"PIPE SLIPS. -PJSM. C/O RISERS,R/U TEST JT AND GREASE VALVES. 05:00 - 05:30 0.50 BOPSUR P PRE SHELL TEST ON STACK,250/3500 PSI, GOOD. -ALL COMPONENTS ON BOPE FUNCTION TESTED WITH REMOTE STATION, GOOD. Printed 3/12/2018 4 01.31PM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 2 oCN Operation Summary Report Common Well Name:03-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/22/2018 End Date:2/28/2018 X3-018R6-C:(1,828,344.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:8/8/1979 12:00:00AM 1Rig Release:2/28/2018 Rig Contractor:NABORSALASKA DRILLING INC. BPUOI:USA00001377 Active datum:KB @64.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT Total Depth I Phase Description of Operations hr (usft) I 05:30 - 12:00 6.50 BOPSUR P PRE COMMENCE BOPE TESTAS PERAOGCCAND BP REQUIREMENTS-H2SAND LEL ALARMS TESTED BY ELECTRICIAN,GOOD. -AOGCC REP JEFF JONES WAIVED WITNESSING- i TEST ALL COMPONENTS @ 250/3500 PSI,5 MIN EACH/CHARTED.-TEST ALL RAMS, ANNULAR PREVENTOR,AND CHOKE VALVES. TEST HCR VALVES.ACCUMULATOR DRAW DOWN TEST. -NO FAILURES,(0)PASS/ FAILS RETEST#2 12:00 - 13:00 1.00 BOPSUR P PRE LID TEST JT&RD TEST EQUIPMENT AND MU INJECTOR'TO WELL 13:00 - 14:40 1.67 BOPSUR P PRE CHECK TREE BOLTS AND TEST C9&C10 FROM REVERSE DIRECTION TREE BOLTS ARE GOOD 14:40 - 15:30 0.83 BOPSUR P PRE CAN'T GET ATEST ON C9&C10 NO VISIBLE LEAKS,'FILL COIL&PURGE ALL SURFACE LINES AND TRY TESTING C9&C10 AGAIN 15:30 - 16:25 0.92 BOPSUR P PRE PT BOTH PUMPS SINCE THEY WERE BOTH REBUILT TEST C9&C10 16:25 - 18:00 1.58 BOPSUR P PRE GOOD TEST,PU THE INJECTOR,INSTALL THE BHI CV'S AND TEST 18:00 - 19:00 1.00 WHSUR P PRE SWAP COIL OVER TO MILLING FLUID -EVACUATE STACK. 19:00 - 22:00 3.00 WHSUR P PRE I PJSM, DISCUSS RIGGING AND MEASUREMENTS FOR PULLING TWC. -INSTALL LUBRICATOR. -INSTALL JUMPER FROM LUBRICATOR TO TV3 1-CIRCULATE METHANOL THROUGH MPD LINE TO TIGER TANK -PERFORM PRESSURE TEST TO 3500#TO LUBRICATOR TEST CRITERIA. -PULL TWC FROM TUBING HANGER. -RD AND OFFLOAD VALVE CREW EQUIPMENT 22:00 - 23:00 1.00 WHSUR P PRE -MAKE UP NOZZLE AND STINGER ASSEMBLY -STAB INJECTOR -TEST LUBRICATOR BREAK TO 3500#. 23:00 - 00:00 1.00 KILLW P PRE PJSM, DISCUSS PRESSURE CROSSCHECK. REVIEWANNULAR MONITORING AND BLEEDING. -BEGIN BULLHEAD DOWN MPD LINE -SPEAR 10 BBLS METHANOL 1 -COME UP TO KILL RATE OF 5.5 BPM @ 640# -CAUGHT FLUID AT 25 BBLS AWAY. -CONTINUE ON TO 02-24-2018 REPORT. 2/24/2018 00:00 - 01:30 1.50 KILLW P PRE BULLHEAD KILL CONTINUED KILL RATE 5.5 BPM @ 825#-910# -290 BBLS 1%KCL -20 BBLS HIVIS PILL -200 BBLS 8.7 PPG QD-N -COME OFFLINE. LET WELL BLEED DOWN. OPEN SWAB. CIRCULATE ACROSS TOP TO TIGER TANK. -PERFORM 30 MIN FLOW CHECK. WELL DEAD. FILL WELL WITH 6.1 BBLS -NOTIFY ODE. Printed 3/12/2018 4:01:31 PM *All depths reported in Drillers Depths* 110 ♦ e3 1 North America-ALASKA-BP • Page eb4a Operation Summary Report Common Well Name:03-10 AFE No Event Type:RE-ENTER-ONSHORE(RON) ' Start Date:2/22/2018 End Date:2/28/2018 X3-018R6-C:(1,828,344.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:CDR-2 Spud Date/Time:8/8/1979 12:00:00AM Rig Release:2/28/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001377 Active datum:KB @64.00usft(above Mean Sea Level) Date 1 From-To Hrs Task 1 Code : NPT I Total Depth Phase I Description of Operations (hr) (usft) 01:30 - 05:00 3.50 STWHIP P WEXIT MAKE UP AND RIH WITH 3.80"DRILLING BHA 1#1 -RATE:0.64 BPM IN,0.76 BPM OUT.CIRC PRESSURE:846 PSI MUD WEIGHT:8.69 PPG IN,8.73 PPG OUT 05:00 - 05:05 0.08 STWHIP P WEXIT LOG TIE IN 05:05 - 05:20 0.25 STWHIP P WEXIT -CORRECT DEPTH 18' RIH DISPLACING HIGH VIS PILL TO EDC 05:20 - 05:35 0.25 STWHIP P ' WEXIT, 11 BBLS OF THE HIGH VIS PILL OUT,CLOSE 'THE CHOKE AND BH 05:35 - 05:50 0.25 STWHIP P WEXIT HIGH VIS PILL OUT,WHP HOLDING STEADY AT 290 PSI',CLOSE EDC AND SLOWLY BLEED OFF WHP 05:50 - 06:00 0.17 STWHIP P WEXIT WT CK=55.1 K,RIH WT=26K,RIH DRY TO TAG _ 06:00 - 06:15 0.25 STWHIP P 9,280.50 WEXIT 1 TAG WS AT 9280.5'WITH 2.8K WOB PU START MILL AND WORK DOWN TILL WE SEE MOTOR WORK _ 1 INITIAL LOSS RAT AT 1 BPM BUT HEALING UP 06:15 - 07:00 0.75 STWHIP P 9,280.20 WEXIT START MILLING WINDOW AS PER PLAN AT 9280.2' 2.77 BPM IN 2.56 BPM OUT SURF WT=26.87K WOB=0.49K _ CIRC PSI=2609 PSI ROP=1.0 FPH 07:00 - 09:35 2.58 STWHIP' P 9,182.20 WEXtT HIGH VIS PILLAT SURFACE BRINGING UP Q-��j ( 109:35 - 11:10 1.58 STWHIP P 9,282.80 WEXIT MILLING WINDOWAS PER PLAN J'�ur/( 2.85 BPM IN 2.71 BPM OUT 03'IiO/icSURF WT=21.41 K WOB=2.32K CIRC PSI=2722 PSI ROP=1.1 FPH 11:10 - 12:35 1.42 STWHIP 'P 9,284.50 WEXIT MILLING WINDOWAS PER PLAN 2.84 BPM IN 2.72 BPM OUT SURF WT=22.58 K WOB=3.39 K CIRC PSI=2797 PSI ROP=1.1 FPH 12:35 - 12:45 0.17 STWHIP P 9,286.10 WEXIT MILLING WINDOWAS PER PLAN 2.83 BPM IN 2.73 BPM OUT I SURFWT=22.18K WOB=2.69K 'CIRC PSI=2851 PSI ROP=1.0 FPH 12:45 - 13:25 0.67 STWHIP P 9,286.20 WEXIT WOB&MOTOR WORK DROPPING OFF, CLOSE TO EXITING THE BOTTOM OF THE WINDOW 13:25 - 13:35 0.17 STWHIP P 9,287.00 WEXIT WINDOW MILL EXITED THE BOTTOM OF THE WINDOW AT 9287.0'(6.8'WINDOW) CONTINUE MILLING AT 1FPH TO DRESS THE BOTTOM OF THE WINDOW WITH THE STRING REAMER , 2.85 BPM IN 2.72 BPM OUT SURFWT=23.39K WOB=.042K CIRC PSI=2658 PSI ROP=1.0 FPH 13:35 - 14:10 0.58 STWHIP P 9,287.30 WEXIT FIELD AT PHASE 2 I WE HAVE 415 BBLS OF MUD ON THE RIG WITH ANOTHER 290 GETTING LOADED, LOSSES AT 9 BPH WHILE MILLING 14:10 - 15:05 i 0.92 STWHIP P 9,288.00 ll WEXIT MILLED 1'WITH STRING MILL,START APPLYING WOB TO MILL RAT HOLE 15:05 - 16:05 1.00 STWHIP P 9,295.00 WEXIT PUMP 10 BBL HIGH VIS PILL Printed 3/12/2018 4:01:31PM *All depths reported in Drillers Depths* Tom= ' CSN NOTES: SWELL READINGS AVERAGE 125 1N�LHEAD FRC • 03-1 0 WHEN ON MI. WELL REQUIRES A SSSV ACTUATOR= BAKER C r A I HEN ON ML OKB.ELEV= 64' Ai !�4 BF.ELEV= 27.77' 9-518"CSG,47#,L-80 H 1390' ,1` !/ 1376' -� B2 9 5!8"FES ES CBv6YT KOP- 4100' HYD 563,D"8.681" 11/ X 111 Mix Angle= 45°@ 5900' 9-5/8"BOWBV EXT J 1390' 1.i �t� 1994' -15-1/2"HES X NP,D=4.562" - .._ - _ - I Datum ND= 9398' // 11 Datum TVD= 8800'SS CSG PATCH � i1� 2338' H9-5/8"UPPER FOC 5-1/2",17#,L-80 HYD 563 XO TO L-80 TCI --j 1964' �• ►Ij • 2465' H9-5/8"LOWER FOC 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2731' 1 8366' H 5-1/7 FES X NP,D=4.562" C ItJ 8387' -9-5/8"X 5-112"BKR S-3 PKR,D=4.750" Minimum ID = 2.635"@ 9529' 3-1/2" OTIS XN NIPPLE 1 8411' -{5-112"HES X NP,D=4.562" 5-1/2"TBG,17#,L-80 TCI, 8494' 1 8473' -5-1/2"HES XN NP,ID=4.455" .0232 bpf,D=4.892" 5-1/2"TBG STUB(03123108) 8493' J 8509' H9-5/8"X 5-1/2"UNIQUE OVERSHOT 8536' H5-1/2"OTIS SBR ASSY,D=4.562" 1MI L 8561' -19-5/8"X 5-1/2"OTIS RH PKR,D=4.734" 5-1/2"TBG-FC,17#,L-80,.0232 bpf,D=4.892" -I 8566' 8566' H5-1/2"X 4-1/2"XO,D=3.958" TOP OF 7"LI'R -I 8745' 8745' -19-5/8"X 7"BOT LNR IiGR,D= i 8804' -14-1/2"OTIS X NP,D=3.813" (4 1/2"TBG,12.6#,L-80 BTC,_0152 bpf,ID=3.958" H 8849' 8849' -14-112"1T WLEG,D=3.958' 9-5/8"CSG,47#,N-80,ID=8.681" H 9067' 8837' H ELND TT LOGGED 09/18/86 9152' H TOP 7"MER JONT 4-1/2"X 7"BKR DELTA WS w/RA TAGS(02/15/18) -! 9276' 9171' BOTTOM 7"MCR JOINT I I 9310' -17"X4-1/2"OTIS WD PKR,D=4.00" ��i 9314' H5-3/4"MLLOUT EXTBJSION(8'),D=4.35" 4-1/2"IFC TBG,12.64f,L-80 BTC, -j 9344' i 9322' -I5-3/4"X 4-1/2"XO,D=3.958" .0152 bpf,13=3.958" _ 9332' H4-1/2"OTIS X NP,D=3.813" TOP OF 4-1/2"TBG -' 9453' I 9332' H4-1/2-PX TOP LOADER PLUG(07/11/14) 9344' -14-1/2"TT WLEG,D=1958' PERFORATION SUMMARY 111 9453' -17'X 4-1/7 OTIS WO PKR,D=4.00" REF LOG:BHCS ON 08/31/79 9457' _H5-3/4"MLLOUT D(TBJSION,ID=4.35" ANGLE AT TOP PERF:2°@ 9213' A H Note:Refer to Production DB for historical pert data 5-3/4"X 4-1/2"XO,D=3.958" SEE SPF NTERVAL Opn/Sqz DATE 9603' ]H4-112"3.7"NO-GO AVA NPw/3.3"BR SLV SEE PAGE 2 FOR PERFORATION DATA 9516' -14-1/2-X 3-1/2"XO,ID=2.97" ii ►C3 9518' -17"X 4-1/2"OTIS WD PKR D=4.00" 1 4-1/2"IPC TBG, 12.6#,L-80,.0152 bpf,D=3.958" -j 9528' ; 9522' 15.78"MLLOUT DCiE7�SION D=4.35" 9526' 1 3.1/2"MULE SHOE,D=2.97" It 9528' H 4-1/2 XO 3-1/2",D=.?„ FWD -1 9732' ' 9629' H 3-1/2"OTIS XN NP,D=2.635" 17"LNR 29#,L-80,.0371 bpf,D=6.184" H 9776' 9531' -I 3-1/2"MULESHOE,D=2.97" 11111111�� TD 9780' 1111111111111111 9639' H UNKNOWN DEBRIS(TAGGED 02121/86) 1.1.1.1.1.1.1.4. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJMD ADDED Ii2S SAFE]Y NOTE WELL: 03-10 07/27/86 WW1 RWO 07/15/14 SWC/JMD FULL DH CJ-EKE/SET PLUG(7/11/14) FERMI No:r1790210 04/04/93 N2BE RWO 01/28/16 MGS/TLH CORRECTIONS(MN ID/AVA NP) API No: 50-029-20361-00 04/05/08 N4ES RWO 11/20/17 JNUJMD ADDED BF EEV SEC 11,T1 ON,R15E,2134'FSL&638'FWL 05/05/09 FR/JMD DRLG DRAFT CORRECTIONS 02/19/18 MS/JM) SET WS w/RA TAGS(02/15/18) 02/11/11 NB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • D= • 03-1 0 ! ACTUATOR= BAKER C 1 i I OKB ELEV= 64' y• BE ELEV= 27.77' A KOP= 4100' 14 • Nix Angle= 45"@ 5900' y X Datum&Et= 9398' H I Datum TV D= 8800'SS 11 ►' ►' ►41 I I X z I I I I 1) 1 f PERFORATION SUN14ARY REF LOG:BIM ON 08/31/79 ANGLE AT TOP PERF:2"@ 9216' Note:Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sgi DATE ' II 3-1/8" 4 9188-9208 S 07/20/86 3-3/8" 4 9216-9236 S 12/01/89 / • 3-3/8" 4 9216-9236 0 06/04/92 A Ilk 3-1/8" 4 9290-9292 S 12/01/89 3-118" 4 9354-9394 S 12/01/86 3-3/8" 1 9406-9425 S 12/01/89 ■ 3-3/8" 2 9406-9440 0 07/06/92 3-3/8" 4 9440-9450 S 12/01/89 1,,,I 3-1/8" 4 9460-9474 S 07/25/86 3-1/8" 4 9500-9512 S 11/24/89 3-3/8" 4 9500-9512 0 07/25/86 1E31 , 3-1/8" 4 9533-9555 S 07/23/86 3-3/8" 4 9533-9555 0 05/03/93 3-1/8" 4 9560-9576 S 07/23/86 3-3/8" 4 9560-9576 S 05/03/93 el i 2K kli illy I 44464464/. �4 4 DATE REV BY COMMENT'S DATE REV BY COMvEJTS PRUDHOE BAY UNTf 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 T IN/JM) ADDED Ii2S SAFETY NOTE WELL: 03-10 07/27/86 WW1 RWO 07/15/14 SWC JJM)PULL DH CHOKE/SET RUG(7/11/14) FERMT No:'1790210 04/04/93 N28E RWO 01/28/16 MGS/TLH CORRECTIONS(MN ID/AVA NIP) AR No: 50-029-20361-00 04/05/08 N4E5 RWO 11/20/17 JNUJM3 ADD®BF REV SEC 11,T1ON,R15E,2134'ESL&638'FWL. 05/05/09 FR/JM3 DRLG DRAFT CORRECTIONS 02/19/18 M3/JM) SET WS w/RA TAGS(02/15/18) 02/11/11 M3/JN13 ADDED SSSV SAFETY NOTE BP Exploration(Alaska) L OF Ty • 4w\�1y/� TSA THE STATE Alaska Oil and Gas • OfLSKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh? Main: 907.279.1433 OF ALAS*I+ Fax: 907.276.7542 • www.aogcc.alaska.gov Uchenna Egbejimba 9n 117, Engineering Team Leader '� ��� �' BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-10 Permit to Drill Number: 179-021 Sundry Number: 317-547 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Commissioner DATED this S day of December, 2017. RSL3 VIS (,i- L 1 1 2017 STATE OF ALASKA �, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS al' lZ ( &' ( 7 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 C,I ( Cgram ❑ Plug for Redrill m • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 179-021 - Exploratory 0 Development 0 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20361-00-00 . 99519-6612 Stratigraphic ❑ Service RV 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No EI PBU 03-10 - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327• PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9780 • 9246 • 9332 8798 2488 9332 9639 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 37-118 37-118 1530 520 Surface 2701 13-3/8" 36-2737 36-2737 4930 2670 Intermediate 9041 9-5/8" 34-9067 34-8533 6870/8150 4760/5080 Liner 34/78 4-1/2" 9310-9344/9453-9531 8776-8810/8919-8997 8430 7500 Liner 1030 7" 8745-9775 8212-9241 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9216-9555 8682-9021 5-1/2"17#x 4-1/2" L-80 32-8854 Packers and SSSV Type: 5-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(ft): 8399/7867 5-1/2"OTIS RH Packer 8567/8034 12.Attachments: Proposal Summary 11 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development 0 Service I11• 14.Estimated Date for Commencing Operations: December 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 1I ' 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 ' Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt,Trevor be deviated from without prior written approval. Contact Email: Trevor.Hyattt bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 4627 Authorized Title: Engineering Team Leader -CTD&RWO Authorized Signature: �. `� • Le • Date: ql 7/ C) I7 ��� �(�`� COMMISSION USE O Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 17 Mechanical Integrity Test 0 Location Clearance 0 3 I1• 5 LI 1 Other: Bop res/ to 3 5 ) 0 p 5 i 7-�1-7,J--)L.J14r pre-V/n -r�/��r1-5 t tD 2��n p s�5. Post Initial Injection MIT Req'd? Yes❑ No L�7 // l i-'t Yh a fC fp 1 vq p I G1,C t l-v"1 r!-7 * Gt p r0 v \ Spacing Exception Required? Yes 0 No Subsequent Form Required: /JD—4,07i P r r a v Ar G 2,5' 112L L/ APPROVED BYTHE Approved by:/!�/ `/ t/A COMMISSIONER COMMISSION Date:)2- 15-I-7 RBDMS t DEC112017 ORiGINAL Submit Form,,,c � and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachmen4 in Duplicate 7%26.(7 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt 0 b CTD Engineer Date: November 16, 2017 Re: 03-10 Sundry Approval Request History of 03-10i: The 03-10i is a central injector in a pattern that has had 3 recent Pattern Rotation wells drilled. This well has had the majority of its injection into the Victor Package(Z4A/Z3/Z2C). The well has an extensive history of wellwork to attempt to isolate injection into Z4B and Z2B, with no success. Due to this, a short replacement sidetrack is / proposed to bring the well into conformance in zones Z4B and Z2B, effectively sweeping to the newly drilled sidetracks which logged up to 40' TVD of oil in Z2B. • o�GU', proved 6.,ahr ce 5l ri r��'ro.e e/2 Proposed plan for 03-10Ai: a4d Ceco✓ac %7,1 attser v4/5 ! f(/* The sidetrack will be drilled with the Nabors CDR2 rig on or around February 15th, 2018.A 4-1/2" x 7"whipstock will be set and cemented pre-rig inside the 7" production liner. The rig will move in, kill the well (if needed) and mill a 3.80"window. The proposed sidetrack is a 1,126' MD U-shaped Zone 26/4B Ivishak injector to be completed with a 3-1/2"x 3-1/4"x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated (post-rig). This Sundry covers plugging the existing 03-10 production via the cemented whipstock set pre-rig,the liner cement iob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin December 1st,2017) 1. E Set Whipstock 2. C Cement Whipstock* 3. V Pre-CTD Tree work. Rig Work(scheduled to begin February 1st,2018) 1. MIRU and test BOPE 250 psi low and 3,500 Qsi high (MASP 2,488 psi). 2. Mill 3.80"Window. 3. Drill build section: 4.25"OH, 448' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, 678' (12 deg DLS planned). 5. Run 3-1/2"x 3-1/4"x 2-7/8" 13Cr liner leaving TOL at 8,460' MD. 6. Pump primary cement job: 31 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200'TVDss. 8. Close in tree, RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. V: Tree work as necessary. 2. D: Liner lap test. 3. C: Perforate—100' MD. 4. S: LTP set post rig if needed, and test* Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 S AVBRA 125 _ D= CAN 03-1 0 SAFETY �NOTES:MIS,. WEREQUIRES A(SSSV ACTUATOR= BAKER C I WHEN ON ML 4 14,4 10 II, BF ESV= -� 9518"CSG,47#,L-80 - 1390' I i A1376' H 9-5/8"FES ES CBS KOP= 4100' HYD 563,1D=8.681" /#/ A Max Angie= 45°@ 5900' 9518"BOWHN OCT H1390' 11 # II 1994' --I5-1/2"HES X NP,ID=4.562" Datum MD= 9398' // 11 Datum TVD= 8$00 SS CSG PATCH 14 '41 2338' H9-5/8"UPPER FOC 5-1/2",17#,L-80 HYD 563 XO TO L-80 TCI H 1964' 1i1 *as 2465' H 9-5/8"LOWER FOC 13-3/8"CSG,72#,L-80 BTC,D=12.347" -I 2731' 8366' H5-1/2"HIS X NP,D=4.562" ►�♦ ►�� 838T H9-5/8"X 5-1/2"BKR S-3 FKR,D=4.750" Minimum ID =2.635"@ 9529' 3-112" OTIS XN NIPPLE 8411' -5-1/2"FES XNIP,D=4.562" I 5-1/2"TBG,17#,L-80 TCI, H 8494' 8473' 8509' H H 5-1/2" 9-518"HES X 5-1/2"XN NPUNQ,13u:4(VERS.455HOT .3:581 HOT bpf,ID=4.892' 5-1/2"TBG STUB(03/23/08) H 8493' 8536' H 5-1/2"OTIS SBR ASSY,D=4.562" 8561' -19-5/8"X 5-1/2'O11S RH PKR,ID=4.734" P.:21 CA 5-1/2"TBG-PC, 17#,L-80,.0232 bpf,D=4.892" --I 8566' 8566' H5-1/2"X 4-1/2"XO,ID=3.958" TOP OF 7"LNR 8745' ® 0 8745' -19.518"X 7"BOT LNR HGR,ID= 8804' H4-1/2"O-ns X NP,D=3.813" 4-1/2"TBG,12.6#,L-80 BTC,.0152 bpf,ID=3.958" -I 8849' 8849' -14-1/2"TT WLEG,D=3.958" 9-5/8"CSG,47#,N-80,D=8.681" -I 9067' 8837' -I ELMID TT LOGGED 09/18/86 9152' -I TOP 7"MrKR JONT 9171' -I BOTTOM 7"NKR JONT I 9310' -17"X 4-1/2"OTIS WD PKR,D=4.00" IF2 ►�� 9314' -15-3/4"MLLOUT EXTENSION(8'),D=4.35" -4-1/2"IPC TBG,12.6#,L-80 BTC, -{ 9344' 1 9322' -I5-3/4"X 4-1/2"XO,D=3.958" .0152 bpf,0=3.958" 9332' -�4-t12"0115 X NP,D=3.813" ` TOP OF 4-1/2"TBG 9453' I 9332'_J-4-1/2"PX TOP LOADER PLUG(07/11/14) 9344' -I4-1/2"TT WLEG,ID=3.958" PERFORATION SUMMIARY 0 0 9453' -I 7"X 4-1/2"OTIS WD FKR,D=4.00" REF LOG:BHCS ON 08/31/79 9457' -15-3/4"MLLOUT EXTENSION,ID=4.35" ANGLE AT TOP PERF:2°@ 9213' ' 9464• -15-3/4"X 4-112"XO,13=3.958" Note:Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 9503' H4-112"3.7"NO-GO AVA NP /3.3"BR SLV SEE PAGE 2 FOR PERFORATION DATA 9516' -14112"X 3-1/2"XO,D=2.97" 0 Cil 9518' -17"x 4-1/2"O11S WD PKR D=4.00" 4-1/2"IPC TBG,12.6#,L-80, .0152 bpf,ID=3.958" -I 9528' ' 9526' -13-1/2"tULLESHOE,D=2.97" D H 9528' - 14-1/2XO3-1/2", ="t` P61139732' 9522' -I 5.78"MLLOUT EXTENSION,ID=4.35" 9529' -�3-1/2'OTIS XN NP,D=2.635" 7"LNR,29#,L-80,.0371 bpf,D=6.184" --I 9775' 9531' -{3-1/7'MULESHOE D=2.97" 1111.1.1 .0411.4* TD 9780' 11 t"A 0,*,4,1 9639' H UNKNOWN DEBRIS(TAGGED 02/21/86) .,.a s aas aaa DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDI-DE BAY UNE 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMN/JMD ADDE?I-12S SAFETY NOTE WELL: 03-10 07/27186 WW1 RWO 07/15/14 SWCIJtID PULL DH CHOKE/SET PLUG(7/11/14) FERIAE No:F1790210 04/04/93 N28E RWO 01/28/16 MGSITLH CORRECTIONS(MN ILYAVA NP) AR No: 50-029-20361-00 04/05/08 N4ES RWO SEC 11,T10N,R15E,2134'FSL&638'FINE 05/05/09 FR/JM) DRLG DRAFT CORRECTIONS 02/11/11 MB/JM) ADDED SSSV SAFE!Y NOTE BP Exploration(Alaska) CP 03-10 Y4ELLFEAD= RNC ''ACTUATOR= BAKER 1 P. I KB.ELE/= 64' 1. BF.ELEV= _? /i KOP= 4100' 111 1 Max Angle= 45'©5900' 111 1x it Datum LD 111= 9398' ' Datum TVD= 8800 SS �1, 11. ►1i I I z Z I I I I r--.. C.i PERFORATION SUMMARY / REF LOG:BI-CS ON 08/31/79 ANGLE AT TOP PERF:2°@ 9216` Note:Refer to Production DB for historical perf data SIZE SFF NTERVAL Opn/Sqz DATE I ' 3-1/8" 4 9188-9208 S 07/20/86 3-3/8" 4 9216-9236 S 12/01/89 / N 3-3/8" 4 9216-9236 0 06/04/92 A 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/86 3-3/8" 1 9406-9425 S 12/01/89 3-3/8" 2 9406-9440 0 07/06/92 3-3/8" 4 9440-9450 S 12/01/89 k7.1 3-1/8" 4 9460-9474 S 07/25/86 3-1/8" 4 9500-9512 S 11/24/89 3-3/8" 4 9500-9512 0 07/25/86 ® ' 3-1/8" 4 9533-9555 S 07/23/86 3-3/8" 4 9533-9555 0 05/03/93 3-1/8" 4 9560-9576 S 07/23/86 3-3/8" 4 9560-9576 S 05/03/93 ell 1 Z ea \y ■ I •111111111111111 1�1e1.1�1e1�1e11 DATE REV BY COWANTS DATE REV BY COM1ILB'TTS PRUDHOE BAY UNIT 09/07179 R35 ORIGINAL COMPLETION 01/10/12_TWWJMD ADDED Ft2S SAFETY NOTE WELL: 03-10 07/27/86 WW1 RVVO 07/15/14 SWC/JMD PULL DH CHOKE/SET PLUG(7/11/14) FE RMT No:'1790210 04/04/93 N28E RVVO 01/28/16 MGS/TLH CORRECTIONS(MN ID'AVA NFP) API No: 50-029-20361-00 04/05/08 N4ES RVVO SEC 11,T1ON,R15E,2134'FSL&638'FWL 05/05/09 FR/JMD DRLG DRAFT CORRECTIONS 02/11/11 F6/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) T1 = PROPOSED - SAFETY NOTES:H2S READINGS AVERAGE 125 waLFAAD= Franc _ ppm WHEN ON MI. WELL REQUIRES A SSSV ACTUATOR= 1 vI EF11 WHEN ON MI. OKB. EV= 64' 4 O BF.BEV ? 9-5/8"CSG,47#,L-80 H 1390' 14•4 '1 1376' -�95/8"HES ES CEWB�tTER KOP= 4100' HYD 563,1D=8.681" /�/ 1�1 Max Angle= _°@ 95/8" JEXT �1 1390' I$1 1v1 1994 ' H5-1/2"HES X NP,ID=4.562" Datum MD= I h 14 Datum TVD= 8800'SS CSG PATCH Iii Zvi 2338' H9-5/8"UPPER FOC 1y. .+v 5-1/2",17#,L-80 HYD 563 XO TO L-80 TCN -1 1964' IA4 1;1 2465' H9-5/8"LOVVE2 FOC 13-3/8"CSG,72#,L-80 BTC,D=12.347" -1 2731' 8366' 5-1/2"HES X NP,ID=4.562" Minimum ID= " '=, 0 8387' H9-5/8"X 5-1/2'BKR S-3 PKR,D=4.750" 8411' H5-112'HES XNP,D=4.562' TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNR H 8460' 8460` 4.375"BKR C2 SLV,D=3.680" 1.1 I H 3.70"DEPLOY MEM SLEEVE,D=3.00" 3-1/2"LNR,_#, ( 8473' -15-1/2"HES XN NP,ID=4.455" . bpf,ID= " I 3-1/2"X 3-1/4"XO,D=2.786"J 5-1/2"TBG,17#,L-80 TCI, - 8494' 0232 bpf,D 4.892" Pj 8509 H9-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG STUB(03/23/08) -1 8493' 8536' H5-1/2"OTIS SBR ASSY,ID=4.562" , 8561' H 9-5/8"X 5-1/2"OTIS RH PKR,D=4.734" 5-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" -1 8666' 8566' -15-1/2"X 4-1/2"XO,ID=3.958" TOP OF 7"LNR -1 8746' . 8746' -19-5/8"X 7"BOT LNR HGR,D='r 8804' H4-1/2"OTIS X NP,ID=3.813" 4-1/2"TBG, 12.6#,L-80 BTC,.0152 bpf,ID=3.958" H 8849' l IL 8849' H4-1/2"TT WLEG,ID=3.958" 8837' -I ELMD TT LOGGED 09/18/86 9-5/8"CSG,47#,N-80,D=8.681" -1 9067' 9152' HTOP 7"NKR Jaw 9171' H BOTTOM 7"MKR JOM 7"X 4-1/2"DELTA WHIPSTOCK(XX/XX/XX) -1 9280" I 7"LNR,291t,L-80,.0371 bpf,D=6.184" H -9280' Ml LOUT WNDOW(03-10A)9280'-__ PERFORATION SUIMV\RY REF LOG: ON XXFXXIXX ANGLE AT TOP PERF:°@' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE _ SQZ 3-1/8" 4 9188-9208 S 07/20/86 3-3/8" 4 9216-9236 S 12/01/89 3-3/8" 4 9216-9236 0 06/04/92 3-1/4"LNR,6.6#,13-CR TC11,.0079 bpf,D=2.85" H PBTD - H3-3/16"X 2-7/8"XO,D=2.377" 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,ID=2.441" -1 10406' -�-� DATE REV BY COMIu6VTS DATE REV BY COMMENTS PRUDHOE BAY UNT 09/07/79 R35 ORIGINAL COMPLETION WELL: 03-10/' 07/27/86 WW1 _RWO I PERMTNo: 04/04/93 N28E _RWO API No: 50-029-20361-ai 04/05/08 N4ES RWO SEC 11,T1 ON,R15E,2134'FSL&638'FWL CTD ST(03-10A) 07/18/17 JMD BUILT PROPOSED BP Exploration(Alaska) Weld, Blank CDR2-AC BOP Schematic Date Quick Test Sub to Otis I -1.1 ft Topof7"Otis 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub Top of Annular I 0.0 ft • ► 7-1ns"5k Flange X T'Otis Box Top Annular Element 0.7 ft u ..rE s Bottom Annular 2.0 ftIMMIN ► ,„ Blind/Shear CL Blind/Shears I 3.3 ft I ► 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft B5 5, B6 ;;�!�� s B7 i B8 Deployment Line "$ -vibe re � - ::= arm s # - .., £5k Mud •. '4* r6 9Y Cross ° �iS*AIL... {88 lM a � nnnn III Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft 2-318"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft ► BI B2 ( Choke Line Kill Line _ 1.— Blind/Shear III - CL Blind/Shears 10.0 ft ► 2-3/8"PipelSlips ii �1 CL 2-3/8"Combi's 10.7 ft ► �� 1 N CL of Top Swab 13.3 ft 114 4---Swab 2 Test Pump Hose 4/Swab 1 CL of Bottom Swab 14.8 ft � � T1 je T2 Pr CL Flow Tee 16.2ft � _ •�• _ - BOP2 CL of SSV 17.5 ft g _ s Master 2 Fusable CL of Master Valve 19.0 ft BOP1 Master 1 LDS 20.5 ft II II II II II Gound Level I, II n n u r. 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 Responsib e 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or / "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then / it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech _ for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. MEMORANDUM • State t of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,January 06,2017 Jim Regg P.I.Supervisor , 1fq 17 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 03-10 FROM: Guy Cook PRUDHOE BAY UNIT 03-10 Petroleum Inspector Src: Inspector Reviewed By:e, P.I.Supry,J 1 - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-10 API Well Number 50-029-20361-00-00 Inspector Name: Guy Cook Permit Number: 179-021-0 Inspection Date: 1/3/2017 Insp Num: mitGDCl70103141650 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well f 03-10 ' Type Inj w TVD 8027 - Tubing 916 921 - 920 - 919 PTD 1790210 " Type Test SPT Test psi 2007 - IA 213 2289 - 2250 , 2245 - Interval 4YRTST P/F P ✓ 1 OA o o - o - o , Notes: SCANNED APR 0 5 201? Friday,January 06,2017 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, April 09, 2016 9:57 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C WL Completions Superintendent; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Pettus, Whitney; Sternicki, Oliver R; Dickerman, Eric; Munk, Corey; Odom, Kristine; Regg, James B (DOA) Subject: NOT OPERABLE:Injector 03-10 (PTD #1790210) Due for AOGCC MIT-IA All, Injector 03-10 (PTD#1790210) is due for an AOGCC MIT-IA at the end of April. However, due to surface constraints,the well will not be placed on injection for before due date. The well is reclassified as Not Operable until ready to be placed on injection and has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus $ � APR 2 12016 (Alternate:Kevin Parks) BP�Allasska-Well Integrity Coordinator JYV 'cftrT'1`, WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 . V OF Tye �w\�����j�,sv THE STATE Alaska Oil and Gas 1 �i Of Conservation Commission -:_l____ - A�LASIc:A ttsttt= 333 West Seventh Avenue k f` -, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907.279.1433 OF ASI`CP' Fax. 907.276 7542 www aogcc.alaska.gov SCONE° Ralph Sinnok I I q.- 0 P-1 Production Engineer 1 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-10 Sundry Number: 315-534 Dear Mr. Sinnok: 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, e'16 Cathy . /)2144-./Foerster Chair RBDMS SEP 0 9 1015 DATED this day of September, 2015 Encl. STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM' ')N APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon Cl 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 Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Patch Across Perfs RI • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 179-021 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0 99519-6612Stratigraphic 0 Service ®. 6. API Number: 50-029-20361-00-00. 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU 03-10 -,` :.t v` 9. Property Designation(Lease Number): 10. Field/Pools: AUG G�' O ADL 0028328 • PRUDHOE BAY,PRUDHOE OIL • l 11. PRESENT WELL CONDITION SUMMARY CIl' � Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junli rflr3asul'e )L 4,J 9780• 9246• 9332 8798 9332 9639 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20"94#H-40 37-118 37-118 1530 520 Surface 2701 13-3/8"72*L-80 36-2737 36-2737 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment , See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment 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 ® Exploratory 0 Stratigraphic 0 Development 0 Service ® • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ❑ WAG ® • Abandoned 0 Commission Representative: Op Shutdown❑ GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sinnok,Ralph Email Ralph.Sinnok@bp.com Printed Name Sinnok,Ralph Title Production Engineer Signature Phone 19075644630 Date DQ/z�)/z s',r COMMISSION USE ONLY (� d v� Conditions of approval:Notify Commission so that a representative may witness Sundry Number. 3\5- 53 `( Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No 1 Subsequent Form Required: /G — 4( APPROVED BYTHE p Approved by:/-'�/� COMMISSIONER COMMISSION Date:9—PJ �l Sr 1,-77L `i ORIGINAL RBDMS'1 SEP 09201' Submit Form and Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. 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Z o ' N N N N N N N N N CV N N Z � Q. 6 W W I-4 In 0 0 0 0 1n O W W ❑ J W ❑ N Cr S.- NNNNNN (N Z a :9 - U WW W 1L W a � COCONNNNNNT- N- N- NNNN- NNN- N- N- s m ❑ 0: ❑ W J_ 3 -I :, W W O0 < < co a CO a s a co a et 0 E co O O O O O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Li- co es c.s ch cvs (h c%) c,s c%) os c7 r) c.s cvs A c� M c� c� cvs c s c; cis m a a a U J a O w a 000000000000000000000 o < < m m 1L E co Cl) a OC Packers and SSV's Attachment ADL0028328 SW Name Type MD TVD Depscription 03-10 PACKER 8398.96 7866.8 5-1/2" Baker S-3 Packer 03-10 PACKER 8426 7893.73 4-1/2" BAKER S-3 PERM PACKER 03-10 PACKER 8523 7990.36 5-1/2" Baker SAB Packer 03-10 PACKER 8560 8027.24 5-1/2"Otis RH Packer 03-10 PACKER 9314.88 8781.2 4-1/2"OTIS WD PACKER 03-10 PACKER 9458.07 8924.39 4-1/2"OTIS WD PACKER 03-10 PACKER 9522.38 8988.7 4-1/2" OTIS WD PACKER ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: 03-10 Well Type: WAG Injection Well API Number: 50-029-20361-00 Well Activity Conventional 4 Classification: Activity Description: Patch Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None. requirements? Sundry Form 10-403 Required? Yes — Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Ralph Sinnok Contact numbers: (907)564-4630 (907)304-252 Well Intervention Engineer: Todd Sidoti Contact numbers: (907)564-5113 (907)632-411 Lead Engineer: Laurie Derrick Contact numbers: (907)564-5952 (720)308-338 Date Created: July 22,2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injectic Date Oil Rate Inj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 7/21/2015 19,587 0 1,766 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A. Recent H2S (date,ppm) 3/31/1992 12 Maximum Deviation(Angle and ppm Depth) 45° 5,900' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 8° 6,200' MD Reservoir pressure(date, 3/8/2000 3,437 psi Minimum ID and Depth 3.813"@ 8,804' MD;4-1/2"OTIS X- psig) NIP. Reservoir Temp,F 157°F Shut-in Wellhead Pressure Vacuum. Known mech.integrity OA cemented to surface in 2003, MIT-IA to 4,000 psi passed on 6/2/15. problems(specifics) Last downhole operation(date, 4/25/2015 EL:WFL&IPROF to check for leaks and channel, results showed none. operation) Most recent TD tag(date,depth, 4/22/2015 9,332' MD SL:3.70"cent.,4-1/2"TEL,and s-bailer;Schmoo toolstring OD) encountered. Surface Kit Fit-for-Service? YES If No,Why? N/A. Comments,well history, 03-10i is currently a Zone 4 PW injector only. A plug was set @ 9,332' MD on 7/11/14 to shut off injection background information, into Zone 3 or theif zone. Based on IPROF splits and historical injection rates,Zone 3 has had sufficient etc: sweep and it cycles water injection with little to no oil benefit. A WFL&IPROF were performed on 4/25/15 to check for potential channeling and/or packer/plug/tubing leaks. The results showed no - channeling or leaks. The long-term plan is to inject only into Zone 4&2 to support the offset producers in the 03-10i pattern. Also,this well has been identified in pattern reviews as a high potential and benefit for injecting MI into this well for EOR in the pattern. Operations is ensuring the MI line for this well is fit for service. The well has passed a MIT-IA to 4,000 psi which passes the BP criteria for having integrity to inject MI. The objective of this procedure is to return the water injector to zonal injection conformance by shutting off • injection into Zone 3 with a patch. Zonal injection conformance will better support the offset producers which do have open perforations in Zone 2 including 03-01A, 03-31A, 09-04A,and soon to be 09-03A(SOR on backlog to shoot Z2). The goal is to support the offset producers in Zone 4&2 for oil sweep. Also, in the future,we plan to inject MI in this well and pattern for additional EOR. - Well Intervention Details Suspected Well Problem: Cycling water injection in Zone 3 with little to no benefit,out of injection conformance for pattern. Specific Intervention or Well Objectives: 1 Pull plug. 2 Obtain caliper and jewelry log. 3 Set nipple reducer. 4 Set Baker snap-latch patch. 5 Obtain SBHPS. Key risks,critical issues: Mitigation plan: 1 Getting stuck due to schmoo. Perform SBG treatment. 2 Dirty OTIS nipple(s). Perform brush. Summary Service Line Activity Step# 1 F SBG treatment. 2 S D&T, pull plug, D&T, caliper/jewelry log,and set nipple reducer. 3 E Set lower packer of patch. 4 S SBHPS and set remaining patch. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): Perform SBG treatment. See attached Fullbore Template and Pumping Template. Plug was set @ 9,332' 1 F MD on 7/11/14. A SBG was performed on 12/26/14. On 4/22/15 SL recovered 1.5 cups of Schmoo. On 4/24/15 EL encountered schmoo during WFL passes. 2 S D&T to ensure ability to get down to plug @ 9,332' MD. 3 Pull plug @ 9,332' MD in 4-1/2"OTIS X-NIP. D&T to deviation to ensure ability to get down to 9,503' MD 4-1/2"AVA BPL XN-NIP. Use a toolstring to 4 emulate EL's packer setting tool. Last tag below 9,332' MD was on 12/26/1993 with SL tagging 9,711' MD. 5 If unable to get down to deviation due to schmoo then have FB perform another SBG treatment to treat lower zones. Caliper/jewelry log from tag to surface. Ensure caliper has GR/CCL. This will ensure EL can set the packer 6 at the correct depth. Tie-in Log: BHCS on 8/31/79. If BHCS log cannot be found then use Atlas CNL on 2/10/80. *All the packers in the 7"were not installed till after the BHCS or Atlas logs so GR will be used primarily. 7 Brush 4-1/2°AVA BPL XN NIP @ 9,503' MD. This ensures the nipple reducer can be set without issues. 8 Set nipple reducer©9,503' MD in 4-1/2'AVA BPL XN-NIP. This will allow us to set a plug in the future after the patch is set if Zone 2 needs to be shutoff. 9 E Set lower packer between 9,457'and 9,503' MD. Set depth will be identified with the SL jewelry log. 10 S Perform SBHPS. See attached SHBP Form. 11 Set remaining patch between 9,332'and 9,314' MD. Set depth will be identified with the SL jewelry log. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 18,000 Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: POI with PW. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= aW W8_LFEAD= 03-10 _ WHEN ON Merit WEELAL READINGS AVERAGE A SS125 V ACTUATOR= BAKER C1 1 r..rEN ON ML � OKE_B.EV= 64' 11j fel BF.ELEV= _? 9-5/8"CSG,47#,L-80 r 1390' T 1 1376' —19-5/8"FES ES CEMENTS KOP= 4100' HYD 563,D=8.681' �*� Datum MD=0443X Angle= 45'ft 5900' 9.518'BOWE N EXT —I 1390' 141 ll r 1994' —+5-1/2'HES X MP D=4.562" 939814 11 Datum TVD= 8800'SS CSG PATCH 1*i ,41 /4. ,. 2338' —I9-5/8"UFFER FOC 5-1/2",17#,L-80 HY D563 XO TO L-80 TCI H 1964' /A/ 1,/ 2465• —I9-5/8"LOWER FOC 13-3/8"CSG,72#,L-80 BTC,D=12.347" —I 2731' , 8366' H 5-11T HES X PP,13=4.562" Minimum ID = .875"@ 9332' g N,7 838T H9-5/8"X 5-1/2"BKR S-3 Rai,0=4.750" CHOKE IN X NIPPLE I 8411' H5-1/2"HES X P,D=4.562" 5-1/2'TBG,17#,L-80 TO, —I 8494' I 8473' H5-1/2*FES XN PP,13=4.455" .0232 bpf,D=4.892" 8509' H 9-5/B"X 5-1/2"UNIQUE OVERSFDT 5-1/2"TBG SIL$(03/23/08) H 8493' �H 5-1/2.OTIS SBR ASSY,D=4.562" 113.51 ' 8561' '---I9-5/8"X 5-1/2"OTIS RH R(R,D=4.734' 15-1/2"TBG-PC,17#,L-80,.0232 bpf,D=4.892" H 8566' I--- 8566' H5-1/2"X 4-1/2"XO,D=3.958" TOP OF 7"LMR H 8745' I--10 8745' H 9-5/8"X 7"BOT LNR NOR,D=? I I 8804' —I4-1/2"OTIS X PP,0=3.813' 4-1/2"TBG,12.6#,L-80 BTC,.0152 bpf,D=3.958' H 8849' \ 8849• —.41/2"TT WL.EG,D=3.958'- 9-5/8"CSG,47#,PF80,D=8.681" —{ 9067' . 8837' H ELMS TT LOGO 09/18/86 9152' HTOP7'M RJOWT 9171' H BOTTOM 7"MQRJOWT 9310' H 7"x 4-1/2"OTtS WD R(R,D=4.00- 14 =' 9314' H 5-314"MLLOUT EXTENSION(8'),D=4.35" 4-1/2"PC TBG,12.61!,L-80 BTC, —I 9344' I/ 9 —I5-314"X 4-1/2"XO,D=3.958" .0152 bpf,0=3.958" ` 9332' u-(4-1/2"OTIS X P1',0=3.813" TOP OF 4-1/2'TBG —I 9453' I 9332" —I4-1/2"PX TOP LOADER PLUG(07/11/14) 9344' H4-1/2"TTWLEG,D=3.958" PERFORATION StI41AARY 1):4 9453' H T x 4-1/2"OTS WD R(R,0=4.00" REF LOG:BI-CS ON 08/31/79 9457' H5-3/4"MLLOUT EX TB4SION,13=4.35" ANGLE AT TOP PEP:2'@ 9213' Note:Refer to Production DB for historical perf data 9464' 5314"X4-1/2"XO,D=3.958" SIZE SPF.1 tNTBRVAL Opn/Sq I GATE 9503' H 4-1/2"AVA BR XN M D=3.70"w/BR SEE PAGE 2 FOR PERFORATION DATA 9516' H 4-1/2"X 3-1/2"XO,D=2.97- -4 •. 97' -4 `W 9518' 7"X 4-1/2"011S 3 PKR 0=4.00" 4-1/2'IPC TBG,126#,L-80,.0152 bpf,D=3.958" --I 9528' , 9522 J-15.78"MLLOUT EXTENSION,D=4.35" 1 - a 9526' H3-1/2"M..LESHOE,D=297' ‘119528' H4-1/2 X0 3.1a,D=?' FBTD —I 9732' ' 9629' H3-1/2"0115 XN NP D=2.635' 7"LNR,29#,L-80,_0371 bpf,D=6.184" —I 9775' •••••••• 9531' H3-1/2"IlttESHOE,D=297' 4444444444444441 1-----6-) 9780' 4444444441+44441 9639' H UNK NO1MN DEBRIS(TAGGED 02/21/86) DATE REV BY COMMENTS j GATE REV BY COMMENTS PRaDHOE BAY INT 09107/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJMD ADD®H2S SAFETY NOTE WB_L: 03-10 07/27/86 WW1 R1NO 07/15/14 SWCIJMD RLL OH CI—OKE/SET PLUG(7/11/14) R3491"No: 1790210 04/04193 N28E MVO AR No: 50-029-20361-00 04/06108 NOES RWO SEC 11,T10N,R15E,2134'FSL 8 638'FWL 05/05/09 FRIJMD DRLG DRAFT CORRECTIONS •02/11/11 M3/J/40 ADDED SSSV SAFETY NOTE ' BP Btploratlon(Alaska) ,D= 03-1 0 ACTUATOR= BAKER C t i f KB.ELEV= 64' /II BF.ELEV= ? I KOP= 4100' A Max Angle= 45"(?5900' AX X Datum MD= 9398' 141 Datum IVD= 8800'SS I. I4i ►4i E II I r ii i: PERFORATION SUMMRY REF LOG:BRCS ON 08131/79 ANGLE AT TOP PERF:2"@ 9216' . Note:Refer to Ptoduction DB for historical perf data SIZE SW INTERNAL Opn/Sqz ATE 3-1/8' 4 9188-9208 S 07/20/86 3-3/8' 4 9216-9236 S 12/01/89 i • 3-3/8' 4 9216-9236 0 06/04/92 A 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/86 3-3/8" 1 9406-9425 S 12/01/89 t 3-3/8' 2 9406-9440 0 07/06/92 3-3/8" 4 9440-9450 S 12/01/89 lil'i 3-1/8" 4 9460-9474 S 07/25/86 3-1/8" 4 9500-9512 S 11/24/89 3-3/8" 4 9500-9512 0 07/25/86 8 1 3-1/8" 4 9533-9555 S 07/23/86 3-3/8" 4 9533-9555 0 05/03/93 3-1/8" 4 9560-9576 S 07/23/86 3-3/8" 4 9560-9576 S 05/03/93 Ci I 14I ►af 111116v I 14144444441414444 1.44161444441411 DATE REV BY COM.6NIS - (ATE REV BY CDMJBNTS PR DHOE BAY INT 08107179 1235 ORIGINAL COMPLETION i 01/10/12 TIMMIAD ADDED H2S SAFETY NOTE WELL- 03-10 0712716 WW1 MVO 07/15/14 SVYC/JWO PUL CH CHOKE/SEI PLUG(7/11/14) FE IAT No: 1790210 04104/3 NNE FANO API No: 50-029-20361-00 04/05/08 NIE5 RWO SEC 11,T1 ON,R15E 2134'FSI&638'FWL 05/05109 FRAC DRLG DRAFT CORFECTONS 1 02/11/11 MBIJM) ADDED SSSV SAFETY NOTE ! 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M �~-+ E cu [C m a a N o o = a N o 0 o N Z v 0 ,.� C 0 J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well H Plug Perforations L Perforate L Other Ld BrightWater 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: Name: BP Exploration (Alaska), Inc Development❑ Stratigraphic❑ ,, Exploratory Service ❑✓ 179-021-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20361-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028328 PBU 03-10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: RECEIVEE Total Depth measured 9780 feet Plugs measured 9332 feet true vertical 9246.32 feet Junk measured 9639 feet AUG 2 7 2014 Effective Depth measured 9332 feet Packer measured See Attachment feet /� w AOGC true vertical 8798.32 feet true vertical See Attachment feet !C Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 94# H-40 36-118 36-118 1530 520 Surface 2701 13-3/8" 72# L-80 30-2731 30-2730.98 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet 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) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9216'-9236', 9406'-9440', 9500'-9512', 9533'-9555' Treatment descriptions including volumes used and final pressure: 3415GALS EC9360A,17000GALS EC9398A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1907 10421 0 0 2335 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorLI Development ❑ Service Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas L WDSP GSTOR ❑ WINJ ❑ WAG E] GINJ ❑ SUSP ❑ SPLUG[] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(d)bp.com Printed Name Nita Summerha s Title Petrotechnical Data Engineer Signa Phone 564-4035 Date 8/27/2014 Form 10-404 Revised 10/2012 RBCMS AUG 2 8 2` - , Submit Original Only Daily Report of Well Operations ADL0028328 ACTIVITYIDATE SUMMARY T/1/0=1400/20/0 Brightwater treatment (RESERVOIR SWEEP MOD) Standing by for 8/3/2014 fluid ***WSR continued from 8-3-14*** Brightwater Treatment (RESERVOIR SWEEP MOD) 8/4/2014 Standing by for fluid. ***WSR continued to 8-5-14*** ***WSR continued from 8-4-14*** Brightwater treatment (RESERVOIR SWEEP MOD) Pumping Brightwater chemicals down TBG while welll is on water injection. Pumped 4794 gallons of EC9398A Polymer Pumped 980 Gallons of EC9360A Surfactant 8/5/2014 ***WSR continued to 8-6-14*** ***WSR continued from 8-5-14*** Brightwater Treatment (RESERVOIR SWEEP MOD) Pumping Brightwater chemicals down TBG while the well is on water injection 11000 BWPD Pumped 6768 gallons EC9398A Polymer. Total of 11652 gallons since the start of this project. Pumped 1344 gallons EC9360A Surfactant. Total of 2324 gallons since the start of this project. 8/6/2014 ***WSR continued to 8-7-14*** continued from 8-6-14*** Brightwater Treatment (RESERVOIR SWEEP MOD) Pumping Brightwater chemicals down TBG while well is on water injection 11000 BWPD. Pumped 1091 gallons EC9360A Surfactant. Total of 3415 gallons since the start of this project. Pumped 5438 gallons EC9398A Polymer. Total of 17000 gallons since the start of this project. Final Valve positions= SV= Closed SSV, MV, WV= Open IA, OA= OTG FWHP= 1500/240/0 8/7/2014 Job Complete GALS 34151EC9360A 17000 EC9398A 20415 TOTAL FLUIDS PUMPED AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028328 MLK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 03-10 12/1/1989 SQZ 9188 9208 8654.33 8674.33 03-10 6/4/1992 APF 9213 9216 8679.33 8682.33 03-10 6/4/1992 RPF 9216 9236 8682.33 8702.32 03-10 2/25/1996 RPF 9240 9249 8706.32 8715.32 03-10 2/25/1996 RPF 9249 9252 8715.32 8718.32 03-10 2/25/1996 RPF 9252 9256 8718.32 8722.32 03-10 2/25/1996 RPF 9256 9266 8722.32 8732.32 03-10 2/25/1996 RPF 9266 9272 8732.32 8738.32 03-10 2/25/1996 RPF 9272 9290 8738.32 8756.32 03-10 12/1/1989 SQZ 9290 9292 8756.32 8758.32 03-10 7/11/2014 BPS 9354 9369 8820.32 8835.32 03-10 7/11/2014 BPS 9370.5 9371.5 8836.82 8837.82 03-10 7/11/2014 BPS 9377.5 9378.5 8843.82 8844.82 03-10 7/11/2014 BPS 9386.5 9387.5 8852.82 8853.82 03-10 7/11/2014 BPS 9393.5 9394.5 8859.82 8860.82 03-10 7/11/2014 BPS 9406 9425 8872.32 8891.32 03-10 7/11/2014 BPS 9425 9440 8891.32 8906.32 03-10 7/11/2014 BPS 9440 9450 8906.32 8916.32 03-10 7/11/2014 BPS 9460 9474 8926.32 8940.32 03-10 7/11/2014 BPS 9500 9512 8966.32 8978.32 03-10 7/11/2014 BPS 9533 9555 8999.32 9021.32 03-10 1 7/11/2014 BPS 9560 9576 9026.32 9042.32 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADLOO28328 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 94# H-40 36 - 118 36 - 118 1530 520 INTERMEDIAT 1364 9-5/8" 47# L-80 27 - 1391 27 - 1391 6870 4760 INTERMEDIAT 1808 9-5/8" 47# SOO-95 1390 - 3198 1390 - 3197.93 8150 5080 INTERMEDIAT 5860 9-5/8" 47# N-80 3198 - 9058 3197.93 - 8524.39 6870 4760 LINER 991 7" 29# L-80 8745 - 9736 8211.73 - 9202.32 8160 7020 LINER 34 4-1/2" 12.6# L-80 9309 - 9343 8775.32 - 8809.32 8430 7500 LINER 73 4-1/2" 12.6# L-80 9452 - 9525 8918.32 - 8991.32 8430 7500 LINER 13 4-1/2" 12.6# L-80 9517 - 9530 8983.32 - 8996.32 8430 7500 SURFACE 2701 13-3/8" 72# L-80 30 - 2731 30 - 2730.98 4930 2670 TUBING 8490 5-1/2" 17# L-80 26 - 8516 26 - 7983.39 7740 6280 TUBING 62 5-1/2" 17# L-80 8498 - 8560 7965.46 - 8027.24 7740 6280 TUBING 288 4-1/2" 12.6# L-80 8560 - 8848 8027.24 - 8314.58 8430 7500 Packers and SSV's Attachment ADL0028328 SW Name Type MD TVD Depscription 03-10 PACKER 8393 7860.86 5-1/2" Baker S-3 Packer 03-10 PACKER 8560 8027.24 5-1/2" Otis RH Packer 03-10 PACKER 9309 8775.32 4-1/2" OTIS WD PACKER 03-10 PACKER 9452 8918.32 4-1/2" OTIS WD PACKER 03-10 PACKER 9517 8983.32 4-1/2" OTIS WD PACKER awSAFETY 9327 NOTES: 1-12S READINGS AVERAGE 125 YWB-LFEAD = FMC a-1/2" OTIS x NP, D = 3.813" 03-10 ppm WHEN ON MI. WELL REQUIRES A SSS V Acn ATOR = BAKER C 9344' WHEN ON U OKB. B.EV 64 7" x 4-112" OTIS WD FKEZ D = 4.00" 9457 BE BEV = _? 9-5/8- CSG, 47#, L-80 1390' 1376' 9 5/8" tES ES C�tTi� KOP = 4100' HY D 563, D = 8.681" 4-1/2" AVA BR- XN NI, D = 3.70" w / BR ngl 45' @ 1390' 1994' S 112" HE5 X NP, ID = 4.562" DatumKbx - 9398' �9-518"BOV1016F] 5.78" MLLOUT BCTENSKA D = 4.35" 9526' Datum TVD= 8800' SS CSG PATCH 9528' 2338' 9-518" UPFE2 FOC 15-1/2',17#, L-80 HY D 563 XO TO L-80 TCI 1964' 2465' 9 518" LOWER FOC 13-3/8" CSG, 72#, L-80 BTC, D = 12.347" 2731' UNKNOWN DEBRIS (TAGGED 02/21186) 8387 9-5/8" X 5-1/2"BKR S-3 PKR, D =4.750- Minimum ID = .875" @ 933 2' CHOKE IN X NIPPLE 8411' s1/rHfxNP,D=4.ssr 5-1/2" TBG, 17#, L-80 TC1, $494' 8473' S 1/2" HES XN NP. D= 4.455" .0232 bpf, D = 4.89r 8509' � 5!8" x 5- yr uNouE ov E3zsHOT 15-1/2- TBG STUB (03/23/08 8493' Ql 8536' 5-1/2" OTIS SBR ASSY, D = 4.562- 5-1/2* TBG -PC, 17#, L-80, .0232 bpf, D = 4.892" 8566' TOP OF 7" LNR 874V 1 4-1/2" TBG, 12.6#, L-80 BTC, .0152 bpf, D= 3.958" 8849' 9-5/8" CSG, 47#, N-80, D = 8.681' --r 9W -r 4-1 rr EPC TBG, 12.6#, L-80 BTC, 9344' 0152 bpf, D = 3.958" TOPOF 4-1r2" TBG PERFORATION SUMMARY REF LOG: BHCS ON 08/31(79 ANGLE AT TOP PERF: 2' @ 9213' Note: Refer to Production DB for historical pert data SIZE SPF I INTERVAL I Opn/Sgz I DATE SE PAGE 2 FOR FEM�ORATION DATA 1 4 -1/2 - IPC TBG, 12.6#, L-80, .0152 bpf, D = 3.958" J—{ 9528' PBTD 9732' 7" LNR, 29#, L-80..0371 bpi, ID = 6.184' 9775- 97W 8561' —j9-5/8" X 5-1/2- OTIS RH PCR, D = 4.734" 8745' 9-518' X T BOT LNR HGR D ='? 8804' 4-1/2- OTIS X NP, D = 3.813" 4-1/2" TT WLEG, D = 3.958" 8837' E3.W0 TT LOGGED 09/18/86 9152' TOP 7" MKR JC)#JT 9171' BOTTOM 7" MKRJONT' 9310' 7" X 4-1/2" OTIS WD PKR, D = 4.00• 9314' 5-314' MLLCWT EXTENSION (8'), D = 4.35' 9327 5-314" X4-1/2" XO, D = 3.958" 9332' a-1/2" OTIS x NP, D = 3.813" 9332' 4-1/2" PX TOP LOADER PLUG (07/11/14) 9344' 4-112- TT WLEG, D 9453' 7" x 4-112" OTIS WD FKEZ D = 4.00" 9457 5-3/4" MLLOUT DCTEJSDN, D = 4.35" 05/05/091 FR/JMD I DRLG DRAFT CORRECTIONS 9503' 4-1/2" AVA BR- XN NI, D = 3.70" w / BR 9518' 7" x 4-1/2" OTIS WD PKR D = 4.00" 9522' 5.78" MLLOUT BCTENSKA D = 4.35" 9526' 3112" MLLE SHOE, D = 2.97" 9528' 4-1/2 XO 3112", D = a" 9529' 3-1/2" OTIS XN NP, D= 2.635" 9531' 3112- MULESHOE, D = 2.97" 9639' UNKNOWN DEBRIS (TAGGED 02/21186) PRUDHOE BAY LUT WELL: 0310 PERMrT No: 1790210 API No: 50-029-20361-00 SEC 11, T1 OR RI5F-2134' FSL & 638' FVVL DATE REV BY COR&UNITS DATE I REV BY COWAENTS 09/07t79 R35 ORIGINAL COMPLErION 01/10/12 TMWJMD ADDED H2S SAFETY NOTE 07/27/86 WWI RWO 07/15114 SWCJJMD FULL DH CHOKE/SET PLUG (7/11/14) 04/04193 N28E IWWO 04/05108 N4PS RINO 05/05/091 FR/JMD I DRLG DRAFT CORRECTIONS BP Exploration (Alaska) F0-2/1 1/111 MBIJMD I ADDED SSSV SAFETY NOTE XV A WELLHEAD = FMC ACTUATOR = BAKER C I03. ELEV = 64' BF. ELEV = 4 KOP = 4100' 1v4x Angle = 45' @ 5900' Datum MD = 9398' Datum TVD = 8800' SS PERFORATION SUIMMRY REF LOG: BRCS ON 08/31/79 ANGLE AT TOP PEW: 2' @ 9216' Note: Refer to Production DB for historical pert data SIE SPF INTERVAL Opn/Sgz DATE 3-1/8" 4 9188-9208 S 07/20/86 3-318" 4 9216-9236 S 12/01/89 3-318" 4 9216-9236 O 06/04/92 3-1/8" 4 9290-9292 S 12/01/89 3 -Mr 4 9354-9394 S 12/01/86 3-318" 1 9406-9425 S 12/01/89 3-318" 2 9406-9440 O 07/06/92 3318' 4 9440-9450 S 12/01/89 31/8" 4 9460- 9474 S 07/25/86 31/8" 4 9500-9512 S 11/24/89 3318" 4 9500-9512 O 07/25/86 31/8" 4 9533-9555 S 07/23186 3318" 4 9533-9555 O 05/03/93 31/8" 4 9560- 9576 S 07/23/86 33/8" 4 9560- 9576 S 05/03193 03-10 PRUDHOE BAY UVT WELL: 0310 PERW No: 1790210 API No: 50-029-20361-00 SEC 11, T1 OR R1 5E, 2134' FSL & 638' FWL DATE REV BY COMA NTS DATE REV BY COMAENTS 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJM3 ADDED H2S SAFETY NOTE 07/27/86 WWI RWO 07/15114 SVYCJJMD PULL DH CHOKFJSET PLUG (7/11/14) 04/04/93 N28E RWO 04/05/08 MEM WO 05/05/09 FR/JM? I DRLG DRAFT 6CT10NS BP Exploration (Alaska) 102/11/111 M QMD JADDEDSSSV SAFETY NOTE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED AUG 0 7 2014 1. Operations Abandon.—] Repair Weil__ 1 Plug Perforations L�j Perforate E Othe ._ Performed: Alter Casing ❑ Pull Tubing'] Stimulate - Frac ❑ Waiver [ Time Extension❑ % Change Approved Program ❑ Operat. Shutdovrr❑ Stimulate - Other ❑ Re-enter Suspended We❑ 2. Operator 4 Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmen❑ Stratigraphi❑ Exploratory I_ Service[ 179-021-0 3. Address: P.O. Box 196612 6 API Number. Anchorage, AK 99519-6612 50-029-20361-00-00 7. Property Designation (Lease Number): 8 Well Name and Number: ADL0028328 PBU 03-10 9 Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s). PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9780 feet Plugs measured 9332 feet true vertical 9246.32 feet Junk measured 9639 feet Effective Depth measured 9332 feet Packer measured See Attachment feet true vertical 8798.32 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 94# H-40 36-118 36-118 1530 520 Surface 2701 13-3/8" 72# L-80 30-2731 30-2730.98 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet 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) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final ScpHNLD n r � 2014 pressure: 13, Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 11707 0 1407 Subsequent to operation: 0 0 1051 0 941 14 Attachments: 15. Well Class after work Copies of Logs and Surveys Run Exploratcr❑ Development❑ Service[ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work: Oil ❑ Gas ❑ WDSP❑ GSTOR [ WINJ J WAG ❑ GINJ ❑ SUSP ❑ SPLU(F] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt: 314-258 Contact Garry Catron Email Garry.Catron(cD_BP.Com Printed Name Garry Catron Title PDC PE 41;Q Signature ��—� Phone 564-4424 Phone Date 8/5/2014 V L,, 1"'/ RBCMS AUG - 8 20q; Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028328 SW Name Type MD TVD Depscription 03-10 PACKER 8393 7860.86 5-1/2" Baker S-3 Packer 03-10 PACKER 8560 8027.24 5-1/2" Otis RH Packer 03-10 PACKER 9309 8775.32 4-1/2" OTIS WD PACKER 03-10 PACKER 9452 8918.32 4-1/2" OTIS WD PACKER 03-10 PACKER 9517 8983.32 4-1/2" OTIS WD PACKER Casing / Tubing Attachment ADL0028328 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 94# H-40 36 - 118 36 - 118 1530 520 INTERMEDIATE 1364 9-5/8" 47# L-80 27 - 1391 27 - 1391 6870 4760 INTERMEDIATE 1808 9-5/8" 47# SOO-95 1390 - 3198 1390 - 3197.93 8150 5080 INTERMEDIATE 5860 9-5/8" 47# N-80 3198 - 9058 3197.93 - 8524.39 6870 4760 LINER 991 7" 29# L-80 8745 - 9736 8211.73 - 9202.32 8160 7020 LINER 34 4-1/2" 12.6# L-80 9309 - 9343 8775.32 - 8809.32 8430 7500 LINER 73 4-1/2" 12.6# L-80 9452 - 9525 8918.32 - 8991.32 8430 7500 LINER 13 4-1/2" 12.6# L-80 9517 - 9530 8983.32 - 8996.32 8430 7500 SURFACE 2701 13-3/8" 72# L-80 30 - 2731 30 - 2730.98 4930 2670 TUBING 8489 5-1/2" 17# L-80 26 - 8515 26 - 7982.39 7740 6280 TUBING 62 5-1/2" 17# L-80 8498 - 8560 7965.46 - 8027.24 7740 6280 TUBING 288 4-1/2" 12.6# L-80 8560 - 8848 8027.24 - 8314.58 8430 7500 AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028328 MILK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 03-10 12/1/1989 SQZ 9188 9208 8654.33 8674.33 03-10 6/4/1992 APF 9213 9216 8679.33 8682.33 03-10 6/4/1992 RPF 9216 9236 8682.33 8702.32 03-10 2/25/1996 RPF 9240 9249 8706.32 8715.32 03-10 2/25/1996 RPF 9249 9252 8715.32 8718.32 03-10 2/25/1996 RPF 9252 9256 8718.32 8722.32 03-10 2/25/1996 RPF 9256 9266 8722.32 8732.32 03-10 2/25/1996 RPF 9266 9272 8732.32 8738.32 03-10 2/25/1996 RPF 9272 9290 8738.32 8756.32 03-10 12/1/1989 SQZ 9290 9292 8756.32 8758.32 03-10 7/11/2014 BPS 9354 9369 8820.32 8835.32 03-10 7/11/2014 BPS 9370.5 9371.5 8836.82 8837.82 03-10 7/11/2014 BPS 9377.5 9378.5 8843.82 8844.82 03-10 7/11/2014 BPS 9386.5 9387.5 8852.82 8853.82 03-10 7/11/2014 BPS 9393.5 9394.5 8859.82 8860.82 03-10 7/11/2014 BPS 9406 9425 8872.32 8891.32 03-10 7/11/2014 BPS 9425 9440 8891.32 8906.32 03-10 7/11/2014 BPS 9440 9450 8906.32 8916.32 03-10 7/11/2014 BPS 9460 9474 8926.32 8940.32 03-10 7/11/2014 BPS 9500 9512 8966.32 8978.32 03-10 7/11/2014 BPS 9533 9555 8999.32 9021.32 03-10 7/11/2014 BPS 9560 9576 1 9026.32 9042.32 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MILK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Daily Report of Well Operations ADL0028328 ACTIVITYDATE SUMMARY ***WSR CONT FROM 7/10/14***(profile mod) RUN 2.86" CENT, 10 X 2.25" PUMP BAILER W/ MSFB TO 275' SLM RECOVERED 1/4 GALLON OF HARD SCHMOO BRUSHED TBG W/ 5-1/2" BRUSH & 4.40" G. RING TO 8,970' SLM (8,566' MD) (no obstructions) RUN KJ, 2'x 1-7/8" 4-1/2" BRUSH, 3.805" G. RING TO 9305' SLM/ 9332' MD PULL 4-1/2" D/H CHOKE @ 9305' SLM/ 9332' MD SET 4-1/2" PX TOP LOADER W/ (1" eq ports X4, v-packing X2 sets inside,oal = 26",secondary lockdown pin) RUN 4-1/2" CHECK SET, S/D @ 9305' SLM/ 9332' MD(sheared) SET, TOP LOADER PRONG @ 9303' SLM (top of prong) , ( 2.31" f/n, 72.25" oal w/ 3.74" no-go @ 23.50" from bottom of prong max od above no-go = 2.75" max od below no-go = 2.55") 7/11/2014 ***WSR CONT ON 7/12/14*** T/1/0=400/0/0; Install 6-3/8" CIW FLS HWO Temp valve #55 as 2nd SV for S/L; Torque and test to 7/11/2014 300 and 5000 psi. Passed; Final T/1/0=400/0/0; ***SEE LOG*** T/I/0 248/-20/-2 Assist Slickline (Brush and Flush). Pumped 5 bbls MEOH followed by 270 bbls 180* diesel while SLB brushes. FWHP's=1444/-12/-2 DSO notified upon departure SLB on well & in 7/11/2014 control of all WHV's ***WSR CONT FROM 7/11/14***(profile mod) R/D SWCP 4519 7/12/2014 ***WELL LEFT S/I ON DEPARTURE DSO NOTIFIED OF STATUS*** T/1/0=6/0/4. Temp = SI. TBG FL. (APE request). TBG FL @ Surface. Integral flange installed on IA casing valve =inspection not current. Job Complete. 7/21/2014 SV, WV & SSV = C. MV = O. IA & OA = OTG. NOVP. 08:35. T/I/O = Vac/0/0. Temp = SI. Tbg FL (APE Request). Well has 2 SW's putting tree cap valve up on roof of well house. Unable to get T FL (Tbg on vac, had no where to get pressure for Echo meter). 7/28/2014 SW, WV, SSV = C. SW, MV = O. IA, OA = OTG. 04:00. T/I/O = vac/vac/3. Temp = SI. TBG FL (APE request). TBG FL @ near surface (-35'). 7/29/2014 SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. 1715 hrs. T/I/O = 0/0/0. N/D temp SV #55 & SV. N/U new 6-3/8" x 7-1/16" CIW SV. Torque & test. See log 7/31/2014 for details. ***Job complete*** FWHP's = 0/0/0. TREE = CNV WELLHEAD =-- FMC A(;TUATOR= BAKERC OKB. ELEV = 64' 8F. ELFV = - o KOP = 4100' Mix Angie = 45° @5900 Dstwn K) = 93W Datum TVD = 8800' SS 9-5/8" CSG, 47#, L-80 FiY D 563, D = 8.681' 9-5/8" BOWEN EXT CSG PATCH 5.1/2". 17#. L-80 HY D 563 XO TO L-80 TCI 13-3/8" CSG, 72#, L-80 BTC, D = 12.347- 1 1390' 1 1 1390' 1 1964' 2731' Minimum ID = .875" @ 9332' CHOKE IN X NIPPLE 5-1/2" TBG, 17#, L-80 TCI, -L .0232 bpf, D = 4.892" 5-1/2" TBG STUB (03/23/08) 1 5-1/2" TBG -PC, 17#, L-80, .0232 bpi, D = 4.892" I TOP OF 7' LNR 4-1/2" TBG, 12.6#, L-80 BTC, .0152 bpf, D = 3.958- 9- 5/8' .958"9-5/8' CSG, 47#, N-80, D = 8.681' 4-1/2' IPC TBG, 12.6#, L-80 BTC, 0152 bpf, D = 3.958" TOP OF 4-1/2" TBG 03-10 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ML 1376' 95/8' HES ES C9�TT 1994' -j 5-1 /2' HES X NP, ID = 4.562" 2338' 9-5/8" UPPER FOC 2465' 9-5/8" LOWER FOC S-1/2" FES X NP, D = 4.562" 838T 9-5/8" X 5-1/2"BKR S-3 WP, D = 4.750" 8411 •5-1/2" FES X NP, D = 4.562" 8473• -15-1/2" IES XN NP, D = 4.455" 8493• WQ 8509' 9-5/8" X5-1/2" UIJEOVERSHOT 8536' 5-1/2OTIS SBR ASSY, D = 4.562" 8566' 8� 74V 1 8849' 1 1 9067' 1 1 9344' 1 PERFORATION SUMMARY REF LOG: BFCS ON 08/31/79 ANGLE AT TOP PERF 2- @ 9213' Note. Refer to Production DB for historical pert data SIZE SPF I INTERVAL jOpn/Sqzj DATE SEE PAGE 2 FOR PERFORATION DATA 1 4-112" IPC TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 1-j 9528' ISTD 9732' 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 9775' 0 9780' 8561' -19-5/8' X 5-1/2" OTIS RH PKR D = 4.734" 8745' 9-5/8' X T BOT LNR HGP, D = 8804' 4-1/2' OTIS X NP, D = 3.813' 4-1/2" TT WLEG, D= 3.958" 883T ELIrD TT LOGGED 09/18/86 9152' TOP 7" MKR JOw•IT 9171' BOTTOM 7" MKR DONT 9310' 7' X 4-1/2" OTIS WD PKP, D = 4.00' 9314' 5-314" MLLOUT EXTENSION (8'), D = 4.35" 9322• 5-314' X4-1/2" XO, D= 3.958' 9332' a -t /z" OTiS X NP, D = 3.813" 9332• 4-1/2" PX TOP LOADER PLUG (07/11/14) 9344' 4-1/2" TT WLEG, D = 3.958" 9453' 7" X 4-1/2" OTIS WD PKP, D = 4.00" 945T 5-3/4" MLLOUT EXTENSION, D = 4.35" 04/05/08 N4ES RWO 9503' 4-1/2" AVA BFL XN NP, D = 3.70" w / BPI 9516' 4-1/2" X 3112" XO, D = 2.97" 9518' 7' X 4-1/2" OTIS WD PKR D = 400" 9522' 5.78" MLLOUT E>crENSK)K D = 4.35' 9526' 3-1/z" MULE SFDE, D = 2.97" 9528' 4-1/z xo 3-1rr, D= � 9529' 3-1/2' OTIS XN NP, D = 2.635' 9531' 3-1/2" MULESHO� D = 2.97" 9639' UNKNOWN DEBRIS (TAGGED 02/21/86) PRUDHOE BAY UTAT WELL, 03-10 PERMIT No 1790210 AR No 50-029-20361-00 SEC 11, T1 OR R1 5E. 2134' FSL 8 638' FWL DATE REV BY COMMENTS DATE REV BY CDA&E TS 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJMD ADDED H2S SAFETY NOTE 07127186 WW1 RWO 07/15114 SWC/JPULL DH CFDKOSET RUG (7/11/14) 04/04/93 N28E RINO 04/05/08 N4ES RWO 05/05109 I FR/JMD I DRLG DRAFT CORRECTIONS BP Exploration (Alaska) Oil 1/111 MEVJMD JADDE3DSSSV SAFETY NOTE TRS _ CIw ,WELLHEAD = FMC ACTUATOR = BAKER C KB ELEV = 64' BF ELEV = _? KOP = 4100' Max Angle = 45° @ 5900' Datum MD = 9398' Datum TVD = 8800' SS PERFORATION SLPAWRY REF LOG: BRCS ON 08/31/79 A NGLE AT TOP PERF2" @ 9216' Note: Refer to Production DB for historical pert data SQE SPF MTERVAL Opn/Sqz DATE 3-1/8" 4 9188-9208 S 07/20/86 3-318" 4 9216-9236 S 12/01/89 3-3/8" 4 9216-9236 O 06/04/92 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/86 3.318" 1 9406- 9425 S 12/01/89 3-318" 2 9406 -9440 O 07/06/92 3-318" 4 9440-9450 S 12/01/89 3-1/8" 4 9460 -9474 S 07/25/86 3-1/8" 4 9500-9512 S 11/24/89 3-318" 4 9500-9512 O 07/25/86 3-1/8" 4 9533-9555 S 07/23/86 3-318" 4 9533- 9555 O 05/03/93 3-1/8" 4 9560- 9576 S 07/23/86 3-3/8" 4 9560- 9576 S 05/03193 03-10 PRUDHOE BAY UNT WELL. 03-10 PERMIT No. 1790210 API No: 50-029-20361-00 SEC 11, T1 OR R15E� 2134' FSL & 638' FWL DATE REV BY COMMENTS DATE REV BY COMuENTS 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJMD ADDED H2S SAFETY NOTE 07/27186 WW1 RWO 07/15/14 SWC/JlVD PULL DH CFiOKE/SET PLUG (7/11/14) 04/04/93 N28E RWO 04105/08 MES RINO 105/05/091 FR/JMD I DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 02/11/11 M /JMD JADDED SSSV SAFETY NOTE • • ®F Ths X7.177,. kV ,THE STATE o' 4_, �'` oda �� �� pr�j T z•�,,,, ,, r -r ,zr of�1 , I Itr#t# 333 West Seventh Avenue ••Itel �'ie GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 4'4, 1,P*_ ,.$',7 v$ Main 907 279 1433 ®� Ate ,,x. 907.276./-2-.2 SCANNED AUG 0 8 2014 Higino Dos Santos Petroleum Engineer � BP Exploration (Alaska), Inc. 1. P.O. Box 196612 I Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-10 Sundry Number: 314-258 Dear Mr. Santos: 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, b &fl'(' — Cathy P oerster Chair DATED this 2- day of April, 2014. Encl. • IAE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ^P R 2 1 `,'/Y14 - APPLICATION FOR SUNDRY APPROVALS 4___(//''�z�li � 20 AAC 25.280 AV GGC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑• Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: P'-‘5 fi 7c" oct 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. VL/-'' BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 179-021-0 ' f/J2 /14- 3.Address: Stratigraphic ❑ Service Q• 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20361-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 03-10 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028328' PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9780 • 9246 • 9732 9198 None 9639 Casing Length Size MD ND Burst Collapse Structural Conductor 82 20"94#H-40 36-118 36-118 Surface 2701 13-3/8"72#L-80 30-2731 30-2730.98 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service [- 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 'WINJ ❑ GINJ ❑ WAG Q• Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoin a is true and correct to the best of my knowledge. Contact Higino Dos Santos Email Higino.Dos Santos@BP.Com Printed Name Higino Dos Santos Title Petroleum Engineer Signature _ A Phone 564-4342 Date Prepared by Garry Catron 564-4424 .rte" `t-\l- "{ / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 'S' ii— 2-5 25 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ _�^p Other: RBDMS� MAY U 8 2014 Spacing Exception Required? Yes ❑ No El Subsequent Form Required: le -4-04 ' � � APPROVED BY Approved by: , / COMMISSIONER THE COMMISSION Date:¢-2_4L-/ Form 10-403 RevisedG 10/2012 4/7z/it p r i 16 Ii�AIL 12 months from the date of approval. SSuu mit Form and Attachments in Duplicate /d 4- v ') `` Ofi/'T/!f'' ,/s'_, ‘7.472../5/ • I') O O O Cr) 0 0 0 0 0 0 0 (131" CO CO Q 00 CO CO CO CO CO CO Ur Z J Z 0 J J J C') a) Q O 0 0 00 0 0 0 0 0 0 • (N O O CO N 0 0 0 I` co co I— N- O LC) LC) LC) (fl N N pLn I` I` N- I` N O (fl U • O O O O O O O O O O O CO N- N- LC) co co M M () 7 Ln CO CO r V V O I,- N- CO m r CO CO CO CO CO CO CO 't N- N- a) Ln (0 r st co N CA CO 1- '- N CO a7 N 0) O O 0) O) co Co N CO LC) N CO O) 0) I,- 0) O > 1- CO CO 0) CO CO CO N N- CO H 0 CO0 O N LC) CO CO LO ~ CO N- 0) 0) '- I,- CO a- O CO CO p CM N CO N N- 0) C7) CO N 0) CO CO CO 00 00 I� A H L 03 CO E N °� co co 0 co co co co O Lt) LC) O co m 0) LU 0) CO c M N M (fl N 0 CO O r- I- M LC) LC) I- LC) LC) 0) CO 0) 0) 0) 0) N CO CO (/) O 2 0 C 0 Q • I O N- 00) 00LO) d- O '- LN O CO 00) U Q CO N CO I- M Ll) M N CO CO 0) 0) 0) CO OO CO 00 CO coO O O co CO Q i i 00 co Q co J J J J J J 0\0 00 NN N- N N N N N O 4 4 4 LI) L() CA O CA — 0) N CO CO O V co co O co N J 0 CO CO M !� N LO C W W W Q Q Q (70www LU U Z_ Z Z W W W W W W W c[ pp pp • Z _ _ _ _ U Z Z J J J J (n Perforation Attachment ADL0028328 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03-10 12/1/89 SQZ 9188 9208 8654 8674 03-10 6/4/92 APF 9213 9216 8679 8682 03-10 6/4/92 RPF 9216 9236 8682 8702 03-10 2/25/96 RPF 9240 9249 8706 8715 03-10 2/25/96 RPF 9249 9252 8715 8718 - 03-10 2/25/96 RPF 9252 9256 8718 8722 03-10 2/25/96 RPF 9256 9266 8722 8732 03-10 2/25/96 RPF 9266 9272 8732 8738 03-10 2/25/96 RPF 9272 9290 8738 8756 03-10 12/1/89 SQZ 9290 9292 8756 8758 03-10 12/1/89 SQZ 9354 9369 8820 8835 03-10 12/1/89 SQZ 9371 9372 8837 8838 03-10 12/1/89 SQZ 9378 9379 8844 8845 03-10 12/1/89 SQZ 9387 9388 8853 8854 03-10 12/1/89 SQZ 9394 9395 8860 8861 03-10 7/7/92 RPF 9406 9425 8872 8891 03-10 7/7/92 RPF 9425 9440 8891 8906 03-10 7/7/92 SQZ 9440 9450 8906 8916 03-10 11/24/89 STC 9460 9474 8926 8940 03-10 11/24/89 STC 9500 9512 8966 8978 03-10 7/24/86 RPF 9533 9555 8999 9021 03-10 7/24/86 RPF 9560 9576 9026 9042 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF NGS 125 TREE_, CNV 03-1 O ppm WHEN ON MI.H2 REQUIRESS A(SSSV WELLHEAD= FMC II WHEN ON MI. ACTUATOR= BAKER C /1 ►/ KB.ELEV= 64' 9-5/8"CSG,47#,L-80 H 1390' /i� ��1 BF.ELEV= ? HYD 563,ID=8.681" 11G A• 1376' -195/8"HES ES CEN6JTER 11 1/ KOP= 4100' 1 1 Max Angle= 45°@ 5900' 9-5/8"BOWEN EXT -I 1390' 14. it 1994' -15-1/7 HES X NIP,ID=4.562" Datum MD= 9398' CSG PATCH II.: h1ll Datum TVD= 8800'SS1, j 2338' H9-5/8"UPPER FOC 11. 1! 5-1/2", 17#,L-80 HY D 563 XO TO L-80 TCII -I 1964' 1.1 1.1 2465' -19-5/8"LOWER FOC 13-3/8"CSG,72#,L-80 BTC,ID=12.347" -I 2731' 8366' -15-117"HES X NIP,ID=4.567' 0 10 8387'_1-19-5/8"X 5-1/2'BKR S-3 PKR,ID=4.750" Minimum ID = .875"@ 9332' CHOKE IN X NIPPLE 8411' -I5-1/7'HES XNIP,ID=4.567' 5-12"TBG,17#,L-80 TCII, -I 8494' 8473' -5-1/7'HES XN NIP,ID=4.455" .0232 bpf,ID=4.892' - 850W -9-5/8"X 5-12"UNIQUE OVERSHOT 5-1/7'TBG STUB(03/23/08) - 8493' 135.341-5-1/7'OTIS SBR ASSY,ID=4.562" �a� FIN 8561' -19-5/8"X 5-1/7'OTIS RH PKR, ID=4.734" 5-12"TBG-PC,17#,L-80, .0232 bpf,ID=4.897' -I 8566' 8566' -15-1/2"X 4-12"XO,ID=3.958" TOP OF 7"LNR H 8746' 8745' H9-5/8"X 7"BOT LNR HGR,ID=? 111 8804' -14-12"OTIS X NIP,ID=3.813" 4-12"TBG,12.6#,L-80 BTC,.0152 bpf,ID=3.958" -1 8849' 8849' -14-1/2"TT WLEG,ID=3.958" 9-5/8"CSG,47#,N-80,ID=8.681" - 9067' 8837' H MD TT LOGGED 09/18/86 9152' H TOP 7'MKR JOINT 9171' 1 BOTTOM T'MKR JOINT I 9310' H T X 4-12"OTIS WD PKR ID=4.00" 9314' -5-3/4"MILLOUT EXTENSION(8'),ID=4.35" 4-1/2"IPC TBG, 12.6#,L-80 BTC, -1 9344' 9322' -15-3/4"X 4-12"XO, ID=3.958" 0152 bpf,ID=3.958" 9332' 4-12"OTIS X NP W/7/8"DOWNHOLE TOP OF 4-112"TBG --J 9453' I ICHOKE(4-1/2'X LOCK),ID=3.813' 9344' -14-12"TT WLEG,ID=3.958" PERFORATION SUMMARY c/ 9453' HT X 4-1/2"OTIS WD PKR,ID=4.00" REF LOG:BRCS ON 08/31/79 1 9457' H5-3/4"MILLOUT EXTENSION,ID=4.35" ANGLE AT TOP PERF:2°@ 9213' A8464` 5 314"X 421XO ID=3.958" Note: Refer to Production OB for historical perf data SIZE SPF I INTERVAL Opn/Sqz DATE 9503' H4-1/2"AVA BPL XN NIP,ID=3.70"w/BPI SEE PAGE 2 FOR PERFORATION DATA 9516' -4-12"X 3-1/7'XO,ID=2.97" 9518' HT'X 4-12"OTIS WD PKR ID=4.00" 4-1/2" tli IPC TBG,12.6#,L-80, .0152 bpi,ID=3.958" H 9528' 1-- , 9522' H5.78"MILLOUT EXTENSION,ID=4.35ill J 9526' -f3-1/2"MULE SHOE ID=2.97 9528' H4-12 XO 3-12" ID=7" PBTD JI 9732' ' 9529' -3-1/7'OTIS XN NIP,ID=2.635" 7"LNR,29#,L-80,.0371 bpf,ID=6.184" H 9775' •••••••• 9531' -3-1/7'MULESHOE,ID=2.97" 1111111111111111 TD 9780' 1111111111111111 9639' -UNKNOWN DEBRIS(TAGGED 02/21/86) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJMD ADDED I-QS SAFETY NOTE WELL: 03-10 07/27/86 WWt RWO PERMIT No:'1790210 04/04/93 1428E RWO API No: 50-029-20361-00 04/05/08 N4ES RWO SEC 11,T10N,R15E,2134'FSL&638'FVVL 05/05/09 FR/JMD DRLG DRAFT CORRECTIONS 02/11/11 AIB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) TREE= CAN 03-1 0 WELLHEAD= FMC ACTUATOR= BAKER C 1 v' i I KB ELEV= 64' ►• BF.ELEV = _? IAC KOP= 4100' ►1 Max Angle= 45°@ 5900' y X it Datum MD= 9398' ��, ' Datum TVD= 8800'SS ►1. II I R z I I 1 _ _ _ ›, „ PERFORATION SUMMARY \ / REF LOG BRCS ON 08/31/79 ANGLE AT TOP PERF 2°@ 9216' — — Note Refer to F-oduction DB for historical perf data SIZE SFE INTERVAL Opn/Sqz DATE 3-118" 4 9188-9208 S 07/20/86 3-3/8" 4 9216-9236 S 12/01/89 i \ 3-3/8" 4 9216-9236 0 06/04/92 A . lk 3-1/8" 4 9290-9292 S 12/01/89 • 3-1/8" 4 9354-9394 S 12/01/86 I 3-3/8" 1 9406-9425 S 12/01/89 3-3/8" 2 9406-9440 0 07/06/92 0 3-3/8" 4 9440-9450 S 12/01/89 3-1/8" 4 9460-9474 S 07/25/86 3-1/8" 4 9500-9512 S 11/24/89 ' 3-3/8" 4 9500-9512 0 07/25/86 O 3-1/8" 4 9533-9555 S 07/23/86 3-3/8" 4 9533-9555 0 05/03/93 I 3-1/8" 4 9560-9576 S 07/23/86 3-3/8" 4 9560-9576 S 05/03/93 n I U I Z ilk. a , ,,,,000,,, .,.,,,,,,,0,, 44.4..4. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE WELL 03-10 07/27/86 WW1 RWO PERMIT No '1 79021 0 04/04/93 N28E RWO API No 50-029-20361-00 04/05108 N4ES RWO SEC 11,T10N, R15E,2134'FSL&638'FWL 05/05/09 FR/JMO DRLG DRAFT CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.4,DBR,LHD,EAZ 03/31/14) General Information • Well Name: • 03-10 Well Type: Water Injection well API Number: 50-029-20361-00 Well Activity Classification: Conventional 4 Activity Description: Set Plug Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: 125 Job Type: Profile Modification Estimated Cost, $M: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory requirements? No Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? `112 Primary Secondary Engineer: Higino dos Santos Contact numbers: 907-564-4342(W) 713-269-3879(M) Well Intervention Engineer: Contact numbers: Lead Engineer: Bernhard Stechauner Contact numbers: 907-564-4594(W) Date Created: April 11,2014 Revisions(date,who,what changed): Current Well Status Information Date Oil Rate Water Rate Gas Rate GOR Choke Gas Lift Rate FTP (bond) (bwod) IMMscf/Dav) (scf/stbol (MMscf/Dav) (osil Recent Welltest or Injection 4/10/2014 17.741 1,743 Rate&Pressure Current Status: Operable If not operable or under evaluation, why? NA Recent H2S (date,ppm) NA I Maximum Deviation(angle and depth) 45° 15,900'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 0.875'®9,332'MD(Downhole choke in X Nipple) Reservoir pressure(date,psig) 3/8/2000 13,437 psi Reservoir temperature,F 157°F Shut in wellhead pressure 1,670 psi Known mechanical integrity problems(specifics) Last downhole operation(date,operation) 03/21/2010-E-line performed IPROF,temperature warmbacks and jewerly log Most recent TD tag(date,depth,toolstring 03/16/2010,9,332'MD,2.50'centralizer&sample bailer(Tagged downhole choke) OD) Comments,well history, 03-10i is a produced water injection well that had a RWO in 2008 to repair IAxOA communication and now has the OA background information,etc: cemented to surface.The well was hydraulic fracture in Zone 4 in June 1992 and has a downhole choke a OTIS X Nipple @ 9,332'MD with 3.813'ID. Schmoo-B-Gone from the manifold was executed on 11Dec13 to ensure that the wellbore is clean and ready for Bright Water to be pumped to treat Zone 4. A plug needs to be set to isolate Zone 4 and make the Bright Water treatment a success.The intent is to establish / injection for minimum of two months with new configuration and only after pump the bright water. According to the 21Mar10(PROF only 50%of the water is being injected in Zone 4(where we actually need the water) so the value of water is-125 bopd(18,000 bwpd x 0.014 bopd/bwpd).Therefore,if all the water is injected into Zone 4 the total value will be-250 bopd. Note that there is no oil production coming from below Zone 4 from any of the offset producers.Note that the plug removal after there are no longer Bright Water benefits being observed will depend on the injection conformance(if perforations are added in any of the offset producers below Zone4 and/or if surveillance data confirms oil production below Zone 4). Well Intervention Details Suspected Well Problem: Specific Intervention or Well Objectives: 1 To pull downhole choke 2 ,Set PX plug 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step p 1 S Pull downhole choke @ 9,332'MD and set 4-12'PX Plug @ 9,332'MD 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): Pull 4-12'X Lock with 7/8'diameter insert in 4-12'OTIS X Nipple @ 9,332'MD. 1 S Drift to 4-1/2 OTIS X Nipple @ 9,332'MD with gauge ring and brush. Set 4-1/T PX Plug in 4-1/2 OTIS X Nipple @ 9,332'MD 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPDI 18000 FTP(psi): 1800 Choke setting: Post job POP instructions: P01 as soon as possible post job. Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: NOTES: S NGS AVERAGE 125 TREE= CAN 03-1 O SAFETY II.PPWEN ON MWEEEQU RES A SSSV WELLHEAD= FMC I WHEN ML ACTUATOR= BAKER C //a I. 4 KB.ELEV= 64' 9-5/8"CSG,47N,L-80 H 1390' /p o/ BF ELEV= ? HYD 563,ID=8.681" /11' 1'1/ 1378' I--19-5/8"HEs ES c nnErarERI i.KOP= 4100' /•� X 111 Max Angle= 45°CA 5900' 9-5/8"BOWEN EXT --I 1390° 111 , I 1894' 1-15-12"HES X NIP,ID=4.587' I Datum MD= 9398' CSG PATCH 11: 4Datum TVD= 8800'SS 11. 4., I 2338' -19-5J8"UPPER FOC 5-1/7',17N,L-80 HY0563 XO TO L-80 Tal -I 1984' 1,1 1,1 2485' IH9-5/8"LOWER FOC I 13-3/8"CSG,720,L-80 ETC,10=12.347" -I 2731' I 8388' IH5-12"HES X NP,ID=4.567' I • Minimum ID=.875"@ 9332' 0 el 8387' H9-5/8"X 5-1/7'BKR S-3 PKR ID=4.750" I CHOKE IN X NIPPLE I 8411' H5-1/7'FES XNP,ID=4.567' I 5-1/2"TBG,170,L-80 TCII, H 8494' 1 8473' H5-1/7'NES XN NIP,ID=4.455" 0232 bpf,ID=4.892" 8508' 1-1&5/8"X5-1/7'UNIQUE OVERSHOT I I5-1/7 TBG STUB(0323/08) I-I 8493' 8538' H5-1/7'011S SBR ASSY,ID=4.562" I �� 01744 8561' J--19-5a.X 5-1/7'OTIS RH PKR,ID=4.734"I 1 5-12"TBG-PC,170,L-80,.0232 bpf,10=4.897' H 8566' 1 8568' H5-1/7'X 4-12"XO,ID=3.958" I ITOP OF 7"LNR H 8745' 8745' -19-5/8"X T'BOT LNR HGR ID=? I 8804' H412"OTSXNP,ID=3.813" I 412"TBG.12.60,L-80 BTC,.0152 bpf,ID=3.968" H 8848' I 8849' -14-1/7'TT WLEG,ID=3.958"i • 19-5/8"CSG,470,N-80,O=8.681" H 9087' 8837' H ELMD Ti'LOGGED 09/18/86 I 9152' HTOP7'MKR JOINT I 47(!/ J 9171' 1--IBOTTOM T'A/KR JOINT I �4 9310' H T'X 4-12"OTIS WD R(R,ID=4.00" I 'i 9314' 5-3/4"FALLOUT EXTENSION(8'),ID=4.35" I • 4-1/7'IPC TBG,12.60,L-80 BTC, 9344' 9322' I-15-3/4'X 412"XO,ID=3.958" I .0152 bpf,ID=3.958" 9332' -4-1/2"OTIS X NP W/7/8"DOWNHOLE TOP OF 4-1/2"TBG 9453' I CHOKE(4-1rz'X LOCK),ID=3.813" 9344' H4-12"TT WLEG,ID=3.958"I PERFORATION SUMMARY 7.4 oi 9453' H T'X 4-1/2"OTIS WD PKR,ID=4.00" REF LOGBHCS ON 08/31/79 9457' H5-3/4"MILLOUT EXTENSION,ID=4.35" I ANGLE AT TOP PERE 2' 9213' ' 8484' H5-3/4"X4-1/2"XO,ID=3.958" I ' Note:Refer to Production C8 for historical pert data SIZE I SPF I INTERVAL IOpn/Sgz I DATE 9503' H412"AVA 8PL XN NIP,ID=3.70"w/BR SEE PAGE 2 FOR PERFORATION DATA 951W H4-1/2"X 3-12"XO,ID=2.97" I I 1 I I I 14 9518' H T'X 4-1/2"OTIS WD PKR ID=4.00" I ` 9522' I-15.78"M�LOUT EXTENSION,O=4.35' 14-1/7'IPC TBG,12.60,L-80,.0152 bpf,1D=3.958" H 9528' I- \ 9528' H3-12"MIRE SHOE,ID=2.97" W �I 9528' 1--1412xo3-1rz',ID='" PBTD 9732' ' I 9529' H3-117'OTS XN NIP,D=2.635" 1 17"LNR,290,L-80, 0371 bpf,ID=6.184" -1 9775' t•t• t•t•1 9531' H3-1/7'I U ESHOE,0=2.97' I 11111111111/111 I TD 9780' 1111111111111111 I 9839' HUNKNOWN DEBRIS(TAGGED 0221/86) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/07/79 R35 ORIGINAL COMPLETION 01/10/12 TMWJMD ADDED I-QS SAFETY NOTE WELL. 03-10 0727/86 WWI RWO PERMIT No.'1790210 04/04/93 N28E RWO AR No: 50-029-20361-00 04/05/08 N/ES RWO SEC 11,T1ON,R15E,2134'FSL&638'FMA. 05/05/09 FR/JM0 DRLG DRAFT CORRECTIONS 02/11/11 MB/JA/0 ADDED SSSV SAFETY NOTE BP Exploration(Alaska) M TREE= CW 03-10 WELLHEAD= FMC ACTUATOR= BAKER Ct 1 KB.ELEV= 64' ►�• 'BF.ELEV= ? ►C • KOP= 4100' 11 • Max Angle= 45'I/5900' ►�1 X X /a 11 Datum MD= 9398' A 1 1 Datum TVD= 8800'SS ►8. �•i 1 I z z I I �1 I 1J 1� PERFORATION SUI ARY 21 lx REF LOG BRCS ON 08/31/79 ANGLE AT TOP PERF:2'ft 9216' —_ Note.Refer to Ftoduction D8 for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1 1 3-1/8" 4 9188-9208 S 07/20/86 3-3/8" 4 9216-9236 S 12/01/89 i • 3-3/8" 4 9216-9236 0 06/04/92 A 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/86 3-3/8" 1 9406-9425 S 12/01/89 1 3-3/8" 2 9406-9440 0 07/06/92 3-3/8" 4 9440-9450 S 12/01/89 3-1/8" 4 9460-9474 S 07/25/86 3-1/8" 4 95500-9512 S 11/24/89 3-3/8" 4 95500-9512 0 07/25/86 I ' 3-1/8" 4 9533-9555 S 07/23/86 3-3/8" 4 9533-9555 0 05/03/93 3-1/8" 4 9560-9576 S 0723/86 = 3-3/8" 4 9560-9576 S 05/03/93 I ra ea 1•••••••4 ••••••••��� �1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/07179 R35 ORIGINAL COMPLETION 01/10/12 TMV.15/0 ADDED HOS SAFETY NOTE WELL: 03-10 07/27/86 WW1 RWO PERMT No'.'1790210 04/04/93 N28E RWO AR No: 50-029-20361-00 04/05108 N4E3 RWO SEC 11,T10N,R15E,2134'FSL&638'FWL 05/05/09 FR/JMD DRLG DRAFT CORRECTIONS 02/11/11 M3/JAAD ADDED SSSV SAFETY NOTE Be Exploration(Alaska) v Injector Mini log 13 Techlog Project PBU_EWF Well. 03-10 Author Laura J.Larson Scale 1 700 Date 2/13/2014 Iu>a„n 64 s:71459062 SPLA Dote 1979-08.0S00.0000 Coueo USA .�NB 5939994 91 Corrpbbon Date 1879-09-0700:00:00 Fold Prudhoe Bea AO 1' ' 000 9780 - 148 273197 Status Stale Alaska .1. 70 23.4073 Operala BPXA Corntuh. BPXA DEN Z r.�s°3`10i "°"zbs Simile*Msb0809 NEU cn GR TODST MD _moi- jy ]110.8ES1 cc CALL (FEET) (h) PE Info YI RES MED 6O D7 3 _ _t19-10 T rAl I 1000 1:)00 4.10 g�ST OTro ii IN 2D yl �RI -"755 O57F SS .-... I ^ GR RES_DEP TVOSS SW PORoO 0 n03 1GA o COMP/ lvn e rAO CASE siv 10 W.W.II ..• e0v11 o Ns ^' 3 TSR. I 1 I %Water 8600 9200 13 SQP MW �,.. _ _... C"-- __._. - _._ CCC 37 Mat 4 xn 0 .. a aN 'i-8700 -9300 II. x ice« -.♦ 1 « II SQP Met . f. S .. ' "8800-_9400_ _-___- __.____—_ _.___-- Min' > ! - -. 50 MIN 3 ) I SQP®M� C ]�-; 5 c. SQP Mel 1> �` 1'4,.: -8900 .9500,_ • � '- Ili • . SQP MIN % — '�. ■MW - ill : '.; . :‘, . ill MIR C9000.9600 em ( 4 _ 1111 Il91009700 __ 1 0 I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 26, 2012 TO: Jim Regg 6/, qi (� z P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 03 -10 FROM: Lou Grimaldi PRUDHOE BAY UNIT 03 -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03 -10 API Well Number 50- 029 - 20361 -00 -00 Inspector Name: Lou Grimaldi Permit Number: 179 -021 -0 Inspection Date: 4/24/2012 Insp Num: mitLG120424153605 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03 -10 ' Type Inj W TVD 7855 IA 370 2215 ' 2190 2185 - PTD 1790210 - Type Test SPT ' Test psi 1963 OA 5 5 5 5 Interval 4YRTST - P/F P Tubing 1670 1670 1670 1670 Notes: Good solid test $ JU 1 2012 Thursday, April 26, 2012 Page 1 of 1 Schlum~erger Alaska Data & Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99603-2838 ATTN: Beth Well Job # Log Description Date BL 0337 07-23B V-123 09AKA0188 09AKA0078 BBKA-00002 OH MWD/LWD EDIT - / OH MWDA.WD EDIT CH EDIT PDC SCMT ~ - 02/14/10 01/10/10 01/15/10 2 2 1 1 1 04-42 08-12A X-04 B148-00099 AP3O-D0081 BBSK-00012 INJECTION PROFILE PRODUCTION PROFILE LDL 03/23/10 03!21/10 -03/14110 1 1 1 1 1 1 03-28 14-11A 15-318 03-10 14-07 03-11 12-28 P2-22 P2-22 B9RH-00017 83S0-00050 AP3O-000(12 89RH-00018 8146-00098 89RH-00019 ANHV-00121 BBSK-00011 BBSK-00011 PRODUCTION LOG PERF RECORD & FL 1 G BHP ~ LDL - INJEC ON PROFILE PERF RECORD & FLOWING BHP INJECTION PROFILE - PRODUCTION PROFILE - USIT CORROSION DATA - USIT CEMENT DATA y 03/19/10 /20/10 93!22110 :93/21/10 03/22/10 .03/22/10 03/18/10 03/11/iD 03/11/10 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 03-28 89RH-00017 CBL - ) 8 03/19/10 1 1 15-30A B5JN-00045 SCMT - - 03/22A0 1 1 MPS-08 BBUO-00009 USIT - 03/12/10 1 1 PLEASE ACKNl1W1 Fnr:F wt=c ctor wv cir_uru n_ gun oeT„o.uur_ n.,~ ........ ~..... -.._ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. w t / ~ ~~ ~ ~ c ~ _.~~~,,. ~~ ~~ t ~ ~ ~~~ .1 ~ ! 03/25/10 ~° ~-' ~. .ra _ ... NO. 5481 Company: State of Alaska n ~~ (,) ~ ~'} ~ ~~ Alaska Oil & Gas Cons Comm !~ 1 f ~ eP Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 qt t ~ Color CD a~ ~p Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 u 1 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMISSION t'(Cl.~ C t v c t~ MAY 1 6 200$ REPORT OF SUNDRY WELL OPERATIOa Oil & Gas Cons. Commission 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ Othe~®horage Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ SEAL TITE Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ FAILED 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~. 179-0210 3. Address: P.O. Box 196612 Stratigraphic '' Service ' 6. API Number: Anchorage, AK 99519-6612 50-029-20361-00-00 7. KB Elevation (ft): 9. Well Name and Number: "~.. 64 KB f~• PBU 03-10 8. Property Designation: 10. Field/Pool(s): ~. ADLO-028328 `''~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 9780 - feet Plugs (measured) None true vertical 9246 - feet Junk (measured) None Effective Depth measured 9732 feet true vertical 9198 feet Casing Length Size MD TVD Burst Collapse Conductor 81' 20" SURFACE - 112' SURFACE - 112' 1530 520 Surface 2731' 13-3/8" 72# L-80 SURFACE - 2730' SURFACE - 2730' 4930 2670 INTERMEDIATE 9067' 9-5/8" 47# N-80 SURFACE - 9067' SURFACE - 8533' 6870 4760 LINER 1030' 7" 29# L-80 8745' - 9775' 8212' - 9241' 8160 7020 ~~~~EU MAY ~ ~ 200 Perforation depth: Measured depth: see attachment - _ _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 5-1/2" 17#X4-1/2" 12.6# L-80 SURFACE - 8848' (+2, SEE DIAGRAM) 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BKR S-3 8387' 9-5/8"X5-1/2" OTIS RH PKR 8561' 7"X4-1/2" OTIS WD PKR 9453' 7"X4-1/2" OTIS WD PKR 9310' 7"X4-1/2" OTIS WD PKR 9517' 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: SHUT-IN Subsequent to operation: 12560 100 1027 14. Attachments: 15. Well Class after proposed work: Copies of Logs and surveys Run Exploratory Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed k: Oil ~ Gas WAA~' GINJ WINJ ,. WDSPL ~ ~ undry Number or N/A if C.O. Exempt: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ 307-352 Contact Gary Preble Printed Name Gary Preb a Title Data Managem n t n gineer e E ~ / yJ ,~ ~~ ~ Sig~{y~r~ 0 evi 04 Phone 564-4944 ~~~t'""!~f ' 1. ~~"!~ a~u~~/~AR,~aI Only ~ Perforation Depth MD (ft) 9188 - 9208 9213 - 9216 9216 - 9236 9240 - 9249 9249 - 9252 9252 - 9256 9256 - 9266 9266 - 9272 9272 - 9292 9290 - 9292 9354 - 9369 9406 - 9425 9425 - 9440 9425 - 9450 9440 - 9450 9460 - 9474 9500 - 9512 9533 - 9555 9560 - 9576 9370 - 9372 9378 - 9378 9386 - 9388 9394 - 9394 • 03-10 PERFORATIONS 179-0210 Opn/Sqz Perforation Depth TVD (ft) SQZ 8654 - 9674 OPN 8679 - 8682 OPN 8682 - 8702 OPN 8706 - 8715 OPN 8715 - 8718 OPN 8718 - 8722 OPN 8722 - 8732 OPN 8732 - 8738 OPN 8738 - 8758 SOZ 8756 - 8758 SOZ 8820 - 8835 SQZ 8872 -=$891 SOZ 8891 - 8906 SQZ 8891 - 8906 OPN 8906 - 8916 OPN 8926 - 8940 OPN 8966 - 8978 OPN 8999 - 9021 OPN 9026 - 9042 SQZ 8836 - 8838 SQZ 8844 - 8844 SQZ 8852 - 8854 SOZ 8860 - 8860 TREE _ ' WELLHEAD FMC ACTUATOR = BAKER C KB. ELEV...- 64' BF. ELEV ~._...__..z~...._ KOP= _-.n 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS • ~ _ ` 13-5/8 X 9-5/8"CMT TO Surface 13-3/8" CSG, 72#, L-80, ID =12.347" I 2730' 5-1;2" TBG; 17#: L-80, .0232 bpf, (D - 4.892'" ~ 8494' Minimum ID = .875" @ 9332' CHOKE IN X NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 8566' TOP OF 4-1/2" TBG-PC 8566' TOP OF 7" LNR 8745' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" gg4g' 9-5/8" CSG, 47#, N-80, ID = 8.681 " 9067' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"~ 9343' TOP OF 4-1/2" TBG 9453' PERFORATION SUMMARY REF LOG: BHCS ON 08!31/79 ANGLE AT TOPPERF: 2 @ 9213' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA ~ 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" TD 1390' -j9-518"` CSG, 47#, L-80, 1D-8.681" 1994' S-1f2" X Nippie, ID = 4.862:` 8366' ~ 5-112`" X N'€pple, ID = 4.562" 8387' 9-518'" X 5-'1 /2" BKR S-3 PKR 8411' S-112" X Nipp(e, (D = 4.562" 8473' S-1I2" XN Nipple, ID = 4.455" ~. 8493' S-112" TBG STUB 8509` 9-5,8"` x 5-1/2" UNiOUE GUIDED OVE4;SI-IOT 8536' 5-1/2" OTIS SBRASSY 8561' 9-5/8" X 5-1/2" OTIS RH PKR~ 8566' 5-1/2" X 4-1/2" XO a'+~'. 8804' 4-1/2" OTIS X NIP, ID = 3.813" 8849' 4-1/2" TT WLEG $837' ELMD TT LOGGED 09/18/86 9310' 7" X 4-1/2" OTIS WD PKR 9332' 4-1/2" OTIS X NIP W/7/8" DOWNHOLE CHOKE (4-1/2" X LOCK), ID = 3.813" 9343' 4-1/2" TTL WLEG 9453' 7" X 4-1/2" OTIS WD PKR 9502' 4-1/2" AVA BPL NIP, ID = 3.7" W/ BPI 9517' 7" X 4-1/2" OTIS WD PKR ' 9528' 4-1/2" X 3-1/2" XO 9528 9529' 3-1/2" OTIS XN NIP, ID = 2.635" 9530' 3-1/2" WLEG 9732' 9775' 9780' DATE REV BY COMMENTS DATE REV BY COMMENTS 09!07/79 ORIGINAL COMPLETION 07/27/86 WW1 RWO 04!04/93 N28E RWO 04/05/08 N4ES RWO 04/11/08 /TLH CORRECTIONS 05/04/08 GJF/PJC MILL XX PLUG (05/01/08) PRUDHOE BAY UNIT WELL: 03-10 PERMfT No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FEL & 1360.22' FNL BP Exploration (Alaska) TREE _ FMC GEN 1 WELLHEAD = CM/ ACTUATOR = BAKER C KB. ELEV = -. 64' BF. ELEV = KOP = 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS ~ 03-10 PERFORATION SUMMARY REF LOG: BHCS ON 08/31/79 ANGLE AT TOPPERF: 2 @ 9213' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 09188 - 09208 S 12/01/89 3-3/8" 4 09213 - 09236 O 06/04/92 3-3/8" 4 09240 - 09290 O 02/25/96 3-1/8" 4 09290 - 09292 S 12/01/89 3-1/8" 4 09354 - 09394 S 12/01/89 3-3/8" 2 09406 - 09440 O 07/07/92 3-3/8" 4 09440 - 09450 S 12/01/89 ? 4 09460 - 09474 O 07/24/86 ? 4 09500 - 09512 O 07/24/86 ? 4 09533 - 09555 O 07/24/86 ? 4 09560 - 09576 O 07/24/86 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COMPLETION 07/27/86 WW1 RWO 04/04/93 N28E RWO 04/05/08 N4ES RWO 04/11/08 /TLH CORRECTIONS 05/04/08 GJF/PJC MILL XX PLUG (05101/08) PRUDHOE BAY UNIT WELL: 03-10 PERMff No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FEL & 1360.22' FNL BP Exploration (Alaska) LJ 03-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ', 1/22/2008'T/I/O = 160/20/10. Temp = SI. Assist Sealtite (prep). Collected a fluid sample ', ifrom the OA. 1/27/2008!T/I/0= 260/0/0. Lube and Bleed Brine into IA. (Eval for depth of IAxOA leak to plan seal-tite repair) Pumped 1 bbl meth spear and 24 bbls 9.4# brine into the IA. ***WSR continues on 01/28/08'`** 1/28/2008'T/I/O = 200/1200/0. Temp = SI. Assist SealTite (mitigate SH leak). IA FL @ ',surface. Bled IAP to 500 psi. Using a triplex, pumped SealTite Gel-Seal (S), 'increased IAP to 1250 psi. SI, monitored for 30 min. No change in OAP. ',Increased IAP to 2000 psi (pumped 2 bbls total) while maintaining open OA 'bleed. SI pump, monitored for 30 min. IAP decreased to 1930 psi. SI OA 'bleed. Seal-Tite will continue to monitor. Final WHPs = 200/1930/0. 1/28/2008',***WSR continued from 01/27/08*'`* Lube & Bleed Brine into IA. (Eval for depth ', of IAxOA leak to plan seal-tite repair) Pumped another 9 bbls of 9.4# brine into 'the IA for a total of 33 bbls. Freeze protected surface valve with 1.2 bbls of neat. !,Bled oa to 0 psi. Final WHP= 220/1000/0. Annulus casing valves are open to !,gauges. 1/29/2008;T/I/O = 200/1980/0. Temp = SI. Monitor WHP's post Seal-Tite. IAP increased 50 psi overnight. No change in OAP overnight. 1/30/2008T/I/O = 200/1940/0+. Temp = SI. Monitor WHP's post seal-Tite. IAP decreased 40 psi. IA has Seal-Tite @ surface. 1/31/2008';T/I/O = 170/1900/20. Temp = SI. Monitor WHP's post Seal-Tite. TP decreased 30 psi, IAP decreased 40 psi, OAP increased 20 psi overnight. ______ _ _ _. ~ __~ W _ - _ __ _. 2/9/2008'T/I/0= 200/1900/10 Temp=S/I MIT IA PASSED to 2000 psi (Post Sealtite) :Pressured up IA to 2000 psi with 2 bbls diesel. 1 st 15 min IA lost 20 psi, 2nd 15 :min IA lost 0 psi for a total of 20 psi loss in 30 min test. Bled back 2 bbls diesel. Final WHPs= 120/800/10 (IA/OA casing valves open to gauges, IA is tagged, swab shut, needle valve ;open to gauge at time of departure) 2/17/2008'T/I/O = 200/380/10. Temp = SI. Monitor BUR while on-line (post Seal-Tite). ""*"NOTE: DSO thinks the flowline is frozen.*"'* C 2/18/2008 • T/I/O = 200/380/10. Temp = S1. Monitor BUR while on-line (post Seal-Tite). All pressures unchanged overnight. 2/19/2008,T/I/O = 200/380/10. Temp = SI. Monitor BUR while on-line (post Seal-Tite). No ',change in WHPs overnight. 2/20/2008IT/I/O = 200/380/10. Temp =Hot. Monitor BUR while on line (post Seal-Tite). No change in pressures overnight. 2/22/2008 T/I/0 = 960/940/910. Temp =Hot. Monitor BUR while online (post Seal-Tite). 'TBGP increased 760 psi IAP increased 560 psi & OAP increased 900 osi over :days. Bled OAP from 910 psi to 300 psi in 10 minutes (for BUR monitor). :During bleed IAP increased to 1060 psi. Monitored for 30 minutes. IAP ;increased 90 psi to 1150 psi & OAP increased 150 psi to 450 psi. Final WHP's = 960/1150/450. *Operator stated that OA has already been bled multiple times todav* Seal-Tite Failed ~__ 2/23/2008 T/I/O = 1010/1100/580. Temp =Hot. Monitor BUR while online (post Seal-Tite). IA FL @ surface. OA FL @ surface. TBGP increased 50 psi. IAP increased 300 psi. OAP increased 180 psi since DSO bled IAP & OAP @ 1:30 am. Bled :OAP to 0+ psi in 5 mins (10.5 gals). OAP increased 5 psi in 15 min monitor. :Bled IAP to 200 psi in 9 mins into BT (55 gal). Monitored pressures for 60 mins. :IAP increased 20 psi during monitor. OAP unchanged. Final WHPs = :1010/220/10. • • 2/25/2008 T/I/O = 1050/280/150. Temp Hot. Monitor BUR while online (post Sealtite). IA FL C surface. OA FL @ surface. TBGP increade 40 psi from 1010 psi to 1050 ;psi. IAP increased 60 psi from 220 psi to 280 psi. OAP increased 140 psi from 1D psi to 150 psi. BUR is for two days. _._ 2/26/2008 T/I/O = 1310/30/15. Temp =Hot. Monitor BUR while online (post Seal Tite). ',TP increased 260 psi from 1050 psi to 1310 psi, IAP decreased 250 psi from ',280 psi to 30 psi & OAP decreased 135 psi from 150 psi to 15 psi overnight. 2/27/2008 T/I/O = 1300/320/280. Temp Hot. Monitor BUR while online (post Sealtite). 'TBGP decreased 10 psi from 1310 psi to 1300 psi. IAP increased 290 psi from 30 psi to 320 psi. OAP increased 265 psi from 15 psi to 280 psi overnight. 2/28/2008 T/I/O = 1260/340/400. Temp Hot. Monitor BUR while online (post Sealtite). TBGP decreased 40 psi from 1300 psi to 1260 psi. IAP increased 20 psi from 320 psi to 340 psi. OAP increased 120 psi from 280 psi to 400 psi overnight. 2/29/2008 T/I/O = 1220/460/280. Temp =Hot. Monitor BUR while on-line (post Seal-Tite). 'iTP decreased 40 psi, IAP increased 120 psi & OAP decreased 120 psi :overnight. • 3/1 /2008 RWO Prep FLUIDS PUMPED BBLS 2 diesel 33 9.4# BRINE 9 NEAT METH 44 Total STATE OF ALASKA .~~5-/9-0~ ALAS IL AND GAS CONSERVATION COMMI N ~,~~y -~ ~~~$ REPO~OF SUNDRY WELL OPERA ONS `~asica ~~i ~:~ ~ i~~al~~. ~Ommission 1. Operations Performed: fs„tC~ iu`~:;y6 ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory ~ 179-021 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-20381-00-00 7. KB Elevation (ft): 64, 9. Well Name and Number: `r PBU 03-10 8. Property Designatioq\ 10. Field [Pool(s): ADL 028328 ~,. Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9780 ' feet true vertical 9246 ~ feet Plugs (measured) None Effective depth: measured 9732 feet Junk (measured) None true vertical 9198 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 81' 81' 1530 520 Surface 2731' 13-3/8" 2731' 2731' 4930 2670 Intermediate 9067' 9-5/8" 9067' 8533' 6870 4760 Production Liner 1030' 7" 8745' - 9775' 8212' - 9241' 8160 7020 ~~AN~E~ MAY ~. 200 Perforation Depth MD (ft): 9213' - 9576' Perforation Depth TVD (ft): 8679' - 9042' Tubing Size (size, grade, and measured depth): 5-1 /2", 17# x 4-1 /2", 12.6#; L-80 8848' (+2, see oiayram) Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker'S-3' packer; 5-1/2" Otis "RH' pkr; & 8387'; 8561'; (3) 4-112" Otis'WD' packers 9310'; 9453; 9517' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut, pulled & milled tubing to a depth of 8493'. Cut, pull & dress off 9-5/8" casing to 1390'. Run 9-5/8", 47#, L-80 Tieback to 1390'. Cement w/ 101 Bbls Class'G' w/ GasBlok 567 cu ft / 48 9 sx . Clean out cement run new Com letion 5-1/2", 17# L-80 . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 10,019 1,040 1,032 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status afte ork: ® Well Schematic Diagram ^ OiI ^ Gas WAG ^ GINJ ~ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~7rrp. Sundry Number or N/A if C.O. Exempt: ~~ ~ Contact Sean McLaughlin, 564-4387 ~ ~l 308-008 Printed Name Terrie Hubble Title Drilling Technologist Prepared By NameMumber: OC I / Signature ~ Phone 564-462 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 Submit Original Only s~~ Digital Well File • ~ Page 1 of 1 Well: 03-10 Well History Well Date Summary 03-10 3/5/2008 ***WELL S/I ON ARRIVAL*** (PRE RWO) RAN 4.5" BLB. & 3.80" TO 8,772' SLM.( BRUSHED NIPPLE.) RAN 3.813" XX PLUG & SET C~ 8 772' SLM. 4-3/16" PORTS TESTED W LR !) ***LEFT WELL S/I NOTIFY DSO*** 03-10 3/5/2008 T/I/0=40/0/0. Assist slickline (RWO Prep) MIT T to 3000 PASSED. Pressured tubing to 3000 psi with 4 bbls diesel. MIT T lost 40 psi 1st 15 minutes and 20 psi 2nd 15 minutes, for a total of 60 psi lost during 30 minute test. Bled tubing to 0 psi. FWHP's=0/0/0. Annulus valves left open to gauges. 03-10 3/7/2008 T/I/0= O+NACNAC. Temp= SI. T FL (RWO prep). TBG FL C~ 30'. 03-10 3/8/2008 ***WELL SHUT IN UPON ARRIVAL*** INITIAL T/I/0 = 0/0/0 BEGIN RIG UP FOR TUBING JET CUT. TREE CAP INSERT STUCK -APPLY HEAT, REMOVE TREE CAP LINE WIPER NOT SEALING AROUND WIRE DURING PT, TROUBLE SHOOT AND FIND BLOCKAGE IN HOSE. CONTINUE RIG UP. ***JOB CONTINUED ON 09 MAR 08*** 03-10 3/9/2008 ***CONTINUED FROM 08-MAR-2008 INITIAL T/I/O = 0/0/0 *** CUT TUBING AT 8400' WITH 3.65" POWER CUTTER. FINAL T/I/O = 0/0/0. ***JOB COMPLETED*** 03-10 3/11/2008 T/I/0=0/0/0 Temp= S/I Circ Out well (Pre RWO) Pumped 3 bbls of diesel down OA. OA pressured to 200 psi. RD form OA, RU to IA to begin circ. Pumped 5 bbls neat, 842 bbls 2% kcl and 177 bbls 60*F diesel down IA thru jet cut C~3 8400' up the Tbg thru hardline to treecap on 03-09. U-tube TxIA to freeze protect well.. Freeze protected hard line jumper to 03-09. Final WHPs 0/0/0 -- IA/OA casing valves open to gauges at time of departure-- 03-10 3/12/2008 Set 6 3/8" CIW J BPV pre-rig. T/I/O =VAC/0/0 03-10 3/13/2008 T/I/0= VacNac/0 Temp= SI CMIT-TxIA PASSED to 2000 psi (Pre RWO). Pumped 6.5 bbls diesel at 0.4 bpm down Tbg thru BPV to reach test pressure. T/IA lost 0 psi in 1st 15 mins, T/IA lost 0 psi in 2nd 15 mins for a total loss of 0 psi in 30 mins. Bled pressures back to 0 psi above BPV. RD from tbg and RU to IA. Bled pressures to 0 psi. Tested BPV from below by pumping 2 bbls down IA to 1000 psi. Tbg gauge read 0 psi (indicating no leak by BPV) during 15 min test. Bled pressures to 0 psi. Final WHP's 0/0/0 -- IA/OA casing valves open to gauges, swab shut, master shut and flagged, SSV shut at time of departure-- 03-10 3/13/2008 T/I/O = SSVNacNac. Temp = SI. IA FL (RWO prep). IA FL ~ 1806' (47 bbls). 03-10 3/17/2008 Set 6 3/8" CIW "J" TWC w/ T-BAR. ND/NU, test BOPE. No problems. 03-10 3/17/2008 Pull BPV rig move on. T/I/O = 0/0/0 Print Date: 5/14/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 5/14/2008 BP EXPLORATION Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date Frorn - To Hours i Task I Code ' NPT 3/16/2008 22:00 - 00:00 3/17/2008 00:00 - 06:00 06:00 - 10:30 10:30 - 13:00 13:00 - 14:00 14:00 - 16:30 16:30 - 18:00 18:00 - 22:00 22:00 - 23:30 23:30 - 00:00 311812008 00:00 - 00:30 00:30 - 03:00 03:00 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 14:30 14:30 - 16:00 16:00 - 18:00 2.001 RIGD ~ P 6.00 MOB P 4.50 MOB P 2.50 MOB P 1.00 DHB P 2.50 KILL P 1.50 KILL P 4.001 KILL I P 1.501 KILL I P down 0.50 KILL P DECOMP Closed hydraulic actuator on tree. Held weekly safety meeting with all night rig personnel. Reviewed monthly rig performance data and Safety Alerts, and discussed individuals' safety and operational concerns. 0.50 KILL P DECOMP Continued weekly safety meeting with all night rig personnel. 2.50 WHSUR P DECOMP Held PJSM. ND tree and adapter flange. Verified tubing hanger thread integrity. Checked hanger XO - 7" NSCC with 11-1/2 turns MU. Functioned lock-down screws and capped control lines. Deadhorse temp fell to -44 deg F. Personnel cautioned to limit outdoor activity and use extra care. 3.50 BOPSU P DECOMP Held Fire Drill. Held PJSM. NU BOPE. 7" fixed pipe rams previously installed in lower ram cavit . NU choke and kill lines; installed flow riser. Crew change, pre-tour HSE meeting and daily rig maintenance and checks. 1.00 BOPSU P DECOMP Day tour weekly HSE meeting. Reviewed past weeks HSE incidents in ADW ops and also reviewed new rig scorecard sheme. 1.00 BOPSU P DECOMP PUMU 7" BTC casing test joint w/XO and TIW valve. Finish preparing to test BOPE. 6.00 BOPSU P DECOMP Test BOPE. State's right to witness testing waived by Lou Grimaldi. 1.50 WHSUR P DECOMP PJSM. Rig down test equipment, pick up lubricator, pull two way check valve, lay down lubricator. 2.00 PULL P DECOMP PU and MU landing joint and cross-over to 7" NSCC (BTC). Start: Rig Release; Rig Number: Phase ~ 3/16/2008 4/5/2008 Page 1 of 13 Spud Date: 8/8/1979 End: Description of Operations PRE Gave 24-hr. notice to AOGCC of impending initial BOPE test via telephone call to AOGCC pager at 659-3607 at 07:50-hrs. RD mud lines, PU beaver slide. Scoped down and lowered derrick.Called AOGCC back and spoke to Chuck Sheve at 16:00-hrs. to verify that previous message had been received O.K. It had. PRE Moved rig DS 16 to DS 03. On pad l~ 06:00-hrs. with complete rig and camp. PRE MIRU rig modules. Spot and level sub, pits and pipe shed. Raise and secure derrick. PRE Continue to rig up lines and rig equipment. DECOMP RU lubricator to swab valve and P/T to 500-osi. Pull BPV. L/D lubricator. T/VO = 0!010. Accept rig ~ 14:00-hrs. DECOMP Take on seawater to rig pits. P/T circulating lines to 3500-psi. DECOMP Notify pad operator and BP radio of imminent gas venting and pad access restricted until danger of gas venting is past. Open up well to Super Choke. Commence circulating at 4.0-bpm 810-psi. Obtain stable returns to Tiger Tank. increase rate to 5.0-bpm C~ 1050-psi. Pipe fitting dripping on Tiger Tank. Shut down pumping to repair leak. Resumed pumping 8.5 ppg seawater. DECOMP Held crew change and performed pre-tour checks. Continued circulating well with 8.5 ppg seawater at 5 bpm and 1000 psi. Pumped total of 760 bbls seawater. Shut down pumping and monitored well; had 0 pressure on tubing and IA. Blew down fluid lines. Hauled away waste fluid for disposal. DECOMP Set TWC. Tested TWC from above to 4000 psi for 10 minutes. Printetl: 4/11/2008 12:30:49 PM C~ L BP EXPLORATION Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT ~ 3/18/2008 16:00 - 18:00 2.00 PULL P 18:00 - 19:30 1.50 PULL P 19:30 - 00:00 3/19/2008 00:00 - 06:00 4.50 PULL P 6.00 PULL P Start: 3/16/2008 Rig Release: 4/5/2008 Rig Number: Page2of13~ Spud Date: 8/8/1979 End: Phase Description of Uperatlons DECOMP Screwed into tubing hanger. DECOMP Circulated bottoms up (from 8400') at 5 bpm and 450 psi. Monitored well, had 1-2 gallons of diesel U-tubing up IA, then well stabilized with 0 pressure on tubing and annulus. Blew down circ lines. Steamed tubing spool to aid in pulling hanger. DECOMP BOLDS. Pulled tubing hanger free with gradual PU to 215k Ib. BO and LD tubing hanger and pup joint. POH and LD 7" tubing. Spooled dual 1/4" ss control lines. 39 jts LD at 00:00 hrs. Filled wellbore with seawater each 10 joints. DECOMP Continued POH and LD 7" tubing, spooling dual 1/4" ss control lines. Filled wellbore with seawater each 10 joints. LD MRB SVLN and RD control line spooler at jt #53. No visible internal or external scale or corrosion on tubing. Did not place thread 06:00 - 06:30 0.50 PULL P DECOMP Service rig, check crown o matic, PVT system, OK. Conduct daily derrick inspection, OK. 06:30 - 12:00 5.50 PULL P DECOMP Continue to POOH w/ 7" tubing. Tubing appears to be in relative) ood condition with no visible anomolies. 12:00 - 16:00 4.00 BOPSU P DECOMP PJSM. Clear /clean rig floor, drain stack, set test plug & test from the top to 4000 psi, OK. Change out pipe rams from 7" to 3 1/2" x 6" VBRs. Test annular preventor and VBRs with 3 1/2" test joint C~ 250 / 4000 psi, OK. Bleed all pressure. 16:00 - 18:45 2.75 FISH P DECOMP Pulled test plug. Installed 9" ID wear bushing. PUMU fishing BHA #1: OS guide, OS, ext, bumper sub, oil jar, float sub, DC x 9. Held crew change and performed pre-tour checks. 18:45 - 00:00 5.25 FISH P DECOMP RIH with fishing BHA #1, picking up 3-1/2" DP from pipe shed. 3/20/2008 00:00 - 01:30 1.50 FISH P DECOMP Continued RIH with fishing BHA #1, picking up 3-1/2" DP from pipe shed. Tagged 4-1/2" tubing stub at 8394' DPM. 01:30 - 03:00 1.50 FISH P DECOMP PU kelly and established parameters: PU 156k Ib, SO 125k Ib, Rot 140k Ib, 4 bpm, 550 psi, 47 rpm, 150 a, 3000 Ib-ft. Worked overshot over tubing stub with rotation, engaged grapple. Hit jar 4 times with 200k Ib PU. SO to neutral weight. Slowly rotated 16 RH turns, got 2 turns back. PU above jar trip point, indicating EBH-22 anchor latch released. SO 15k beyond neutral point to re-latch anchor. PU to 175k Ib for 1 jar strike. Slowly rotated 13 RH turns, got 1 turn back. PU 2nd time above jar trip point, indicating fish free. Set back kelly. 03:00 - 04:30 1.50 FISH P DECOMP CBU the long way from 8400'. Pumped 6 bpm and 1300 psi. No gas with bottoms up. 04:30 - 06:00 1.50 FISH P DECOMP LD 1 jt 3-1/2" DP. POH, standing back DP. 06:00 - 06:30 0.50 FISH P DECOMP Service rig, check PVT system, crown o matic, OK. Perform daily derrick inspection, OK. 06:30 - 10:00 3.50 FISH P DECOMP Continue to POOH w/ 3 1/2" DP & fishing BHA. 10:00 - 11:30 1.50 FISH P DECOMP PJSM. Stand back drill collars, release overshot from fish, lay down fish. Recovered cut off jt ... 20.10', pup jt ... 6.75' and EBH-22 anchor assembly. Top of packer should be C~ 8421'. Well bore is stable, not taking any fluid, single barrier still in place. 11:30 - 12:30 1.00 FISH P DECOMP PJSM. Pick up packer milling BHA. 12:30 - 15:00 2.50 FISH P DECOMP PJSM. RIH w/ packer milling BHA on 3 1/2" DP. 86 stands + (1) single. 15:00 - 18:00 3.00 FISH P DECOMP PJSM. Pick up 24' pup, kelly up and taa too of packer 16' in on kell stablish parameters. Up wt = 153K, down wt = Printed: 4/11/2008 12:30:49 PM • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 03-10 03-10 WORKOVER Start: 3/16/2008 NABORS ALASKA DRILLING I Rig Release: 4/5/2008 NABORS 4ES Rig Number: Spud Date: 8/8/1979 End: Date From - To '~ Hours Task Code NPT 3/20/2008 15:00 - 18:00 3.00 FISH P 18:00 - 00:00 6.00 FISH P 3/21/2008 100:00 - 01:00 1.00 FISH P 01:00 - 04:30 3.50 ~ FISH ~ P 04:30 - 06:30 I 2.001 FISH I P 06:30 - 07:00 I 0.501 FISH I P 07:00 - 08:30 1.50 FISH P 08:30 - 12:00 3.50 FISH P 12:00 - 17:30 5.50 FISH P 17:30 - 18:00 I 0.501 FISH I P 18:00 - 19:30 I 1.501 FISH I P 19:30 - 00:00 4.501 FISH P 3/22/2008 ~ 00:00 - 02:30 ~ 2.50 I FISH ~ P 02:30 - 06:00 3.50 FISH P 06:00 - 06:30 0.50 FISH P 06:30 - 08:30 2.00 FISH P 08:30 - 09:30 1.00 FISH P DECOMP 131 K, rotating wt = 142K. Bring on pump C~ 3 bpm / 250 psi. 3000 ft / Ibs of off bottom torque ~ 78 RPM. Milling w/ 12K WOB, torque while milling fluctuating from 4000 - 8000 fUlbs. Mill on packer at 8420'. DECOMP Held crew change and performed pre-tour checks. Continued milling on packer at 8420'. Varied pump rate from 0 - 6 bpm, rotary from 60 - 80 rpm, WOB up to 20k Ib. Torque varied 3000 - 9000 Ib-ft. Made no progress. DECOMP Continued milling packer at 8420' with no progress after about 10 hrs on bottom. Continued to vary milling parameters. Consultated with fishing supervisor, made decision to trip for mill inspection. Blew down and set back kelly. DECOMP Held PJSM. LD 24' DP pup joint and 1 single. POH, standing back 86 stands 3-1/2" DP. DECOMP Stood back drill collars. LD mill BHA #2. Inspect mill face and pilot mill. Minimal wear on mill face, (practically new), and no wear on pilot mill. Empty junk subs, recovered (4) gallons of metal with a few control line band remnants. No rubber or indication of slip segments. Decision made to run back in with a burn shoe. DECOMP Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection. DECOMP Pick up Packer milling BHA #3, (burn shoe). DECOMP PJSM. RIH w/ packer milling BHA on 3 1/2" DP, 259 jts total. DECOMP PJSM. Make up 24' pup & pick up kelly. Tag top of packer 21' in on kelly ~ .8421'• Establish parameters: Up wt = 151 K, down wt = 130K, rotating wt = 140K. Bring on pump @ 3 bpm / 200 psi. Engage rotary table @ 80 RPM. Off bottom torque = 3000 fUlbs. Mill on packer w/ 10 - 15K WOB, observing on bottom torque, 4000 - 10000 ft/Ibs. Mill on down from 8421' - 8423'. Observe as back, not enou h to have to shut in well. Mill on down to 8424'. DECOMP Pumped High-Vis sweep. Circulated seawater at 6 bpm and 700 psi. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued circulating at 6 bpm and 700 psi. Pumped total of 530 bbls seawater. DECOMP POH with BHA #3, standing back 3-1/2" DP. Stood back drill collars. DECOMP Held PJSM. LD packer mill BHA #3. Bottom cutting surface of shoe worn smooth. Moderate wear on inside of shoe. Cleared junk basket. Recovered 1 gal metal cuttings and threaded ring piece from anchor latch, jammed inside shoe. Photos on S-Drive. Held Fire Drill. Cleared and cleaned rig floor. PU packer spear BHA #4: Itco spear, bumper sub, oil jar, DCs, POS. DECOMP RIH with acker s ear BHA #4. DECOMP Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection. DECOMP Slip and cut 84' of drlling line. DECOMP PJSM. M/U 24' drill pipe pup jt, M/U kelly. 151 k UP WT, 125k down wt. Bring on pump C~ 4 bpm / 550 psi. Slack off & see top of packer ~ 8423'. Stack out up to 45K on fish, picking up Phase Description of Operations Printed: 4/11/2008 12:30:49 PM BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date Start: 3/16/2008 Rig Release: 4/5/2008 Rig Number: From - To Hours Task .Code NPT Phase 3/22/2008 08:30 - 09:30 09:30 - 13:00 13:00 - 14:30 14:30 - 15:30 15:30 - 18:00 18:00 - 19:00 19:00 - 00:00 3/23/2008 00:00 - 02:00 02:00 - 06:00 06:00 - 07:00 07:00 - 11:00 11:00 - 13:00 13:00 - 15:30 15:30 - 16:30 16:30 - 18:00 18:00 - 22:00 22:00 - 00:00 3/24/2008 00:00 - 02:30 1.001 FISH I P 3.50 FISH P 1.50 FISH P 1.001 FISH I P 2.50 FISH P 1.00 FISH P 5.00 I FISH I P 2.001 FISH I P 4.001 FISH I P 1.00 CLEAN P 4.00 CLEAN P 2.00 CLEAN P 2.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 4.00 CLEAN P 2.00 CLEAN P 2.50 EVAL P Spud Date: 8/8/1979 End: Description of Operations DECOMP each time and not seeing any sign of a fish on. (Fish should weigh no more than 1000 Ibs). No sign of any drag. No pressure increase when stacking out on fish. DECOMP PJSM. POOH w/ 3 1/2" DP 7 fishing BHA #4. DECOMP PJSM. Stand back drill collars, pull BHA above rotary table, no fish. Inspect spear, indication of top of tubing on stop sub above spear. Duct tape still on grapple. Order out new grapple (3.994") DECOMP PJSM. Make up new, (larger) grapple & fishing BHA on (9) 6 1/4" DCs. DECOMP PJSM. RIH w/fishing BHA #5 on 3 1/2" DP. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Established circulation at 3 bpm and 600 psi. PU 148k Ib, SO 123k Ib without kelly; PU 153k Ib, SO 129k Ib with kelly. SO 30k Ib to engage grapple. PU to 220k Ib, hit jar 3 times, fish came free. Set back kelly and LD 2 singles. DECOMP Jarred out of hole with fish hanging up on each casing collar. PU to 250k Ib for multiple jar strikes each stand. Required about 3 hours to pull first 9 stands, then able to POH without jarring. Stood back 3-1/2" DP. DECOMP Continued POH with spear BHA #5, standing back 3-1//2" DP. Stood back drill collars. DECOMP LD packer spear BHA #5. Recovered milled packer and entire 4-1/2" x 7-5/8" tail i e assembl .Photos on S-Drive. Two 4-1/2" pup jts in tailpipe had single 1/2" holes. Cleared and cleaned rig floor. Held Spill Drill. PU dress-off BHA #6: shoe, washpipe, drive sub, scraper, bumper sub, oil jar, DCs. DECOMP Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection. DECOMP PJSM. AIH w/ 5 1/2" tubing dress off BHA on 3 1/2" DP, (261 jts). Scrape 9 5/8" f/ 8300' - 8410', make several passes. DECOMP PJSM. Pick up 24' DP pup. Kelly up, tap toa of stub 18' in ~ 8492' DPM. Establish parameters. Up wt = 151 K, down wt = 131 K, rotating wt = 140K. Off bottom torque = 3000 ff / lbs. Pump rate C~? 3 bpm / 250 psi. Mill w/ 3 - 5K WOB, rotating 60 RPM, work through junk on top of tubing, mill /dress off tubin to 8493' DPM rotate over stump several times, OK, swallow stump with out rotating several times, OK. DECOMP PJSM. Pump 40 bbls Hi vis sweep & reverse around C~ 5 bpm / 900 psi, nothing significant back over shaker with sweep. DECOMP Conduct weekly safety meeting, covering topics including use of fall protection, control of work, pre planning work, inspection of slings and chains and review of stop cards, along with conducting drills during the course of the work day. DECOMP PJSM. POOH w/ 5 1/2" tubing dress off BHA. DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. Continued POH with dress-off BHA #6, standing back 3-1/2" DP. DECOMP Held PJSM. LD 6-3/4" DC. LD dress-off BHA #6. Cleared and cleaned rig floor. MI and spotted SWS logging equipment. TIEB1 Held PJSM. RU SWS E-line equipment for USIT logging. Barricaded and placed signs noticing sensitive areas on rig and Printed: 4/11/2008 12:30:49 PM • • BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Spud Date: 8/8/1979 Event Name: WORKOVER Start: 3/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task ',Code NPT Phase. Description of Operations -- 3/24/2008 00:00 - 02:30 2.50 EVAL _. P __ TIEB1 on pad near logging unit. RU E-line sheaves and line wiper. Assembled USIT tool string. 02:30 - 04:30 2.00 EVAL P TIE61 IH to in with USIT. Logging from surface to 3000' in -5/8" casin .Held weekly safety meeting wit a nig t personnel. Discussed Safety Alerts, STOP cards, and individuals' concerns. 04:30 - 06:00 1.50 EVAL P TIEB1 RDMO logging equipment. 06:00 - 07:00 1.00 EVAL P TIEB1 Service rig, check PVT system, crown o matic, OK. Perform daily derrick inspection. 07:00 - 09:00 2.00 DHB P TIEB1 PJSM. Pick up Halliburton RBP, run in hole, set ~ 1513', (top of fish neck ~ 1509'). Up wt & down wt = 33K. 09:00 - 09:30 0.50 DHB P TIEB1 PJSM. Test 9 5/8" casing to top of RBP C~? 1000 psi / 15 minutes /charted OK. 09:30 - 12:00 2.50 DHB P TIE61 PJSM. Dump 2200# of 20/40 river sand on top of RBP. Circulate DP clean and tap top of sand ...1474' DPM. 12:00 - 13:30 1.50 DHB P TIEB1 PJSM. Displace well bore above RBP to 9.8 ppg brine, circulating ~ 5 bpm / 300 psi. 13:30 - 15:00 1.50 DHB P TIE61 POOH w/ 3 1/2" DP & lay down running tool. 15:00 - 17:00 2.00 BOPSU P TIE61 PJSM. Pull wear bushing. Test plug rubbers damaged, order new test plug out. Set same & run in (2) lock down screws. 17:00 - 18:00 1.00 BOPSU P TIEB1 RU BOPE test equipment and chart recorder. PU 3-1/2" and 5-1/2" test joints. 18:00 - 22:00 4.00 BOPSU P TIEB1 Held crew change and performed pre-tour checks of PVT system and derrick. BOPE test witness waived by R. Noble, AOGCC at 06:00 hrs 3/24/2008. Attempted to test BOPE; would not hold test pressure. Test plug appeared to be leaking. 22:00 - 00:00 2.00 BOPSU N SFAL TIEB1 Pulled test plug and confirmed orientation. Reset test plug and attempted to test. Test plug still leaking. Attempted to pull test plug; plug was wedged in tubing spool. PU test plug with blocks while shaking with air tugger. Pulled test plug free, but junk ring (seal retainer ring) on test plug parted and remained jammed in tubing spool 3/25/2008 00:00 - 02:00 2.00 BOPSU N SFAL TIE61 Discussed plan forward with Workover Engineer and Ops Workover Supt. Held PJSM. ND BOPE to gain access to test plug junk ring stuck in tubing spool. _Two tested mechanical barriers in lace: 4-1/2" 'XX' lu at 8804' and 9-5/8" RBP at 1513'. Set back BOPE. 02:00 - 04:00 2.00 WHSUR N SFAL TIEB1 Used air tugger to pop damaged junk ring out of tubing spool. Junk ring was radially split and deformed around split. Inside surface of tubing spool had a 6" long x 1/8" deep circumferential gouge. Lip on this gouge appeared to be what prevented test plug from seating properly. Used cold chisel and power grinder to dress off and polish damaged area. FMC repaired and redressed test plug with new junk ring. Confirmed repaired test plug will seat in tubing spool. Installed test plug and RILDS. 04:00 - 06:00 2.00 BOPSU N SFAL TIE61 Held PJSM. NU BOPE. RU test equipment. 06:00 - 06:30 0.50 BOPSU P TIE61 Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection. 06:30 - 13:00 6.50 BOPSU P TIE61 rm w ekl BOPE test as er AOGCC / BP re uirements. Test all choke valves and surface safety valves, upper and lower kelly valves, along with Blind rams and pipe rams to 250 Printed: 4!11!2008 12:30:49 PM • • BP EXPLORATION Operations Summary Report.. Legal Well Name: 03-10 Common Well Name: 03-10 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES ` Date From- To Hours Task ,Code NPT ~ 3/25/2008 106:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:00 15:00 - 16:30 6.50 BOPSU P 0.50 BOPSU P 0.50 STCTPL P 1.00 STCTPL P 1.50 I STCTPL I P 16:30 - 18:00 1.50 STCTPL P 18:00 - 19:30 1.50 STCTPL P 19:30 - 21:00 1.50 STCTPL P 21:00 - 21:30 21:30 - 22:30 22:30 - 00:00 3/26/2008 00:00 - 01:30 01:30 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 07:00 07:00 - 11:30 0.50 STCTPL P 1.00 STCTPL P 1.50 STCTPL P 1.50 FISH P 1.50 FISH P 1.00 FISH P 2.00 FISH P 1.00 FISH P 4.50 FISH P 11:30 - 12:30 12:30 - 14:00 14:00 - 16:00 1.00 FISH P 1.50 FISH P 2.00 FISH P Start: 3/16/2008 I Rig Release: 4/5/2008 Rig Number: Phase_ TIE61 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIE61 TIE61 TIE61 TIE61 TIE61 TIE61 TIEB1 TIE61 TIEB1 TIEB1 TIEB1 TIE61 TIE61 TIE61 Page 6 of 13 Spud Date: 8/8/1979 End: Description of Operations / 4000 psi, OK. Pipe rams tested with 3 1/2" test joint. Test annular preventor @ 250 / 3500 psi, OK. Witnessing of test waived by AOGCC rep Robert Noble. Rig down test equipment, pull test plug. PJSM. Pick up multi string cutter assembly. PJSM. RIH w/cutter assembly on 3 1/2" DP, 14 stands, (1) single, (1) 10' pup and (1) 5' pup. PJSM. Pick up kelly. Establish parameters, 34K up wt, 34K down wt, 34K rotating wt. Bring on pump @ 5 bpm / 600 psi, unable to locate collar @ 1400', pick up and locate collar @ 1360', shut down pump and run kelly down 20' in @ 1380, DPM. Engage rotary table @ 80 RPM / 1000 ft/Ibs of torque free spin. Bring on pump to extend cutter blades @ 5 bpm / 600 psi, after two minutes observe torque gradually increasing up to 3000 - 4000 ft/Ibs, observe torque spike after about 5 minutes of cutting to 5000 - 6000 fUlbs then sudden drop off and corresponding increase in pressure on O/A. Continue with cutting op for another 25 minutes to ensure aood cut. Circulate 120 degree 9.8 ppg brine around annulus. 5 BPM @ 700 psi. Heat up 50 bbl diesel pill to 110 degrees. Close in annular preventer. Spot pill in 9 5/8" x 13 3/8" annulus & allow to soak for 30 min. Pumped 2 BPM @ 450 psi. Flushed DP w/ 12 bbls. Circulate & displace out 50 bbl diesel pillw/ 9.8 ppg brine. Returns were clean after getting small amount of dirty fluid initially. Pumped 5 1/2 BPM @ 800 psi. Pumped total of 88 bbls. S/D & monitor well. Well annulus had slight vacuum. Monitor well. Open annular. Well dead. Service rig. Check PVT alarms & inspect derrick. POOH & UD cutting assy. Clear & clean rig floor. R/U 9 5/8" handlin tools. M/U 9 5/8" Spear on single jt of 3 1/2" DP. RIH & engauge spear into 9 5/8" casing. BOLDS. Heated tubing hanger. P/U & work pipe. Pack off & hanger came free W/ 83K P/U wt. Pulled hanger & Pack off to floor w/ 67K. R/U false bowl. Break out & UD spear. R/U 9 5/8" elevators. Break out & UD hanger assy & 5' pup. Connection broke @ 8K R/U circulating head. Circulate well. Pumped 6 BPM @ 300 psi. Pumped 85 bbls.. No losses. R/D & Blow down lines & circ equip. POH & UD 9 5/8" casing. Connections tight, 8k to 36K. Servoce rog, check PVT system, crown o matic, OK. Perform daily derrick inspection. PJSM. Continue to POOH w/ 9 5/8" casing, break out torque averaging 36,000 ft/Ibs. Recovered 33 jts, 18.69' of cut off jt and (7) bow spring centralizers ..no springs lost down hole. Cut looks relatively good and even. Clear /clean rig floor, prep to pick up dress off BHA. PJSM. Pick up 9 5/8" casing dress off BHA w/ scraper. PJSM. RIH w/ 9 5/8" scraper /dress off assembly. Dress off casing stub to 1390'. P/U Wt = 42K, S/O Wt = 42K. WOB 3-5K, 5 BPM @ 150 psi. 70 RPMs. Printetl: 4/11/"1UUk3 1L:;iU:4y PM • BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Spud Date: 8/8/1979 Event Name: WORKOVER Start: 3/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2008 Rig Name: NABOBS 4ES Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 3/26/2008 16:00 - 18:00 2.00 FISH P TIEB1 Pumped 35 bbl Hi-Vis sweep & circulated hole clean w/ 9.8 ppg brine. 4.2 BPM C~ 120 psi. Pumped total of 235 bbls. 18:00 - 18:30 0.50 FISH P TIE61 Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 19:30 1.00 FISH P TIEB1 POOH & stand back 3 1/2" DP. 19:30 - 20:30 1.00 FISH P TIEB1 Break out & L/D BHA. Clean out junk baskets. Recovered 1 gal of metal shavings & debris. 20:30 - 22:00 1.50 CASE P TIEB1 Clear & clean rig floor. R/U casing tools & Torque Turn equip. 22:00 - 22:30 0.50 CASE P TIEB1 Hold PJSM. Review casing running program & assign specific tasks to personnel 22:30 - 23:30 1.00 CASE P TIEB1 P/U Bowen casing patch & ES Cementer assy. M/U & baker lock assys. Bring 35 centralizers to rig floor. 23:30 - 00:00 0.50 CASE P TIEB1 RIH w/ 9 5/8" 47#, L-80, HYD 563, Tie-Back string. Torque Turn all connections to 15800 ft-Ibs. Installed 1 free floating centralizer per joint. Used Jet Lube Seal Guard Thread compound on all connections. 3/27/2008 00:00 - 04:00 4.00 CASE P TIEB1 Con't to run 9 5/8" 47#, L-80, HYD 563 Tie-Back string. M/U & torque turn all connections to 15800 ft-Ibs. Installed 1 straight bladed free floating centralizer on first 34 jts. Used Jet Lube Seal Guard thread compound on all connections. Ran total of 35 jts. 04:00 - 05:00 1.00 CASE P TIEB1 P/U 10' space out jt + X-over for cementing head & M/U on 9 5/8" casing. RIH & engage Bowen Casing Patch on 9 5/8" stub ,~ 1390'. S/O w/ 40K. P/U & pull test to 250K. Held Ok. P/U wt = 67K, S/O Wt = 67K. 05:00 - 06:00 1.00 CASE P TIEB1 P/U & M/U cementing head. Fill hole & pressure test Tie-Back to 2000 si for 10 min. Tested good. Charted same. Pressure u to 2900 si & o en ES cementer, circulate thru same ~ 4 bpm / 250 psi, OK. 06:00 - 08:00 2.00 CASE P TIEB1 PJSM. N/D stack off well head, remove 3 1/2" x 6" VBR pipe rams. 08:00 - 09:30 1.50 CASE P TIE61 PJSM. Install emergency slips around 9 5/8" casing w/ 195K on the hook, (up wt 67K), set down & energize slips, OK. 09:30 - 11:00 1.50 CASE P TIEB1 PJSM. N/U BOPE, test break to 2500 si OK. 11:00 - 12:30 1.50 CEMT P TIEB1 PJSM. Rig up cementers, rig up clean up truck. 12:30 - 13:00 0.50 CEMT P TIEB1 Conduct pre job safety meeting on cement job w/ all involved parties including cementers, truck drivers and mud man. Identify potential hazards, red zones, safe area, and stress communicating any problems immediately & shutting down operation. 13:00 - 15:00 2.00 CEMT P TIE61 Pump 5 bbls fresh water ahead, pressure test lines to 4000 psi, OK. Pump 101 bbls 15.8 ppg class G cement w/ GasBlok ~ average rate of 5 bpm / 350 psi. Shut down and drop ES cementer closing plug. Displace w/ Schlumberger, pumping 9.8 ppg brine ~ average rate of 5 bpm / 350 psi. Observe plug bump w/ 102 bbls displaced, increase pressure, observe ES cementer close w/ 1100 - 1200 psi, increase pressure to 2075 psi & hold for a few minutes. Bleed off pressure, 1/2 bbl back, floats holding. CIP C~3 14:10 hrs. 15:00 - 16:00 1.00 CEMT P TIEB1 R/D cementing head. Blow down & R/D lines. 16:00 - 17:00 1.00 BOPSU P TIEB1 Split BOP stack to cut casing. 17:00 - 20:30 3.50 WHSUR N TIEB1 Afters littin stack, noticed casin sli shad moved u a roximatel 5" Burin cementin o eration. Attempt to P/U to 250K & re-set slips...no noticeable movement in pipie. Notified Printed: 4/11/2008 12:30:49 PM 1 • BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Spud Date: 8/8/1979 Event Name: WORKOVER Start: 3/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To 'Hours Task Code NPT Phase Description of Operations 3/27/2008 17:00 - 20:30 3.50 WHSUR N TIEB1 town engineer & elected to press secondary Pack Off into new spool. Wait on FMC to locate secondary Pack Off & install in new Tubing Spool. 20:30 - 21:00 0.50 WHSUR N TIEB1 R/U Wach's cutter & cut off 9 5/8" casing. L/D cut off jt & pup. 21:00 - 22:00 1.00 WHSUR N TIEB1 N/U new Tubing spool w/ secondary Pack Off. 22:00 - 00:00 2.00 WHSUR N TIEB1 Attempt to pressure test Pack Off. Made several attempts could not get element to hold. Pressure bleed from 2000 psi to 1500 psi in 6 min. Bled from 1500 psi to 1000 psi in 11 min. 3/28/2008 00:00 - 01:00 1.00 WHSUR N TIE61 Con't to attempt to test secondary Pack off. No success. Con't to bleed off rapidly as before. 01:00 - 03:30 2.50 WHSUR N TIEB1 Notified town engineer of Pack Off test failure. Plan to remove spool & use plastic packing to seal leaks. N/D new spool. Apply plastic around hanger. Inspeacted Pack off, Looked Ok.( Waited on plastic to arrive -1 1/2 hours. ) 03:30 - 04:30 1.00 WHSUR N TIEB1 N/U new Tubing Spool & Pack Off. 04:30 - 07:00 2.50 WHSUR N TIEB1 Attempt to test secondary Pack off against cement top. Testing to 2000 - 3000 psi, each test leveling out at progressively higher levels, up to 1400 psi. 07:00 - 07:30 0.50 WHSUR N TIEB1 Rig down test equipment. 07:30 - 10:00 2.50 BOPSU P TIEB1 PJSM. N/U 13 5/8" x 5M BOPE. Install 3 1/2" x 6" VBRs. 10:00 - 11:30 1.50 CASE P TIEB1 PJSM. Fill hole close blind rams, test 9 5/8", secondary oack off to 3500 psi / 1 hour / charted. Good test, no indication of communication between I/A & O/A. Test ports on tubing spool left open during test to verify pack off is holding, nary a drip there. 11:30 - 14:00 2.50 BOPSU P TIEB1 PJSM. Suck out stack, set test plug. Test VBR i e rams w / 1!2" test jt ~ 250 / 4000 psi, OK. Bleed pressure, lay down test joint, pull test plug, set wear bushing. 14:00 - 16:00 2.00 CLEAN P CLEAN PJSM. Pick up BHA #11 to clean out shoe track. 16:00 - 17:00 1.00 CLEAN P CLEAN PJSM. RIH w/ clean out BHA. 17:00 - 20:00 3.00 CLEAN P CLEAN P/U kelly break circulation 6 BPM C~? 200 psi. & tag up on TOC ~ 1348'. Drill cement & stringers from 1348 to 1379'. Circulate & sweep hole. Drill out ES cementer & plug from 1379 to 1380'. Pump 20 bbl Hi Vis sweep & clean hole. P/U wt = 39K, S/O Wt = 39K. Rot Wt = 40K. WOB = 3-5K, RPMs = 65-75, Torq = 2-4.5K ft-Ibs. 20:00 - 21:30 1.50 CLEAN P CLEAN P/U 3 singles, RIH & tag up hard C~ 1454'. Drill & wash cement from 1454 to 1474'. 6 BPM ~ 250 psi, WOB = 3-5K, RPMs = 75K, Torq =3-4.5K ft-Ibs. Wash down 5' into sand C~ 1479'. 21:30 - 22:30 1.00 CLEAN P CLEAN P/U off bottom & Dry drill 5' to insure cement is broken up. P/U 2' & circulate hole. clean. Pumped 20 bbl Hi-Vis sweep circulated until hole was clean. Pumped 6 BPM C~3 250 psi. 22:30 - 23:00 0.50 CLEAN P CLEAN Service rig. Check PVT alarms, Inspect derrick. 23:00 - 00:00 1.00 CLEAN P CLEAN POOH & stand back 3 1/2" DP. 3!29/2008 00:00 - 01:30 1.50 CLEAN P CLEAN Break out & L/D BHA. Empty junk Baskets. Recovered; 2 gals of metal, cement & rubber. Clean & clear rig floor. M/U RCJB BHA & stand back. 01:30 - 02:30 1.00 CLEAN P CLEAN Close in blind rams & open annulus. Pressure test 9 5/8" cas' to 3500 psii for 30 min. test OK. B ee o pressure, blow down lines & R/D test equip. 02:30 - 04:00 1.50 CLEAN P CLEAN RIH w/ RCJB Assy on 14 stands of 3 1/2" DP. P/U 1 single & kel ly. 04:00 - 04:30 0.50 CLEAN P CLEAN Break circulation 6.5 BPM C~3 1100 psi. Wash down from 1476 Printetl: 4/11/2008 12:30:49 PM • • BP EXPLORATION Page 9 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Spud Date: 8/8/1979 Event Name: WORKOVER Start: 3/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2008 Rig Name: NABOBS 4ES Rig Number: Date ii From - To Hours Task Code NPT Phase Description of Operations 3/29/2008 04:00 - 04:30 0.50 CLEAN P CLEAN to 1484'. Dry rotate down addional 4' to 1488' & kick on pump. Circ debris up into Junk basket. S/D & set back kelly. P/U Wt = 39K, S/O Wt = 39K. 04:30 - 06:00 1.50 CLEAN P CLEAN UD 1 single & POOH & stand back 3 1/2" DP. 06:00 - 07:30 1.50 CLEAN P CLEAN PJSM. Break out & empty RCJB. Recovered numerous large pieces of the ring in the ES cementer and a few shear screws along with other "junk". Opt to re run. 07:30 - 08:00 0.50 CLEAN P CLEAN Service rig, check crown o matic, PVT system, OK. Conduct daily derrick inspection. 08:00 - 08:30 0.50 CLEAN P CLEAN PJSM. M/U RCJB BHA. 08:30 - 09:30 1.00 CLEAN P CLEAN PJSM. RIH w/ 2nd RCJB assembly. 09:30 - 10:00 0.50 CLEAN P CLEAN PJSM. Pick up kelly, 39K up wt, 39K down wt. Tag 13' in on kelly ~ 1476', pick up bring on pum ~ 6 bpm and slack off rather quickly to 1498' to fill basket. 10:00 - 11:00 1.00 CLEAN P CLEAN PJSM. Stand back kelly & POOH. 11:00 - 12:30 1.50 CLEAN P CLEAN PJSM. Empty RCJB, nothing in it. Lay down same and pick up Hallibuton RBP retrieving tool. 12:30 - 13:30 1.00 CLEAN P CLEAN PJSM. RIH, tag top of sand ~ 1474'. 13:30 - 14:30 1.00 CLEAN P CLEAN PJSM. Reverse circulate sand out while displacing well to 8.5 ppg brine. Reverse sand out to top of bridge plug. Observe tag at top of plug and corresponding turning of pipe while reverse circulating, indicating slotting in. Reverse out to clean returns and 8.5 ppg brine back. Lots of sand over the shaker. 14:30 - 15:00 0.50 CLEAN P CLEAN PJSM. Release Halliburton RBP & verify released. OK. 15:00 - 15:30 0.50 CLEAN P CLEAN PJSM. Circulate bottoms up, no gas, OK. 15:30 - 16:30 1.00 CLEAN P CLEAN POOH w/ 3 1/2" DP. Inspect bridge plug. Looks OK, clean a little bit of junk from under retrieving tool. 16:30 - 18:00 1.50 CLEAN P CLEAN RIH wJ Halliburton RBP on 3 1I2" DP. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew Change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 21:30 3.00 CLEAN P CLEAN Continue to RIH w/ 90 stands of 3 1/2" DP. P/U 1 single. 21:30 - 23:00 1.50 CLEAN P CLEAN space out & set RBP l~ 8451'. R/U test equip & pressure test test equip. 23:00 - 00:00 1.00 CLEAN N DPRB CLEAN Attempt to release RBP by working pipe. Would not come free. P/U Wt = 130K S/O Wt = 114K. 3/30/2008 00:00 - 01:30 1.50 CLEAN N DPRB CLEAN R/U & reverse bottoms up to insure no junk/debris on top of RBP. Reverse up 90 bbls. Cont' to work pipe. w/ 2 turns of torgin string. P/U to 175K, 45K over & hold. weight started to ddrop off slowly. Con't to work pipe up to 175K.,RBP finally started to move. P/U to connection & then slack off below settin de th. RBP free w/ some drag. 01:30 - 03:00 1.50 CLEAN P CLEAN Circulate bottoms up Pump 6 BPM ~ 1200 psi. Pumped total of 530 bbls. Got nasty black water returns from bottom w/ no as to surface. 03:00 - 03:30 0.50 CLEAN P CLEAN POOH & UD 10 jts of excess DP. 1st five singles pulled 15-20K drag, then came w/ no overpull. 03:30 - 04:30 1.00 CLEAN P CLEAN Cut & slip 84' of drilling line. 04:30 - 06:00 1.50 CLEAN P CLEAN POOH & stand back 3 1/2" DP. 06:00 - 06:30 0.50 CLEAN P CLEAN Service rig, check crown o matic, PVT system, OK. Perform daily derrick inspection. 06:30 - 07:30 1.00 CLEAN P CLEAN Notice broken strand in drilling line. Slip and cut an additional 276' of drilling line. 07:30 - 10:30 3.00 CLEAN P CLEAN PJSM. POOH w/ Halliburton RBP. Printed: 4/11/2008 12:30:49 PM • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 0 3-10 Common W ell Name: 0 3-10 Spud Date: 8/8/1979 Event Nam e: WORKO VER Start : 3/16/2008 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 4/5/2008 Rig Name: NABOB S 4ES Rig Number: I Date From - To ~, Hours Task Code NPT Phase Description of Operations 3/30/2008 10:30 - 11:00 0.50 CLEAN P CLEAN PJSM. UD running tool and RBP. (1) packer element missing. 11:00 - 11:30 0.50 CLEAN P CLEAN Clear /clean rig floor. 11:30 - 12:30 1.00 CLEAN P CLEAN PJSM. Pick up BHA to vacuum up missing element, including rotary shoe & wash pipe extension below the RCJB. 12:30 - 13:30 1.00 CLEAN P CLEAN Conduct weekly safety meeting. 13:30 - 16:30 3.00 CLEAN P CLEAN RIH w/ cleanout assembly on 3 1/2" DP. 16:30 - 17:30 1.00 CLEAN P CLEAN P/U 8 singles & kelly. Break circulation C~ 8470'. 6 BPM C~ 1700 psi. Wash down to top of 5 1/2" stub (~ 8493', then continue to go over stub for 3' to 8496'. P/U Wt = 136K, S/O Wt = 117K. 17:30 - 18:00 0.50 CLEAN CLEAN S/B kelly, blow down lines & UD excess singles. POOH. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew change. Service rig. Inspect derrick & Check PVT alarms. 18:30 - 19:30 1.00 CLEAN P CLEAN Hold weekly safety meeting w/ all hands. 19:30 - 22:30 3.00 CLEAN P CLEAN POOH & stand back 89 stands of 3 1/2" DP. 22:30 - 00:00 1.50 CLEAN P CLEAN UD 3 6 1/4" DCs. Break out & empty RCJB. Recovered 95+% of missing rubber from RBP. UD remainder of BHA. 3/31/2008 00:00 - 02:30 2.50 CLEAN P CLEAN P/U & M/U &RIH to clean out above "XX" Plug: Rotary Shoe, WP Ext, WP Ext, WP XO Bushing, RCJB, Inner Mandril, 11 jts PAC DP, XO. TL = 359.03'. 02:30 - 06:00 3.50 CLEAN P CLEAN RIH w/ RCJB Assy on stands of 3 1/2" DP. 06:00 - 06:30 0.50 CLEAN P CLEAN PJSM. Continue in hole, observe shear guide shear w/ 12K over ~ 8493'. Tag top of slick stick ~ 8551' DPM, 06:30 - 10:30 4.00 CLEAN P CLEAN PJSM. Pick up kelly and rotate thru slick stick, OK. Up wt 131 K, down wt 116K, rotating wt 125K. Off bottom rotating torque = 2500 ft/Ibs. Rotating C~ 20 RPM. Single on in, washing down from 8551' - 8734'. Encountered resistance ~ 8734' & 15K over pulling. After several attempts to rid ourselves of this piece of junk, opted to pull back above 5 1/2" and let junk fall below us. Able to get down to 8779' with no more overpulling. Rotated C~3 8779' w/ u to 10K WOB with zero ro ress. Opt to POOH & check it out. Max on bottom torque = 3500 ft/Ibs. 10:30 - 14:30 4.00 CLEAN P CLEAN PJSM. POOH w/ cleanout assembly. 14:30 - 15:30 1.00 CLEAN P CLEAN PJSM. stand back PAC pipe, break down and empty RCJB. Recovered pieces of control line bands, packer remnants including chunk of packer rubber stuck in RCJB jet. RCJB full, 1 finger broke off "cage" on catcher sub. Opt to run 10' more of extension and new cages. 15:30 - 16:30 1.00 CLEAN P CLEAN Clear /clean rig floor. Check crown o matic, PVT system, OK. Perform daily derrick inspection. 16:30 - 18:00 1.50 CLEAN P CLEAN M/U BHA. Add an additional 5' extension to BHA. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew change. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 CLEAN P CLEAN UD 2 bad jts of 2 7/8" PAC DP. Replace w/ 1 new jt of PAC DP. (threads galled) 19:00 - 23:00 4.00 CLEAN P CLEAN RIH w/ RCJB BHA on stands of 3 1/2" DP. Sheared out w/ 12k when going over top of stub. 23:00 - 00:00 1.00 CLEAN P CLEAN Tag up on junk C~ 8775'. 90 stds + 5' pup + 6' of kelly. Brerak circulation 5.8 BPM C~ 1150 psi. Begin washing & rotate down. 4/1/2008 00:00 - 02:00 2.00 CLEAN P CLEAN Work RCJB down over junk from 8775 to 8786'. Hard bottom. No progress w/ 5K WOB. P/U Wt = 130K, S/O Wt = 115K, Rot Wt = 120K. RPMS = 25, WOB 1-5K. Torq 2500 ft-Ibs. P/U w/ 20K over pull. Work up & down came free. 02:00 - 05:30 3.50 CLEAN P CLEAN Set back kelly. Blow down lines. POOH & stand back 3 1/2" Printed: 4/11/2008 12:30:49 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date ~ From - To Hours Task I Code NPT 4/1/2008 02:00 - 05:30 3.50 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 07:00 1.00 CLEAN P 07:00 - 07:30 0.50 CLEAN P 07:30 - 08:00 0.50 BOPSU P 08:00 - 14:30 6.50 BOPSU P 14:30 - 15:30 ~ 1.00 ~ CLEAN 15:30 - 17:30 2.00 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 22:00 3.50 CLEAN P 22:00 - 00:00 I 2.001 CLEAN I P 4/2/2008 100:00 - 00:30 I 0.501 CLEAN 1 P 00:30 - 01:30 1.00 CLEAN P 01:30 - 05:30 4.00 CLEAN P 05:30 - 07:00 1.50 CLEAN P 07:00 - 07:30 0.50 CLEAN P 07:30 - 08:30 1.00 CLEAN P 08:30 - 14:30 6.00 FISH X 14:30 - 16:00 1.50 FISH C 17:00 - 17:30 0.50 FISH C 17:30 - 18:00 0.50 FISH C 18:00 - 18:30 0.50 FISH C 18:30 - 22:00 3.50 FISH C 22:00 - 23:00 I 1.001 FISH I C 23:00 - 00:00 ~ 1.00 ~ FISH ~ C 4/3/2008 ~ 00:00 - 03:00 ~ 3.00 ~ FISH ~ P 03:00 - 08:30 I 5.501 FISH I P Start: 3/16/2008 Rig Release: 4/5/2008 Rig Number: Page 11 of 13 ~ Spud Date: 8/8/1979 End: Phase Description of Operations CLEAN DP. CLEAN Stand back PAC DP. Break out BHA & empty RCJB. CLEAN Service rig, check PVT system, crown o matic, OK. Perform daily derrick inspection. CLEAN Lay down RCJB BHA. CLEAN PJSM. Pull wear bushing, set test plug. CLEAN Perform weekly BOPE test. AOGCC rep Lou Grimaldi waived witnessing the test. 24 hour notice given. CLEAN R/D test equip. Pull test plug. Install wear bushing. Clear & clean rig floor. CLEAN PJSM. PUMU 5 Bladed Mill Assy to mill juhnk. CLEAN RIH w/ Mill assy. CLEAN Crew Change. Service rig. Inspect derrick. Check PVT alarms. CLEAN RIH w/ Milling assy on stands of 3 1/2" DP. Sheaered out w/ 13K to go thru top of tubing stub@ 8493'. CLEAN P/U 24' DP pup & kelly. Break circulationC~3 tag up ~ 8786' Be in millin & mill 1' to 8787'. Milling started slow& hard, bottom broke up & milling rate increased, then torqued up. P/U w/ 45K over pull & string came free. Noted fluid loss. P/U Wt = 131 K, S/O Wt = 125K. Rot Wt = 128K. 4 BPM ~ 740 psi. WOB = 5-6K. RPMs = 55 Torq = 3200 tt-Ibs. CLEAN S/D & monitor well.`Fluid level dropping. Notified town engineer. Plan to POOH. POOH to above tubing stub. CLEAN Monitor well & check static fluid loss rate by filling hole every 15 min. Losing 16-20 BPH. CLEAN Set back Kelly, blow down lines & UD 24' pup. POOH & stand back 3 1/2" DP. CLEAN Break out & UD BHA. CLEAN Service rig, check PVT system, crown o matic, OK. Perform daily derrick inspection. CLEAN Clear and clean rig floor. RUNCMP Collaborate with RWO engineering, ADW Well Ops, Baker Fishing and Halliburton on plan forward to retrieve 4-1/2" XX lu .Wait on fishing tools and additional 2-7/8" PAC DP to arrive. RUNCMP PUMU spear BHA and additonal 2-7/8" PAC DP. RUNCMP GPB safety stand down per Willingham/Williams. Reviewed current GPB safety statistics with crew. RUNCMP PUMU spear BHA and additonal 2-7/8" PAC DP. RUNCMP Crew change. Service rig. Inspect derrick. Check PVT alarms. RUNCMP RIH w/ Spear assy on 81 stands of 3 1/2" DP. P/U 2 singles & kelly. RUNCMP Break circulation 2 BPM ~ 1030 psi. RIH slowly till kelly RUNCMP UD 2 sl ow y continue to RIH & look for plug. Tagged u ~ 9325' 6' hi h to ni le w/ choke in well dia r m 87 f stands + 55' of stand 88. Notified town engineer. Plan to CBU & POOH & stand back DP. RUNCMP Circulate bottoms up. Pump 2 BPM ~ 1330 psi for 50 bbls to clear tubing. Drop bar & open pump out sub w/ 2700 psi. Pump 6 BPM ~ 1110 psi. Pumped total of 570 bbls. Recorded 4 bbls of losses. Monitor well. Fluid level drops slowly. RUNCMP UD circulating head. POOH & stand back 3 1/2" DP. Breakout Printed: 4/11/2008 12:30:49 PM • BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Spud Date: 8/8/1979 Event Name: WORKOVER Start: 3/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours' Task Code; NPT Phase - Description of Operations 4/3/2008 03:00 - 08:30 5.50 FISH P RUNCMP shear guide assembly and inspect spear. No fish on! Grapple intact. 08:30 - 09:00 0.50 FISH P RUNCMP Redress spear w/2.515" nomial catch grapple. Redress shear guide assembly with two shear screws. 09:00 - 12:30 3.50 FISH P RUNCMP RIH w/2-7/8" PAC DP and 3-1/2" PAC DP from derrick. 12:30 - 15:00 2.50 FISH P RUNCMP Slip and cut drilling line. 15:00 - 15:30 0.50 FISH P RUNCMP Cont. RIH w/3-1/2" DP. Tap top of tubingstub_at 8493' w/bottom of shear guide assembly. Ease over stub an additonal 18'. Set down on stub with shear guide and shear pins with 12K downweight. RIH to 9323' Kelly up. PUW = 138K, SOW = 122K. Establish circulation at 2.0-bpm and 1268-psi. Wash down and tag fish at 9325'. Set 10K downweight on fish to engage spear. Pump pressure increased to 1325-psi. 15:30 - 18:00 2.50 FISH P RUNCMP POH slowly with 1-2K additional drag. Layed down 13 jts. and eased fish into WLEG at 8849' and up through X nipple at 8804'. Layed down an adidtional 12 jts. and cleared top of tubing stub at 8493' with no further dragging noted. Continued POH LDDP 1 x 1 through pipe shed. 18:00 - 18:30 0.50 FISH P RUNCMP Service rig. Check PVT alarms. Inspect derrick. 18:30 - 00:00 5.50 FISH P RUNCMP Con't to POOH &LDDP 1x1. Laid down 260 jts. 4/4/2008 00:00 - 00:30 0.50 FISH P RUNCMP Finish POOH & L/D 3 1/2" DP 1x1. Laid down total of 270 jts. R/D DP tools. 00:30 - 03:30 3.00 FISH P RUNCMP Break out & PAC DP & BHA. No recovery on spear. Left remains of 4-1/2" "XX" lu in well @ 9325'. 03:30 - 05:00 1.50 FISH P RUNCMP Clear & clean rig floor. 05:00 - 06:30 1.50 BUNCO RUNCMP R/U floor to run completion. R/U Torque Turn equip. Service rig, check PVT system, crown-o-matic, OK. Perform daily derrick inspection. Filled well with 14-Bbls. seawater. 06:30 - 07:00 0.50 BUNCO RUNCMP PJSM -reviewed running completion procedure with all crew, Nabors casing and Baker Packer tech. 07:00 - 10:00 3.00 BUNCO RUNCMP PUMU completion jewelry; 9-5/8" x 5-1/2" guided overshot, 5-1/2" "XN" nipple asst'., 1 jt. 5-1/2" 17#, L-80 TCII tubing, 5-1/2" "X" nipple asst'., 9-5/8" x 5-1/2" Baker S-3 packer and 5-1/2" "X" nipple asst'. Torque turned all connections to optimum torque of 4350 ft-Ibs. using "Jet Lube Seal Guard" thread compound and Baker-Lok on all connections below packer including bottom side of coupling on 1st. 5-1/2" joint. 10:00 - 18:00 8.00 BUNCO RUNCMP RIH w5-1/2" tubin 1 x 1 from pipe shed using compensator and torque turning all connections to specified torque of 4350 ft-Ibs. and applying "Jet Lube Seal Guard' thread compound as needed. 45 jts. RIH at 13:00-hrs. 112 jts. RIH ~ 16:15-hrs. 18:00 - 18:30 0.50 BUNCO RUNCMP Crew change. Inspect derrick. Check PVT alarms. 18:30 - 20:30 2.00 BUNCO RUNCMP Con't to RIH w/ 5 1/2" 17#, L-80, TCII tubing. RIH w/ 159 jts Torque turned all connections to 4350 ft-Ibs. Used Jet Lube Seal Guard thread compound on all conections. 20:30 - 21:30 1.00 BUNCO RUNCMP RIH w/ 5 1/2" "X" Niplle asst'. M/U 2 X-overs & 6 jts of 5 1/2" 17#, L-70 HYD 563 tubing. Torque turned connections to 6700 ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections. 21:30 - 23:00 1.50 BUNCO RUNCMP Con't to RIH w/ 5 1/2" 17# L-80, TCII tubing. Torque turn all connections to 4350 ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections. RIH w/ 200 jts. rrintea: nnuzuuu usu:uarrv~ • • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 03-10 Common Well Name: 03-10 Spud Date: 8/8/1979 Event Name: WORKOVER Start: 3/16/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task I Code I, NPT Phase ` Description of Operations 4/4/2008 23:00 - 00:00 1.00 BUNCO RUNCMP P/U jt # 201 & 17' of Jt #202. & bottomed out. Saw shears ~ 7' in & 15' in on Jt # 202. P/U wt = 143K, S/O Wt = 123K. L/D jts # 200, 201, 202. Perform space out. 4/5/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Space out completion. Bury the following pups; 9.76' + 9.78' + 4.05' + 3.78'. RIH w/ jt # 200. Torque turned all connections to 4350 ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections. M/U hanger & landing jt w/ circulating head. 01:00 - 04:00 3.00 BUNCO RUNCMP Displace well w/ 200 bbls of 120 degree seawater, followed by 285 bbls of 120 degree inhibited brine. Pumped 3 BPM @ 150 psi. 04:00 - 04:30 0.50 BUNCO RUNCMP Land 5 1/2" com letion. P/U Wt = 143K, S/O Wt = 123K. RILDS. 04:30 - 08:00 3.50 BUNCO RUNCMP R/U lines to annulus & freeze protect annulus w/ 88-Bbls of diesel. Bullhead 2 BPM @ 650 psi. Crew change. Service rig, check PVT system, crown-o-matic, OK. Perform daily derrick inspection. R/U to pump down tubing. Bullhead 47-bbls. diesel down tubing at 1.5bpm ~ 800-psi. Shut down pumping and observed SITP C~3 600-psi. Bled pressure off tubing and recovered 14-Bbls. diesel. Tubing freeze protected with 34-Bbls. diesel to 1500'. Notified GPB Wireline and Completions Coordinator and noted on RWO handover form. 08:00 - 09:30 1.50 BUNCO RUNCMP Dro ed ball & rod. Pressure up tubing to 4000-psi to set acker and held ressure for 30-charted minutes. Test O.K. Bled tubing pressure off to 1500-psi and pressure up IA to 4000- si for 30-charted minutes. Test O.K. Bled pressure to 0-psi. 09:30 - 10:30 1.00 BUNCO RUNCMP FMC d rod set TWC. P!f TWC from above to 1500-psi for 10-minutes. Bled off pressure. 10:30 - 12:30 2.00 BOPSU P RUNCMP RDMO LRS. ND ROPE. 12:30 - 18:00 5.50 WHSUR P RUNCMP NU Tree and adapter. P/T adapter to 5000-psi for 30-minutes. P/T Tree to 5000-psi for 30-minutes. Left TWC installed in wellhead per authorization from RWO Team Lead and GPB Wireline & Completions Coordinator. Also communicated this with GPB Drill Site Maintenance. Noted same on RWO handover form. Rig released at 18:00-hrs. Pnntetl: 4n 12oUtl IY:JU:4y t'M TREE _ WELLHEAD= FMC ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = _? KOP = 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TV D = 8800' SS I Surface I 1390' -19-5/8" CSG, 47#, L-80. ID=; 1994' S-1/2" X Nipple, ID = 4.562" 13-3/8" CSG, 72#, L-80, ID = 12.347" 2730' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 8494' Minimum ID = .875" @ 9332' CHOKE IN X NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" $566' TOP OF 4-1/2" TBG-PC 8566' TOP OF 7" LNR 8745' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8849' 9-5/8" CSG, 47#, N-80, ID = 8.681" 906T 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"~ 9343' TOP OF 4-112" TBG 9453' PERFORATION SUMMARY REF LOG: BHCS ON 08/31/79 A NGLE AT TOP PERF: 2 @ 9213' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Oon/Saz DATE SEE PAGE 2 FOR PERFORATION DATA 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" L.~ 8366' -j 5-1l2" X Nipple. ID = 4.562" 8387' 9-5/8" X 5-1/2" BKR S-3 PKR 8411' S-1/2" X Nipple. ID = 4.562" 8473' 5-1l2" XN Nipple, ID = 4.455" 8493' 5-112" TBG STUB 8509' 9-5/8" x 5-112" UNIQUE GUIDED OVERSHOT 8536' 5-1/2" OTIS SBR ASSY 8561' -~-5/8" X 5-1/2" OTIS RH FKR 8566' 5-1l2" X 4-1/2" XO 8804' 4-1/2" OTIS X NIP, ID = 3.813" 8849' 4-1/2" TT WLEG 8837' ELMD TT LOGGED 09118!86 9310' 7" X 4-1/2" OTIS WD PKR 9332' 4-1/2" OTIS X NIP W!7!8" DOWNHOLE CHOKE (4-112" X LOCK), ID = 3.813" 9343' 4-1/2" TTL WLEG 9453' 7" X 4-1/2" OTIS WD PKR 9502' 4-1/2" AVA BPL NIP, ID = 3.7" W/ BPI 9517' 7" X 4-1/2" OTIS WD PKR 9528' 9528' 4-1/2" X 3-1/2" XO 9529' 3-1/2" OTIS XN NIP, ID = 2.635" -~ 9530' 3-1/2" V';LEG 9775' 9780' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07!79 ORIGINAL COMPLETION 07/27/86 WW1 RWO 04104/93 N28E RWO 04/05/08 N4ES RWO 04/11/08 ITLH CORRECTIONS 05/04/08 GJF/PJC MILL XX PLUG (05/01/08) PRUDHOE BAY UNIT WELL: 03-10 PERMfT No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FEL & 1360.22' FNL BP Exploration (Alaska) DRLG DRAFT 0 3 -'~ O TREE = FMC GEN 1 WELLHEAD = CNV ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = _? KOP = 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TV D = 8800' SS PERFORATION SUMMARY REF LOG: BRCS ON 08/31!79 ANGLE AT TOP PERF: 2 @ 9213' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 09188 - 09208 S 12/01/89 3-3/8" 4 09213 - 09236 O 06104/92 3-3/8" 4 09240 - 09290 O 02/25!96 3-1/8" 4 09290 - 09292 S 12/01/89 3-118" 4 09354 - 09394 S 12/01/89 3-3/8" 2 09406 - 09440 O 07/07/92 3-318" 4 09440 - 09450 S 12/01/89 ? 4 09460 - 09474 O 07!24/86 ? 4 09500 - 09512 O 07/24/86 ? 4 09533 - 09555 O 07/24/86 ? 4 09560 - 09576 O 07/24/86 03-10 DATE REV BY COMMENTS DATE REV BY COMMEMS 09/07/79 ORIGINAL COMPLETION 07/27186 WW1 RWO 04/04/93 N28E RWO 04/05/08 N4ES RWO 04!11/08 ITCH CORRECTIONS 05/04/08 GJF/PJC MILL XX PLUG (05/01/08) PRUDHOE BAY UNfT WELL: 03-10 PERMfT No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FEL 8 1360.22' FNL BP Exploration (Alaska) 04/09/08 1. ~w J ~~i~~~m~~r~~~' NO. 4657 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambetl Street, Suite 400 ~~~ ~~~ i. ~ ~~~~ Ataska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Orion WPII .Inh # 1 nn ~PSCrlntlnn Data 131. Cnfnr Ct) 03-10 12045070 USIT -~ 03/24/08 1 1 1-21/K-25 11998996 USIT 03/25/08 1 1 V-223 12061688 CEMENT EVALUATION LOG /(p 03/23/08 1 1 V-214 11978449 MI INJECTOR V - ~ (p r 0 04/01/08 1 1 18-13B 12061689 PRODUCTION PROFILE ~ ~_~-( ~ 03/27/08 1 1 E-10A 11998994 USIT (~ '~ 03/28/08 1 1 02-12B 11628789 MCNL a / ! U 08/21/07 1 1 15-45B 11963079 MCNL (J 02/14/08 1 1 V-220 12031459 CH EDIT PDC GR (USIT)~(5~ /(o d 03/07/08 1 V-214 40016214 OH MWD /LWD T .__._, 04/01/08 2 1 _~ Q- NLtA5t AGKNUWLtUtdE HtGtIPI HY SIGNING ANU HEI UHNIN(i ONt GIJF'Y tAGti TU: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 - 900 E. Benson. Blvd. Anchorage, Alaska 99508 a r } ,,~ ~ ~ ~~ Date Delivered: Ataska Data & Consulting Services 2525 Gambell Street, Suii 400 Anchorage, AK 99503-28 ATTN: Beth Received b • • 03-10 (PTD #1790210) IAxOA c~unication repaired Page 1 of 1 Re g, James B DOA • 9 ~ ) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj 1 Sent: Sunday, February 10, 2008 2:08 PM ~ ~ ~ 13f ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, GC2 OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; GPB, Wells Opt Eng; Winslow, Jack L.; Roschinger, Torin T.; NSU, ADW WI Tech Subject: 03-10 (PTD #1790210) IAxOA communication repaired Attachments: MIT PBU 03-10 02-09-08.x1s; 03-10 TIO PIot.BMP Jim and Tom, A Seal-Tice treatment was pumped into the IA to repair the IAxOA communication on well 03-10 (PTD #1790210) on `~ 01/28/08. Since that time, a 1900 psi pressure differential has been maintained between the IA and OA with no increase in OA pressure. In addition, the well passed an MITIA to 2000 psi on 02/09/08. Please see the attached MIT form for details. The well has been reclassified as Under Evaluation and the plan is to put the well on produced water injection and monitor the OA for pressure build up. If no communication is observed, a 10-404 will follow for the repair. If communication is observed through pressure trends, an AOGCC witnessed MITIA will be scheduled to pursue an AA. «MIT PBU 03-10 02-09-08.x1s» «03-10 TIO PIot.BMP» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 B~E~ FE8 2 ~ 2008 2/13/2008 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD (UNIT J PAD: Prudhoe Bay /PBU / DS 03 DATE: 02/09/08 OPERATOR REP: Andrea Hughes AOGCC REP: `~~ ~V Packer Dept Pretest Initial 15 Min. 30 Min. Well 03-10 Type Inj. N TVD 7895 Tubing 200 230 170 120 Interval O P.T.D. 1790210 Type test P Test psi 000 Casing 500 000 1980 1980 P/F P Notes: MIT-IA post-Sealtite repair. OA 10 200 200 200 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~` MIT Report Form BFL 9/1/05 MIT PBU 03-10 02-09-08.x1s $aaz~a ~rz ~aazi 4 ~z 4 ~ooz~ a era ~ ,taaz~ 4 wa ~o~ -r- goo too ~- ~i -~ • ~ql -f- ~aaz~ ~ ws LaazJ 4 41tr ~.oaz~o wz ~o ds~~w ~~c~ aao' ~ R ~ - oaa'z aaa'~ ~QI~ ~tll ~!~-~~ _ aaa'~ • • ~~ ~ ~ SARAH PAL/N, GOVERNOR ALASKA OII, tusL V[ S 333 W 7th AVENUE, SUITE 100 COi1T5L'`RQA~`IOAT COl-II-IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~ '~ Z.Q~$ Anchorage, Alaska 99519-6612 ~~~l~ JAS Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-10 f ~ Sundry Number: 308-008 Dear Mr. Reem: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ay of January, 2008 Encl. Sincerely, \~° 1. Type of Request:^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time ExtensioA chora n g~ _,/ ~Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well G ^ Change Approved Program ~-~yll Tubing ^ Perforate New Pool ^ Waiver ^ Other ~~//~~ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 179-021 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20361-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 03-10 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028328 ~ 64'- Prudhoe Bay Field / Prudhoe Bay Pool 12 PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9780 ~ 9246 ~ 9732 9198 None None Ca in Len h Size MD TVD Burst Colla se Structural Con u t r 81' 0" 81' 81' 1530 52 Surface 2731' 13-3/8" 2731' 2731' 4930 2670 Intermediate 9067' 9-5/8" 9067' 8533' 6870 4760 Producti n Liner 1030' 7" 8745' - 9775' 8212' - 9241' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9213' - 9576' 8679' - 9042' ~" x a-vz° x 7-srs° x s-vz° x 4-U2" x 3-V2" L-80 8848' (+z, See Diagram) Packers and SSSV Type: 4-1/2" Baker'SB-3' pkr; 5-1/2" Otis "RH' pkr; 4-1/2" Otis Packers and SSSV MD (ft): 8427'; 8561'; 9310'; 'WD'pkr; 4-1/2" Otis'WD'pkr; 4-1/2" Otis'WD' pkr 9453'; 9517' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for. 16. Well Status after proposed work: Commencin O erations: February 15, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify t at the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Da id Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date j ~y o~ Terrie Hubble, 5sa-x628 Commission Use Onl Sundry Numbe Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity I~BOP Test ~gAechanical Integrity Test ^ Location Clearance Other: '~`~®o ~S ~, ~ ~-- ~C ~~ ~~ ~ ~ C C~ . j , - Subsequent Form Required: ~0 APPROVED BY , /~"~.9i / ti.7 ~/ A roved e O MISSIONER THE COMMISSION Date ~~' 1 ~ ~s~ 8' ~-~ ~((~~ a STATE OF ALASKA ~ ~~~~~~~~ i~7 ALASKA OIL AND GAS CONSERVATION COMMfSSION APPLICATION FOR SUNDRY APPROVAL ~~ ~~ $ 20 AAC 25.280 .. fl Form 10-403 Revised 06/2006 `~ ~ ~--~ (~ (` Submit In Duplicate ~~.~~~~~IO~iS ~1~~V~~~~ • 03-10i Rig Workover • Scope of Work: Cut, Pull, Replace 7" L-80 completion with 5-1/2" tubing, Mill packer at 8427', Run a USIT to evaluate TOC. Cut, Pull, Replace 9-5/8" casing and cement to surface. MASP: 2557 psi Well Type: Injector Estimated Start Date: February 15, 2008 Pre-rig prep work: O 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. S 2 Set plug in X nipple at 8804'. MIT-T to 3000. 1f MIT-T fails set another plug in the SWS nipple at 8453'. Re-test tubin . E 3 Jet cut in the middle of the 1S full 'oint above the acker 8400'. Ref: 4/4!93 tubin summa F 5 Circulate/bullhead KWF thru the cut leaving a diesel FP cap. BH diesel into OA. Known leak in 9-5/8" casin at 39'. Bleed WHP's to 0 si. O 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 4es. ND tree. NU and test BOPE to 250 psi low, 4000 psi high protection fluid with sea water through the cut. 2. Pull and LD 7" tubing string. 3. RIH with grapple and 9-5/8" casing scraper to pull tubing stub and anchor. 4. Run USIT to determine TOC behind the 9-518" casing. 5. Set 9-5/8" RPB 600' below the TOC. 6. Cut, pull, replace 9-5/8" casing and cement to surface. 7. Drill out landing collar and cleanout. 8. Pull RBP 9. Test well to 4000 psi. 10. Remove Packer at 8427'. 11. Run new 5-1/2" L-80 tubing completion with packer at 8350' MD. 12. Displace the IA to packer fluid and set the packer. 13. Test Tubing & IA to 4000 psi.. Freeze protect to 2200' MD. 14. Set BPV. ND BOPE. NU and test tree. RDMO. Circulate out freeze 'TREE = FMC GEN 1 WELLHEAD= FMC ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = _? KOP = 4100' Max Angle = 45 (c~ 5900' Datum MD = 9398' Datum ND = 8800' SS ESTMATm CMT TOP ~ 1530' 13-318" CSG, 72#, L-80, ~ = 12.347" ~ 2730' TBG, 26#, L-80, .0383 bpf, ~ = 6.276^ 8369' TOP OF4-1/2"TBG 8369' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" ~ 8475' TOP OF 7-5/8" TBG 8475' 7-5/8" TBG, 29.7#, NT 80S, .0459 bpf, ~ = 6.875" 8496' Minimum ID = .875" @ 9332' CHOKE IN X NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, D = 4.892" 8566' TOP OF 4-1/2" TBG-PC 8566' TOP OF 7" LNR 8745' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ~ = 3.958" 8848' 9-5/8" CSG, 47#, N-80, ID = 8.681" 9067' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ~ = 3.958"11 9343, TOP OF 4-1/2" TBG -~ PERFORATION SUMMARY REF LOG: BRCS ON 08/31/79 ANGLE AT TOP PERF: 2 ~ 9213' Note: Refer to Production DB for historical pert data SEE PAGE 2 FOR PERFORATION DATA ~ (4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, D = 3.958" ~ 9528' PBTD -1 9732' 7" LNR, 29#, L-80, .0371 bpf, m = 6.184" 9775' ~~ 9780'. 03-10 ~'~ • 2183' 7" OTC MRB SLVN, D = 5.963" 8389' 7" X 4-112" XO 8370' 4-1/2" PRKR SWS NP, ID= 3.813" 8427' 9-5/8" X 4-1/2" BKR SB-3 PERM PKR 8453' 4-1/2" PRKR SWS NP, ~ = 3.813" 8474' ~ 4-1 /2" X 7-5/8" XO 8498' 5-1/2" TBG STUB FLARED TO 6-1/2" 8538' ~5-1/2" OTIS SBRASSY 8581' 9-5/8" X 5-1/2" OTIS RH PKR 8566' S-1/2" X 4-1/2" XO 8804' 4-1l2" OTIS X NP, D = 3.813" 8848' 4-1/2" TT WLEG 8837' ELMD TT LOGGED 09/18/86 9310' 7" X 4-1/2" OTIS WD PKR 9332' 4-1/2" OTIS X NP W/7/8" DOWNHOLE CHOKE (4-1/2" X LOCK), ID = 3.813" 9343' 4-1/2" TTL WLEG 9453' 7" X 4-1/2" OTiS WD PKR 9502' 4-1/2" AVA BPL NP, ID = 3.7" W/ BPI 9517' 7" X 4-1/2" OTIS WD PKR 9528' ~4-1/2" X 3-1/2" XO ~ 9529' 3-1/2" OTIS XN NP, ~ = 2.635" 9530' 3-1/2" WLEG DATE REV BY COMu~VTS DATE REV BY COMuENTS 09!07179 ORIGINAL COMPLEf10N 10!30/06 RDWiTLH WAIVER SFTY NOTE DELETED 04/04/93 LAST WORKOY6t 01ro5/02 RN/TP CORRECTIONS 12ro3 KCF/TLP ESTMATED CMT TOP 12/31/05 EZUPJC UPDATEWANERSFTY NOTE 05/30/06 DTM WELLHEAD CORRECTION PRLIDHOE BAY lpolT WELL: 03-10 PERMfT No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R75E, 3871.19' FEL 8 1360.22' FNL ~ Exploration (Alaska) TREE _ • FMC GEN 1 i 03-10 PRUDHOE BAY UNff WELL: 03-10 PERMIT No: 1790210 API No: 50-029-20361-00 SEC 1 1, T10N, R15E, 3871.19' FEL & 1360.22' FNL SP Exploration (Alaska) WELLHEAD = CM/ ACTUATOR = BAKER C KB. ELEV....- 64' BF. ELEV - __ ~ - _ KOP = 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COMPLETION 10/30/06 RDW/TLH WANERSFTY NOTE DELETED 04i0d/93 LAST WORKOVER 01/05/02 RN/TP CORRECTIONS 12/03 KCF(TLP ESTIMATED CMT TOP 12/31(05 EZL/PJC UPDATE WANER SFTY NOTE 05130/06 DTM WELLHEAD CORRECTION PERFORATION SUMMARY REF LOG: BRCS ON 08/31/79 ANGLE AT TOP PERF: 2 @ 9213' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 09188 - 09208 S 12/01/89 3-3/8" 4 09213 - 09236 O 06/04/92 3-3/8" 4 09240 - 09290 O 02/25/96 3-1/8" 4 09290 - 09292 S 12/01/89 3-1/8" 4 09354 - 09394 S 12!01/89 3-3/8" 2 09406 - 09440 O 07/07/92 3-3/8" 4 09440 - 09450 S 12!01/89 ? 4 09460 - 09474 O 07/24/86 ? 4 09500 - 09512 O 07!24/86 ? 4 09533 - 09555 O 07/24/86 ? 4 09560 - 09576 O 07/24/86 TREE _ . FMC GEN 2 WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = _? KOP = 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS • ESTIMATED CMT TOP I~ 1530' 113-3/8" CSG, 72#, L-80, ID = 12.347" I O ~ - ~ O I S TES: proposed completion 1500' 9-5/8" CSG, 47#, L-80, ID=8.681" /U ~ 2000' 5-1/2" X Nipple, ID = 4.562" 5-1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~-1 8498' 9-5/8" x 5-1/2" Unique Overshot 8498' Minimum ID = .875" @ 9332' CHOKE IN X NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 8566' TOP OF 4-1 /2" TBG-PC 8566' TOP OF 7" LNR 8745' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8848' 9-5/8" CSG, 47#, N-80, ID = 8.681" 9067' 12.6#, L-80, .0152 bpf, ID = 3.958"~~ 9343, TOP OF 4-1 /2" TBG 9453' PERFORATION SUMMARY REF LOG: BHCS ON 08/31/79 ANGLE AT TOP PERF: 2 @ 9213' Note: Refer to Production DB for historical pert data SEE PAGE 2 FOR PERFORATION DATA 114-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9528' 8330' HS-1/2" X Nipple, ID = 4.562" 8350' 9-5/8" X 5-1/2" BKR S-3 PKR 8370' S-1/2" X Nipple, ID = 4.562" 8498' 5-1/2" TBG STUB 8536' -~ 5-1/2" OTIS SBRASSY 8561' 9-5/8" X 5-1/2" OTIS RH PKR 8566' S-1/2" X 4-1/2" XO 8804' 4-1/2" OTIS X NIP, ID = 3.813" 8848' 4-1/2" TT WLEG 8837' ELMD TT LOGGED 09/18/86 9310' 7" X 4-1/2" OTIS WD PKR 9332' 4-1/2" OTIS X NIP W/7/8" DOWNHOLE CHOKE (4-1 /2" X LOCK), ID = 3.813" 9343' 4-1/2" rn WLEG 9453' 7" X 4-1/2" OTIS WD PKR 9502' 4-1/2" AVA BPL NIP, ID = 3.7" W/ BPI 9517' 7" X 4-1/2" OTIS WD PKR 9528' H4-1/2" X 3-1/2" XO 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" TD I 9732' I DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COMPLETION 10/30/06 RDW/TLH WANER SFTY NOTE DELETED 04/04/93 LAST WORKOVER 01/05!02 RN/TP CORRECTIONS 12/03 KCF/TLP ESTIMATED CMT TOP 12/31/05 EZUPJC UPDATE WAVER SFTY NOTE 05/30/06 DTM WELLHEAD CORRECTION 3-1/2" WLEG PRUDHOE BAY UNIT WELL: 03-10 PERMfr No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FEL & 1360.22' FNL BP Exploration (Alaska) • • fm° f ` ~~~ f ~ ~ ,r ` S 3, e. R_ 1 ^ 1 , ' t ~ i i i ~ d ~ '~ ~ ~~ ~ ,,._. a ~ e.. v S ` G , . ? #.1 t -_..~ (_~ ~..t F.....C ~..i J COrITSERVA A7`IO C01- IISSIpl~ Chris Colbert PE BP Exploration Alaska Inc. PO Box 196612 SARAH PAL/N, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE~ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, Alaska 99519-6612 r~ -. N01J 2 ~ 20G7 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-10 Sundry Number: 307-352 ~~ Dear Mr. Colbert: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~i day of November, 2007 Encl. ~nairman • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV ~ ZC~~7 ~ ~~'~ APPLICATION FOR SUNDRY APPR~~~~i~ & Gas Cans. Cammissiatt 20 AAC 25.280 ~ ti __ _ _ _ 1. Type of Request: Abandon Suspend Operational shutdown Perforate - Othe Alter casing ^ Repair well ^~ Plug Perforations^ Stimulate ^ Time Extension ^ SEAL TITE Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 179-0210 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage, AK 99519-6612 50-029-20361-00-00 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 03-10 " Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): - ADLO-028328 ~ 64 KB - PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9780 9246.32 ~ 9732 9143 NONE NONE Casing Length Size MD TVD Burst Collapse SEE ATTACHED Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHMENT - - 7" 26# L-80 27 - 8360 - - 4-1/2" 12.6# L-80 8360 - 8476 - - 7-5/8" 29.7# N-80 8476 - 8496 Packers and SSSV Type: 4-1/2" OTIS WD PACKER Packers and SSSV MD (ft): 9453 4-1/2" Baker S-3 Perm Packer 8427 5-1/2" Otis RH Packer 8561 5-1/2" OTIS RH PACKER 9520 4-1/2" Otis WD Packer 9310 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/3/2007 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: ~, G ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: ~ ~~~~~~ ~ ~ ~, Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Colbert Printed Name Chris Colbert Title PE Signature ~ ' Phone 564-5135 Date 11/19/2007 COMMISSION USE ONLY Conditions of a roval: Notif missio that Co re t ti it N ~ S d b pp y m n so a rep sen ve may w ness un um er: ( a ry Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~5 BFI, I~a~l ~ ~ ~ao~ Subsequent Form Required: ~~y APPROVED BY //~~/~D~ Approved by: STONER THE COMMISSION Date: /! corm lU-4U3 Hevisetl U6/2UU6 \ L[7 ~ ~-i' ~ 1 I Submit in Uuplfcate ~: Perforation Depth MD (ft) 9188 - 9208 9213 - 9216 9216 - 9236 9240 - 9249 9249 - 9252 9252 - 9256 9256 - 9266 9266 - 9272 9272 - 9292 9290 - 9292 9354 - 9369 9406 - 9425 9425 - 9440 9425 - 9450 9440 - 9450 9460 - 9474 9500 - 9512 9533 - 9555 9560 - 9576 9370 - 9372 9378 - 9378 9386 - 9388 9394 - 9394 03-10 PERFORATIONS 179-0210 Opn/Sqz Perforation Depth TVD (ft) SOZ 8654 - 9674 OPN 8679 - 8682 OPN 8682 - 8702 OPN 8706 - 8715 OPN 8715 - 8718 OPN 8718 - 8722 OPN 8722 - 8732 OPN 8732 - 8738 OPN 8738 - 8758 SOZ 8756 - 8758 SQZ 8820 - 8835 SOZ 8872 - 8891 SOZ 8891 - 8906 SOZ 8891 - 8906 OPN 8906 - 8916 OPN 8926 - 8940 OPN 8966 - 8978 OPN 8999 - 9021 OPN 9026 - 9042 SOZ 8836 - 8838 SOZ 8844 - 8844 SOZ 8852 - 8854 SOZ 8860 - 8860 ~. Casing Length Size Conductor 82 20" 94# H-40 Liner 1030 7" 29# L-80 Liner 78 4-1l2" 12.6# L-80 Liner 34 4-1 /2" 12.6# L-80 Liner 68 5-1 /2" 17# L-80 Liner 283 4-1 /2" 12.6# L-80 Production 3166 9-5/8" 47# SOO-95 Production 5874 9-5/8" 47# L-80 Surface 2701 13-3/8" 72# L-80 • 03-10 CASING ATTACHMENT 179-0210 MD MD TVD Top Bottom Top 30 112 8745 9775 9453 9531 9310 9344 8498 8566 8566 8849 27 3193 3193 9067 30 2731 • TVD Bottom Burst Collapse 30 112 1530 520 8218 9241 8160 7020 8919 8997 8430 7500 8776 8810 8430 7500 7966 8033 7740 6820 8033 8315 8430 7500 27 3193 8150 5080 3193 8533 6870 4760 30 2731 4930 2670 • • by Chris Colbert 03 & 17 Pad Enginerr BP Exploration (Alaska) Inc. GPB Water Flood Team Direct. (907) 564-5135 900 East Benson Boulevard Colbc1®bp.com P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date November 19, 2007 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-20361-00-00 Permit # 179-021, PBU 03-10 Dear Thomas E. Maunder BP Exploration (Alaska) Inc is requesting approval to use Seal-Tite to achieve and prevent IA to OA communication. The objective is to correct communication from inner to outer casing via small leak below well head using Seal-Tite procedures and sealants. This is an operable well currently shut in due to communication between the inner annulus and outer annulus when the well is on-line. Included are the steps for proposed procedure that Seal-Tite will use. Sincerely DeWayne R. Schnorr • by To: C. Olsen / J. Bixby Well Operations Team Leaders From: Jennifer Julian, Engineer DeWayne R. Schnorr, Engineer Chris Colbert, Production Engineer Date: November 19, 2007 Est. Cost: $40K Cost Code: PBD03WL10-N IOR: Injector Subject: 03-10i Sealtite Treatment to repair IA x OA communication Type Procedure F SeaiTite Treatment. Cycle squeeze. Leave well SI for 3 days. MIT-IA to 3000 psi (Establish LLR if MIT-IA fails) Current Status: SI PWI - IA x OA communication Last Injection: 11/04/2006: 11,244 BWPD @ 1,553 psi. Max Deviation: 45° @ 5900' DD Min ID: 0.875" @ 9332' Choke in XN Nipple Last Tag: 05/05/2002 @ 9339' Last DH Op: 08/05/2007: Brush and Flush to 9324' Latest H2S Value: NA, DS 03 is a H2S site Leak Rate: LLR-IA = 0.8 gpm and LLR-OA = 0.2 gpm (10/29/2006) The objective of this procedure is to repair a small leak in the PC at 39' just below tree using a Sealtite treatment. Well is a water injection well completed with L-80 tubing. The procedure consists of pumping Sealtite treatment down the IA and taking returns back up OA. The treatment will be activated by pressuring up the well until the IA by OA communication disappears. This technique has been performed successfully on two Kuparuk injectors by Conoco Phillips. These two jobs have lasted over one year. If this job is successful, it wi11 open up more candidates for this promising technique. See slides in back of procedure for a description of the repair in the Kuparuk wells. Ann Com Recent Events: > 11 /13/07: LDL found leak @ 39' > 08108/07: Caliper 7": 168 jts <10%; 35 jts 10 to 20%; 1 jt 24%. 4.5" 8 jts <10%; 1 possible hole (82%). 5.5" 3 jts <20%; 1 hole. > 07/24/07: PPPOT-IC Passed to 3000 psi, LDS > 10/29/06: CMIT-IAxOA by DHD w/triplex Failed on stabilization. >10/23/06: AOGCC CMIT-IAxOA Failed on stabilization, TP/IAP 10/20 @ 15 minutes If you have questions or concerns regarding this program, please do not hesitate to contact Jennifer Julian at 564-5663(w), 274-0929(h) or 240-8037(c); or Chris Colbert 564-5135 (w) or 907-240-8037 (c) with any questions or comments. cc: w/a: Well File • Abiective: Repair Production Casing leak at 39' with SealTite treatment. Fullbore --- SealTite Treatment 1. Pump 1.0 bbl (39.0' displacement) of blended Flo-Seal at 8.5 ppg down IA, followed by additional 0.5 bbls (20.0' displacement) with triplex pump, taking returns to surface through the OA. 2. Shut-in OA. Pump down IA, and pressure up well to per SealTite rep. (Estimated fluid compression will be determined by SealTite rep.) 3. Perform cycle squeeze until IAxOA communication disappears, then lock pressure on well for 3 days (curing time). Note: SealTite rep. may change cycle squeeze as needed. Fullbore (Post SealTite) 4. MIT-IA to 3000 psi. Establish LLR if MIT-IA fails. • • rTREE =' FWD G ,WELLHEAD = FNS ACTUATOR BAKER C KB. ELEV - -.... ~; BF. ELEV KOP = 4~, ~MaxAn~lle= 45r~5900' Datum titD - .9398' Qatuin rJD = < 3800' SS rEa ~ ToP H 1534' 72#, L•80, ~ =12.347" ~--~ 2730' .0383 bpf, ID w 6.276" 8369' TOP OF 4-ii2" TBG 8369' 4-112" TBG. 12.6#. L-80, A152 bpf, ID ~ 3.958" ~--~ $475' TOP OF 7-5f8"TBG 8475' 7-5t6"TBG, 29.7#. NT-805, .0459 bpt, ~ •« 6.875" $496' M inimum ID = .875" @ 9332' GHOKE !N X NIPPLE 5-112" TBG-PC, 17#, L-80, .0232 bpf, ~- 4.892" 6566' TOP OF4-ill"7BGPC 8566' TOPOF 7" LNR ~ 8745' 4-i>2" TBG, 12.6#, L-80, .0152 bpf. ~ W 3.958" $848' 9-518" CSG. d7#, N80. tD- 8.681" 946T 12.6#.. L-80, .0152 bpf. ID = 3.958"~--~ 9343' TOP OF 4312" TBG 9453' PERFORAT~N SUMMARY REF LOG: BRCS ON 08,'31; 79 ANGLEA7 TOPPERF 2 ~ 9213" Nnte: Refer In FA~rx~ct~n l~ tur historical pert data SIZE SPF ~fTERVAL OpnlSgz DATE SEE PAGE 2 FOR PERFORATION DATA SAft"TY t~TES: ~~~~ 2963' 7"OTIS MRB SLVN, ID=5,963" 8369' 7" X 4-112" XO $370' 4-112" PRKRSWS NF', Q = 3.813° 8427' 9-~8" X 4112" BKR SB-3 PERM PKR 8474' H4-112" X 7-5,8" XO 8498' HS-tf2" TBG STUB FIAREDTO 6-112" $538' H5-112" OTIS SBR ASSY ~ 8561' 9-5/8" X 5-1;2" OTC RH PKR 85ss' a-112°x4aiz"Xo $804' I--~ 8$4$' 8837' 9310" 4-i?2" QF6S X Nom, tt7 ° 3.613"' 41t2"TTWLEGI ELM1D TT LOGE®09116186 7"X4-112"OTISWDFKR 9332' 4-112" OTIS X N~Wi718" DOWNHOLE CHOKE (4-ii2" X LOCK}, ~ = 3.813" 9343' 9453' 4-tit" TTL WLEG 7" X 4-112" OTC W D FKR 9502' 4-1t2" AVA BPL Ni>, L? = 3.7" Wl BPI 9517' 7" X d-i.r2" OT6 WD R(R 4-1?2" TBG-PC, 12.6#, L-80..0152 hpf, ~ = 3.958" 952g' 9528' 4-112" X 3-1J2" XO 9529' 3-ii2" OTC XN NF', ~ =2.635" 9530' 3-ii2" WLEG L-80..0371 bpf, ®- 6.194° C DATE REV BY COMMENTS DATE REV BY COtv9v1ENTS 09107f79 ORIGINAL COMPLETK?N 10/30106 RDWITLH WANER SFTY NOTE DELETED D4/04193 LAST WORKOVER 03105.?02 RN.~TP CORRECTIONS 12103 KCF.fTLP ESTFhATEDCMTTOP 12/31105 EZLIPJC UPDATE WAIVER SFTY NOTE 05,'30,`06 DTM WELLHEADCORRECTK?N PRUDHOE BAY UNfF WELL 03-10 PERMff Nc: 1790214 A PI NO. 50-029-20361-00 SEC 11, TiON. R15E 3871.19' FEL & 1360.22' FNL BP Fxptoratiorr (Alaska} • 03-10 TEcWeI LDL 11/13/2007 --- Leak in IA x OA 500 Head Tension (!b} i h00 0 ALDA t 00000 0 LSPD (ttlmin} 200 0 RLOB 100000 1000 CCL -100 0 ALDG 100000 0 TEMP (degF} 80 1 L!nierential Temperature idegFb 1 1=-µ - _ _ r ~~ _ .. - ..- . - 'T I ~ ~ - ~ - -. ~ ~ Suspect Profile ~ - ' st ~: -- ~ - _ . -. ~ ~ --- - - r-- - - ~ ` ~ ~ -C CL~ ! ~ - i ~---?emperature~. - ~ ~ DC~ --- _. ' ~ - Line Speed- - AL - - -- + . . ,- . --a--- ~----! ~ ~ - ; D~~erent,al Temperature ~ ~,, ; - - - . - ~ ;J --~- ~ - _. - z + ~-- Head Tension i ~. - , _ r. : - _ - _ __ _ ~ 1 , 4 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, November 16, 2007 7:36 PM To: Schnorr, DeWayne R (PRA) Cc: Julian, Jennifer Y; Preble, Gary B (SA{C); Colbert, Chris M Subject; RE: Well 03-10i --- Sundry approval application 10-403 to fix PC leak ~~`1°~~\ DeWayne, et al, I have spoken. with Commissioner Foerster and she has given her approval for you to proceed with the proposed repair of DS 03-10. We will look to receiving the sundry on Monday. Call or message with any questions. Tom Maunder, PE AOGCC ~~,~-~~~~ Nov ~ ~ Zoos -----Original Message----- From: Schnorr, DeWayne R (PRA} [mailto:DeWayne.Schnorr@bp.com] Sent: Fri 11/16/2007 2:42 PM To: Maunder, Thomas E (DOA) Cc: Julian, Jennifer Y; Preble, Gary B (SAIC}; Colbert, Chris M Subject: Well 03-10i --- Sundry approval application 10-403 to fix PC leak Hi Tom. Sorry about the short notice on this well --- 03-IOi. We are asking for a Sundry Approval Application. 10-403 to be approved to have the following work done. This job could come up as early as the first of next week. We are asking for approval to go ahead with the work before the Sundry Approval Application 10-403 is submitted. Gary Prebel is perparing the 10-403 as I am writing this. The purpose of this 10-403 is to do the following work. We found a small leak in the Production casing at 39' using TecWel's LDL log (logged 11/24/2007). This leak is just below the tree. Leak is small, and we are asking Seal-rite (Neil Cary} if they can put together a procedure that will seal this leak. From the emails below, Neil Cary say that it can be done. If we can seal the leak in the PC by pumping down the IA (same as step 3 below), this would eliminate the need to --- 1.} punch holes in the tubing just above the packer, 2.} circulate brine down the tubing and back up the IA to surface, 3.) pump seal-tite from surface down the IA to and into the leak, and 4.) then patchng the puncher holes. The IAxOA would then be tested to assure that leak has been sealed before well would be put back on water injection. A Sundry Approval Application would be brought to AOGCC on Monday. Well Sketch is included. Sincerely DeWayne R. Schnorr From: Neil Cary [mailto:neil.cary@seal-tite.com] Sent: Friday, November 16, 2007 1:59 PM To: Julian, Jennifer Y; barry.ellis@seal-tite.com Cc: Schnorr, DeWayne R (PRA} Subject: RE: 03-10 --- TecWel LDL found leak in PC @ 39'. 1 • ~ Hey Jennifer, Yes, we have done it this way before. As Dewayne noted, the problem here will of course be the light fluid in the IA (some mixture of diesel and 60/40 McOH/water). We have trouble getting the sealant to float for very long on a methanol column. But since the leak is so shallow we may very well be able to stack up enough to treat this one. The sealant will eventually fall downhole somewhat but we can probably get enough time for a seal. Let me look a little closer and I'll get back to you. Neil From: Julian, Jennifer Y [mailto:Jennifer.Julian@bp.com] Sent: Friday, November 16, 2007 3:57 PM To: Neil Cary; barry.ellis@seal-tite.com Cc: Schnorr, Dewayne R (PRA) Subject: FW: 03-10 --- TecWel LDL found leak in PC @ 39'. Hi Barry and Neil, Dewayne has the great idea to fix this well by pumping down the IA, taking returns to the OA. The well is an injector. The problem with this well is that it doesn't have GLM's, and because the leak is so shallow, sure seems like we could fix it his way. You may recommend using nitrogen down the IA to get to the leak first (actually we may just be able to use artificial lift.) But, if you could please lack at this well, maybe we can get it done in this go round!! We're trying to get a handle on how large the steady stream was mentioned below. «03-10. pdf» Jennifer Julian Senior Wellwork Design Engineer bp, Alaska (907) 564-5663 office (907) 240-8037 cell From: Schnorr, Dewayne R (PRA) Sent: Thursday, November 15, 2007 8:47 AM To: Julian, Jennifer Y Subject: RE: 03-10 --- TecWel LDL found Leak in PC @ 39'. Hi Jennifer. I was the one asking the questions. I was thinking that if we could eliminate the puncher holes, circulating 10#~ brine, and setting a patch by pumping down the IA that would be great. This leak is just below the well head. I will include the WSR from the day that the LDL was run, The TecWel LDL was just run on Tuesday, and we have not seem the log. 2 From digital well files IA x OA comm. IC hanger had sealtite treatment OA Dowgnsgz 12/26/02 & 11/24/03 LDL found leak @ 39' on 11/13/07 > 10/29/06: CMIT-IAxOA by DHD w/triplex Failed on stabilization. LLR-IA=0.8 gpm, LLR-OA=0.6 gpm Planned Actions Obj: Eval for depth of IAxOA leak to plan seal-tite repair 1. E: TecWel LDL - DONE 2. APE: Eval plan forward, consider Seal-Tite to repair IAxOA Comm We able to pump down the OA, and were able to open the leak to the IA. Then we pumped from the IA to OA. A one way leak to start with. Lets talk about this well when you get back. It is an interesting well with a very shallow leak. Thanks DeWayne WELL SERVICE REPORT (WSR) WELL JOB SCOPE UNIT 03-10 LEAK DETECTION LOG SWS 2158 DATE DAILY WORK DAY SUPV 11/13/2007 LEAK DETECTION LOG LYNCH COST CODE PLUS KEY PERSON NIGHT SUPV PBD03WL10-I SWS-PRICE DOSHIER Ron does a great job in getting the information we need ed . DAILY SUMMARY ***CONTINUE AWGRS FROM 12-NOV-07*** WELL SHUT IN ON ARRIVAL: INITIAL WHP: 200/0/0 RAN TECWEL LEAK DETECT LOG FROM SURFACE TO APPROX 3000 FT. PUMPED DOWN IA RETURN DOWN OA INITIALLY, LEAK COULD NOT BE READILY ESTABLSSHED. REVERSED POSITION PUMPING DOWN OA RETURNS TO IA, LEAK FOUND A 39 FT JUST BELOW TREE. ATTEMPT TO PUMP DOWN IA WITH RETURNS TO OA TO VERIFY LEAK FLOW IN BOTH DIRECTIONS. LEAK WAS NOT AS PRONOUNCED PUMPING DOWN IA TAKING RETURNS TO OA. WELL LEFT SHUT IN: FINAL WHP: 170/0/0. ***JOB COMPLETE*** Init Tbg, IA, OA -> 200 0 0 TIME COMMENT 00:00 CONTINUE WAITING FOR LEAK TO ESTABLISH ITSELF. 00:07 BLEED DOWN IA AND PRESSURED IT BACK UP TO 2400 PSI TO TRY AND ESTABLISH LEAK. 00:37 IA PRESSURED UP TO 2400, T AND OA REMAIN UNCHANGED. WAIT FOR IA PRESSURE TO DECREASE. 01:09 IA PRESSURE DID NOT CHANGE. LOG OOH AT 30 FPM LOGGING TECWEL ULTRASONIC LDL 02:55 REACH SURFACE, NO LEAK DETECTED, IA PRESSURE NEVER BLEED OFF. BLEED DOWN IA AND PRESSURED UP TO JUST UNDER 3000 PSI TO ESTABLISH LEAK. 03:22 IA PRESSURED UP TO 2990 PSI. WAIT TO SEE IF PRESSURE BLEEDS DOWN. 04:55 IA PRESSURE DID NOT DECREASE. BLEED IA, PRESSURED UP OA TO 2400, ESTABLISHED LEAK TO THE TA. BEGIN LOGGING TECWELL LDL FROM SURFACE DOWN TO 3000' AT 30 FPM, IO FPM THROUGH RESTRICTIONS. 06:32 REACH 3000', POOH TO LOG ACROSS ANOMALY AT TREE. 07:25 CHANGE OUT WITH NIGHT CREW. 07:48 TOOL NEAR SURFACE, BLED DOWN OA FROM 2260 PSI TO 0 . 08:04 PRESSURE UP IA TO 3000 PSI, T/0=170/0. BEGIN ANOMALY PASS FROM 3 SURFACE LOGGING DOWN 10 FPM 08:18 T/I/0= 17012$50/0. SOLID STREAM OF FLUID REGISTERED BACK TO THE TANK 08:35 LEAK NOT AS PRONOUNCED AS SEEN WHEN PUMPING DOWN OA TAKING RETURNS DOWN IA. PE'S NOTIFIED OF RESULTS. 08:38 PE WILL TALK WITH APE AND CALL BACK 08;43 PE CALLS BACK INSTRUCTING CREW TO RD . 09:55 IA PRESSURE BLED DOWN TO 0. BEGIN RD E-LINE 10:30 RD COMPLETE, PERMIT CLOSED, CREW DEPARTURE Final Tbg, IA, OA -> 170 0 0 FLUID SUMMARY 1 BBL DIESEL TO PT WHE UNABLE TO DETERMINE HOW MUCH 60!40 METH WAS PUMPED DURING LOGGING PROCEDURES. CREW PUMPED WITH TRI-PLEX. 4 . . ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer. PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 November 27, 2006 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. yth Ave. Anchorage, Alaska 99501 RECEIVED DEe 0 4 2006 A/aska ai/ & Gas C AnChor:;:- Commission Subject: 03-10 (PTD #1790210) Application for Cancellation of Sundry #304-016 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 304-016 for Prudhoe Bay well 03-10. The sundry was for continued water injection with IAxOA communication. Combination MIT's of the IA and OA no longer pass. The well will remain shut-in while being evaluated for repair. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. :J~~ ".¡-.... ,.ut.: -. :L'~"';,i\::; '~~~~.~l~ I;)' Anna Dube, P.E. Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 l' & ~A · "1. Operations Performed: -.'~_I AbandonD Repair WellD Plug PerforationsO Stimulate D A~ 1'0- . !f.' , Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time Extension < Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 179-0210 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceŒ 50-029-20361-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 03-10 8. Property Designation: 10. Field/Pool(s): ADL-028328 Prudhoe Bay Field / Prudhoe Bay Pool .' 11. Present Well Condition Summary: · Total Depth measured 9780 feet .. true vertical 9246.3 feet Plugs (measured) None Effective Depth measured 9732 feet Junk (measured) None true vertical 9198.3 feet " ~- i Casing Length TVD Burst Collapse " Size MD . 520 CONDUCTOR 82 20" 94# H-40 30 - 112 30.0 - 112.0 1530 · SURFACE 2701 13-3/8" 72# L-80 30 - 2730 30.0 - 2730.0 4930 2670 ....PRODUCTION 3166 9-5/8" 47# 500-95 27 - 3193 27.0 - 3193.0 8150 5080 E'R0DUCTION 5874 9-5/8" 47# L-80 3193 - 9067 3193.0 - 8533.0 6870 4760 '_,t~ LINER 1030 7" 29# L-80 8745 - 9775 8212.0 - 9241.0 8160 7020 .... Perforation depth: 1'-. Measured depth: 9213-9236,9240-9290,9406-9440,9460-9474, 9500-9512, 9533-9555, 9560-9576 ., True vertical depth: 8679-8702,8706-8756,8872-8906,8926-8940, 8966-8978, 8999-9021, 9026-9042 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 27 - 8369 4-1/2" 12.6# L-80 @ 8369 - 8474 7-5/8" 29.7# NT-80S @ 8474 - 8996 5-1/2" 17# L-80 @ 8498 - 8566 .' 4-1/2" 12.6# L-80 @ 8566 - 8848 4-112" 12.6# L-80 @ 9310 - 9343 Isolation Assembly 4-1/2" 12.6# L-80 @ 9453 - 9528 Isolation Assembly 3-1/2" 9.3# L-80 @ 9528 - 9530 Isolation Assembly Packers & SSSV (type & measured depth): 9-5/8" Baker SB-3 Perm PKR @ 8427 9-5/8" Otis RH Packer @ 8561 7" Otis WD Packer @ 9310 7" Otis WD Packer @ 9453 7" Otis WD Packer @ 9520 tPP·. 7" Otis MBR SSV @ 2163 .' ti~: Stimulation or cement squeeze summary: · Intervals treated (measured): RBDMS 8ft DEC () {} 2006 Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaoe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -- -- 20821 80 1435 Subsequent to operation: -- --- 0 --- 1792 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service[! '. Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilD GasD WAGD GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: ~"mct A~ 304-016 Title Petroleum Engineer p,;ot'" Nam' . r>t tlj\¡-, E Phone 564-5174 Date 11/15/06 Signature '-- ~ [. ~. .~.~. . ., ,,- of> ( } J.< I (~ I [\1 Lll . STATE OF ALASKA. RECI2I\/~D ALASKA OIL AND GAS CONSERVATION COMMISSION DEC c, REPORT OF SUNDRY WELL OPERATION&o1 04 2Ú0) On VJ IV ~L IV ,,-1/lJÚ2lU) Cancel Waiver . . Hello All, The waiver for well 03-10 (PTD #1790210) has been cancelled and the well classified as a Trouble well. Due to a failing CMIT-IAxOA, the well no longer meets the waiver requirements. Tom/Jim/Winton: We will submit a letter canceling Sundry #304-016. Lead Operator: Please ensure all waiver-related information is removed from the well house. Please call with any questions. Thank you, Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 .. 1 of 1 10/31/20062:02 PM RE: 03-10 (PTD # 179021 0), 04-08 (PTD # leO), R-25A (PTD .., . IAxOA leak. We occasionally see pressure increases in adjacent annuli from ballooning, particularly when testing with MI injection pressure, but not to this extent. Please review the test data and provide an explanation of the pressure increase. Pressure data during the MI injection following this 2003 MIT or covering a WAG cycle since that time would be useful, along with any information you may have about well work, etc. ~:':GI\ \,,~I ~," t::n \,...".., h"'~"" ( r C\/o~\ \\ 0-1:7/\0 Jim Regg AOGCC Hughes, Andrea wrote: Winton, Jim and Bob, Please see the attached MIT forms for the following wells: PBU 03-10: CMIT-IAxOA for Waiver compliance PBU 04-08: MITIA to evaluate the well for an IAxOA AA and waiver PBU R-25A: MITIA Pre-dewatering PBU 04-13: MITIA Pre MI swap PBU P1-25: MITIA Pre MI swap PBU S-101: MITIA Pre MI swap PBU NK-13: MITIA for UIC Compliance, Chuck Scheve witnessed The MIT form for PBU X-36 (PTD #1961670) was emailed by Anna Dubs on 9/10/06. If you need an additional copy or did not receive the email, I will gladly send it again. Thank you for your patience. «MIT PBU 5-101 11-23-03.xls» «MIT GPMA P1-25 09-06-06.xls» «MIT PBU 04-13 08-10-03.xls» «MIT PBU 04-08 08-04-05.xls» «MIT PBU R-25A 06-12-05.xls» «MIT PBU 03-10 09-30-05.><Is» «MIT PBU NK-13 09-19-06.xls» Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Hi Jim, Thank you for the note. To update you on MITs that are past due: 1) PBU 04-13; due 1/8/2006 Completed 8/10/03 2) PBU S-101; due 2/25/2006 Completed 11/23/03 3) PBU NK -13 ; due 5/4/2006 Completed 9/19/06 4) PBU X-36; due 5/20/2006 Completed 9/5/06 - Sent in earlier e-mail 5 ) PBU R-25A; due 7/24/2006 Completed 6/12/05 20f4 10/2/2006 9:23 AM RE: 03-10 (PTD #1790210),04-08 (PTD #17.0), R-25A (PTD ... . We agree to schedule MITs on the following wells once on injection: 1) MPU H-06; due 2/28/2006 (SI since 7/2002) Schedule when returned to injection 2) PBU WGI-01; due 4/22/2006 (SI since 12/12/2005) Schedule post Rig Sidetrack later this year 3) MPU F-4l; due 5/14/2006 (SI since 5/2005) Schedule when returned to injection 4) PBU S-31A; due 6/1/2006 (SI since 12/2004) Schedule post Rig Workover 5) PBU P1-01; due 6/4/2006 (SI since 6/2006 for workover) A patch to restore integrity is planned. Scheduel when returned to injection 6) PBU Pl-25; due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C; due 7/22/2006 (SI since 4/2006) returned to injection, estimated some time in '07. Completed 9/6/06 Schedule when Others 1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; MITs (IA and OA) done per monthly injector rpt; date unknown- this well is currently 31 with an AA and Waiver being drafted. I apologize for this office dropping the ball on these wells. Thank you for your patience in this matter, Ron Wilson WI Tech 659-5524 ------------------------------ We have recently completed a mid year review of MIT data from our inspection database to see how many injection wells may be in question regarding MIT timing. Results of our review relating to BP-operated fields are as follows: MITs are past due for the following wells (injecting as of 7/31/2006) 1) PBU 04-13; due 1/8/2006 2) PBU S-101; due 2/25/2006 3) PBU NK-13; due 5/4/2006 4) PBU X-36; due 5/20/2006 5) PBU R-25A; due 7/24/2006 The following shut in wells are past their due date for MIT 1) MPU H-06; due 2/28/2006 (SI since 7/2002) 2) PBU WGI-01; due 4/22/2006 (SI since 12/12/2005) 3) MPU F-4l; due 5/14/2006 (SI since 5/2005) 4) PBU S-31A; due 6/1/2006 (SI since 12/2004) 5) PBU P1-01; due 6/4/2006 (SI since 6/2006 for workover) 6) PBU Pl-25; due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C; due 7/22/2006 (SI since 4/2006) A MIT for each well injecting on the list should be conducted as soon as 30f4 10/212006 9:23 AM RE: 03-10 (PTD #1790210),04-08 (PTD #17.0), R-25A (PTD ... . practical; please notify the Commission for an opportunity to witness. Regarding SI injectors, the Commission suggests deferring testing (at least the Commission's witnessed test) until injection is recommenced and well conditions have stabilized. There's also two wells with MITs that have apparently been done (not witnessed) that we would like to have for our database: 1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; MITs (IA and OA) done per monthly injector rpt; date unknown As with all operating companies, the Commission is willing to work with you to take advantage of operating efficiencies in scheduling MITs (perform multiple MITs per pad; perform tests during the more temperate months; etc.). Feel free to call if you have any questions, and thank you in advance for your prompt attention to those MITs that are past due. Jim Regg AOGCC Content-Description: 04-13 TIO Plot.ZIP 04-13 TIO Plot. ZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 Content-Description: 04-13 Injection Plot.ZIP 04-13 Injection Plot.ZIP Content-Type: applicationlx-zip-compressed Content-Encoding: base64 4 of 4 1012/2006 9:23 AM - ,,- .. - . , ~~..--~.-\- '-""/.., D4¡c: ~'---', Winton, Jim and Bob, Please see the attached MIT forms for the following wells: ,/ PBU 03-10: CM!T-!AxOA for Waiver compliance " 2CD~) , PBU 04-08: MITIA to evaluate the well for an IAxOA AA and waiver ,,/PBU R-25A: M!TIA Pre-dewatering G ~Z¡ 2..:':5' " , ;./PBU 04-13: MITIA Pre M! swap ?i¡ ';,1 i':¿<; 'J ,,/PBU P1-25: MITIA Pre M! swap (t (¡;; , r'ti $5 /PBU S-101: MITIA Pre M! swap 1\l'23Izc'-3: 5'> t/PBU NK-13: MITIA for UIC Compliance, Chuck Schéve witnessed .3 ::>J SCANNEr) SEP 2 92DD5 '~i Z~.\Æ. 1 )' /'The MIT form for PBU X-36 (PTO #1961670) was emailed by Anna Oube on 9/10106. If you need an additional copy or did not receive the email, ! will gladly send it again. "- Thank you for your patience. «MIT PBU S-101 11-23-03.xls» «MIT GPMA P1-25 09-06-06.xls» «MIT PBU 04-13 08-10-03.x!s» «MIT PBU 04-08 08-04-05.xls» «MIT PBU R-25A 06-12-05.xls» «MIT PBU 03-10 09-30-05.xls» «MIT PBU NK-13 09-19-06.x!s» Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Hi Jim, Thank you for the note. To update you on MITs that are _ 1) PBU 04-13¡ due 1/8/2006 ,2) PBU S-101¡ due 2/25/2006 3) PBU NK-13¡ due 5/4/2006 /4) PBU X-36¡ due 5/20/2006 5) PBU R-25A¡ due 7/24/2006 past due: Completed Completed Completed Completed Completed 8/10/03 11/23/03 9/9/06 9/5/06 - 6/12/05 Sent in earlier e-mail We agree to schedule MITs on the following wells once on injection: 10f4 9/25/20069:15 AM ~~ ,~\...-,,-_ ~'f'-'''''''Vl'V' V"'\......L..J'" .,vv'.~~~,.\. '~"'/.,. . Schedule when Schedule post Rig Schedule when Schedule post Rig 1) MPU H-06¡ due 2/28/2006 (SI since 7/2002) returned to injection / 2) PBU WGI-01¡ due 4/22/2006 (SI since 12/12/2005) Sidetrack later this year 3) MPU F-41¡ due 5/14/2006 (SI since 5/2005) returned to injection 4) PBU S-31A¡ due 6/1/2006 (SI since 12/2004) Workover 5) PBU P1-01¡ due 6/4/2006 (SI since 6/2006 for workover) A patch to restore integrity is planned. Scheduel when returned to injection ~/ 6) PBU Pl-25 ¡ due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C¡ due 7/22/2006 (SI since 4/2006) returned to injection, estimated some time in '07. Completed 9/6/06 Schedule when Others /1) PBU 03-10¡ MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08¡ MITs (IA and OA) doneper monthly injector rpt¡ date unknown- v this well is currently SI with an AA and Waiver being drafted. I apologize for this office dropping the ball on these wells. Thank you for your patience in this matter, Ron Wilson WI Tech 659-5524 ------------------------------ We have recently completed a mid year review of MIT data from our inspection database to see how many injection wells may be in question regarding MIT timing. Results of our review relating to BP-operated fields are as follows: MITs are past due for the following wells (injecting as of 7/31/2006) 1) PBU 04-13¡ due 1/8/2006 2) PBU S-101¡ due 2/25/2006 3) PBU NK-13¡ due 5/4/2006 4) PBU X-36¡ due 5/20/2006 5) PBU R-25A¡ due 7/24/2006 The following shut in wells are past their due date for MIT 1) MPU H-06¡ due 2/28/2006 (SI since 7/2002) 2) PBU WGI-01¡ due 4/22/2006 (SI since 12/12/2005) 3) MPU F-41¡ due 5/14/2006 (SI since 5/2005) 4) PBU S-31A¡ due 6/1/2006 (SI since 12/2004) 5) PBU P1-01¡ due 6/4/2006 (SI since 6/2006 for workover) 6) PBU Pl-25¡ due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C¡ due 7/22/2006 (SI since 4/2006) A MIT for each well injecting on the list should be conducted as soon as practical¡ please notify the Commission for an opportunity to witness. Regarding SI injectors, the Commission suggests deferring testing (at least 20f4 9/25/2006 9: 15 AM .~\'.- "j~~'~hv. VV\"~ "Vv'.~~.Jn\. '~'''/... . the Commission's witnessed test) until injection is recommenced and well conditions have stabilized. There's also two wells with MITs that have apparently been done (not witnessed) that we would like to have for our database: 1) PBU 03-10¡ MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08¡ MITs (IA and OA) done per monthly injector rpt¡ date unknown As with all operating companies, the Commission is willing to work with you to take advantage of operating efficiencies in scheduling MITs (perform multiple MITs per pad¡ perform tests during the more temperate months¡ etc.). Feel free to call if you have any questions, and thank you in advance for your prompt attention to those MITs that are past due. Jim Regg AOGCC Content-Description: MIT PBU 8-101 11-23-03.xls MIT PBU 8-101 11-23-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT GPMA PI-25 09-06-06.xls MIT GPMA PI-2S 09-06-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-13 08-1O-03.xls MIT PBU 04-13 08-10-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-08 08-04-05.xls MIT PBU 04-08 08-04-0S.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU R-25A 06-12-05.xls MIT PBU R-2SA 06-12-0S.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 30f4 9/25/20069:15 AM V~ 'V\' ,~",,/v~,vhV~-VV\' ''-'''''VV'W'''-':''.Jn.\l ,,-,rT1J... . Content-Description: MIT PBU 03-10 09-30-05.xls MIT PBU 03-10 09-30-0S.xIs Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU NK-13 09-19-06.xls MIT PBU NK-13 09-19-06.xIs Content-Type: application/vnd.ms-excel Content-Encoding: base64 4 of 4 9/25/2006 9: 15 AM . . .~ .. q \z.-.;\O(o \ <...,(2trl Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OS 03 09/30/05 Anna Oube Packer Depth Pretest Initial 15 Min. 30 Min. We1l103-10 I Type Inj. I W TVD I 7,895' Tubing 1,480 1 ,480 1 ,480 1,4801 Interval I 0 p.T.D.11790210 I Typetest P Test psi11973.75 Casing 2,500 2,480 2,4801 P/FI P Notes: CMIT-IAxOA for revised waiver. OA 0 2500 2480 2480 I Weill I Type Inj. I I TVD Tubing Interval I P.T.D.I I Type test I I Test psi Casing P/FI Notes: OA Weill Type Inj.) ) TVD I Tubing Interval I P.T.D. I Type test I Test psi Casing P/F Notes: OA Weill I Type Inj.1 I TVD I Tubing I Interval I P.T.D.I I Type test( I Test psil Casing I P/F! Notes: OA I Weill Type Inj.1 TVD I Tubing Interval P.T.D.I I Type test I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = other (describe in notes} 2005·0930_MIT _PBU_ 03·1 O.xls STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend D Repair WellŒJ Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 179-0210 Name: BP Exploration (Alaska), Inc. Development D ExploratorvD Service ŒJ 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Stratigraphic D 9. Well Name and Number: 03-10 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 64.00 8. Property Designation: ADL-0028328 11. Present Well Condition Summary: Total Depth measured 9780 feet Effective Depth true vertical 9246.3 feet measured 9732 feet true vertical 9198.3 feet Plugs (measured) Junk (measured) None None OtherD 6. API Number 50-029-20361-00-00 Casing Length Size MD TVD Conductor 82 20" 94# H-40 30 112 30.0 112.0 Liner 68 5-1/2" 17# L-80 8498 - 8566 7965.5 - 8033.2 Liner 283 4-112" 12.6# L-80 8566 - 8849 8033.2 - 8315.6 Liner 1030 7" 29# L-80 8745 - 9775 8211.7 - 9241.3 Liner 34 4-1/2" 12.6# L-80 9310 - 9344 8776.3 - 8810.3 Liner 78 4-112" 12.6# L-80 9453 - 9531 8919.3 - 8997.3 Production 3166 9-5/8" 47# SOO-95 27 - 3193 27.0 - 3192.9 Production 5874 9-5/8" 47# L-80 3193 - 9067 3192.9 - 8533.4 Surface 2701 13-3/8" 72# L-80 30 - 2731 30.0 - 2731.0 Measured depth: 9213 - 9216, 9216 - 9236, 9240 - 9249, 9249 - 9252, 9252 - 9256, 9256 - 9266 9266 - 9272, 9272 - 9290, 9406 - 9425, 9425 - 9440, 9533 - 9555, 9560 - 9576 True vertical depth: 8679.33 - 8682.33, 8682.33 - 8702.32, 8706.32 - 8715.32, 8715.32 - 8718.32, 8718.32 - 8722.32, 8722.32 - 8732.32 8732.32 - 8738.32, 8738.32 - 8756.32, 8872.32 - 8891.32, 8891.32 - 8906.32, 8999.32 - 9021.32, 9026.32 - 9042.32 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 27 - 8360 ;:":'i'¡'1t~":" l '" l..., ~ ~~~~ 4-1/2" 12.6# L-80 @ 8360 - 8476£ \ ~..,,,. "", r~ :~ 'I."" 7-5/8" 29.7# N-80 @ 8476 8496 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 8427 4-1/2" Otis WD Packer @ 9310 4-1/2" Otis WD Packer @ 9453 4-1/2" Otis WD Packer @ 9520 5-1/2" Otis RH Packer @ 8561 7" Otis MBR SSV @ 2163 Burst 1530 7740 8430 8160 8430 8430 8150 6870 4930 MAR 1 0 200i Collapse 520 6280 7500 7020 7500 7500 5080 4760 2670 Þib~'i""ka Oq H~ Gas Cons j~ nrh(¡f ":!f:¡," 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1530' - 2219' Treatment descriptions including volumes used and final pressure: 69.2 bbls arctic set 1 cement with 1/4# per sack of cello flake @ 640 psig Reoresentative Dailv Averaae Production or Iniection Data IØ)MS 8ft 13 Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure Tubing Pressure 0 0 26144 640 1607 0 0 6296 260 1121 16. Well Status after'þroposed work: Operational Shutdown D OilD GasD WAG D GINJD WINJ[&] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 303-338 14. Attachments: 15. Well Class after proposed work: Exploratory D Copies of Logs and Surveys run - Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ~. 2 2004 DevelopmentD Service ŒI Phone 564-4657 Production Technical Assistant Date 3/9/04 Title Signature t' Form 10-404 Revise OR\G\ 03-'0 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/21/03 T/I/O= 1790/620/850. TEMP=HOT. LOAD OA. (PREP FOR OA DOWN SQUEEZE). LOAD OA WITH 110 BBLS CRUDE. FINAL WHP'S=1790/640/850. 11/24/03 T/I/O = 700/640/680. Well is SI. OA Down Squeeze. MIRU Dowell to OA and LRS to IA. Held PJSM. PT Lines to 3000 psi. LRS will be holding 1500 psi on IA. Start dwon OA with 10 bbls methanol, followed by 20 bbls DC101 surfactant, 200 bbls fresh water, 15 bbls DC101 surfactant, 5 bbls fresh water spacer at 6.9 BPM. Pumped 69.2 bbls arctic set 1 cement with 1/4# per sack of celloflake, 5 bbl fresh water spacer at 2.5 BPM. Displace cement with 70 bbls of crude at 6.7 BPM, cut rate to 1.0 BPM for 5 bbls, Then dropped the rate to .5 BPM for the last 5 bbls. The total displacement is 80 bbls. OAP slowly increased during the last 10 bbls of crude from 650 psi to 850 psi (Pump pressure). SD and monitor OAP for 15 minutes. OAP slowly decreased from 640 to 500 psi. Estimated cement top @ 15301 RDMOL. Final WHp1s = 525/700/500. 11/27/03 TIO= 1780/1150/1170. TEMP= HOT. MIT-OA INCONCLUSIVE. (POST OA DOWNSQUEEZE). OA FL NEAR SURFACE. BLED OA FROM 1170 PSI TO 400 PSI. BLED GAS & FLUID. lAP DROPPED FROM 1150 PSI TO 1000 PSI. PUMPED 5 BBLS DIESEL IN OA TO 2400 PSI. 1ST TEST: FIRST 15 MIN LOSS 80 PSI, 2ND 15 MIN LOSS 60 PSI, TOTAL LOSS IN 30 MIN 140 PSI. 2ND TEST: 1ST 15 LOSS 60 PSI, 2ND 15 MIN LOSS 80 PSI, TOTAL LOSS IN 30 MIN 140 PSI. 3RD TEST: FIRST 15 MIN LOSS 60 PSI, 2ND 15 MIN LOSS 60 PSI, TOTAL LOSS IN 30 MIN 120 PSI. DURING THE MIT-OA THE IA PRESSURE STEADILY INCREASED STARTING @ 1000 PSI INCREASING TO 1240 PSI. BLED OAP DOWN TO 50 PSI, lAP DROPPED TO 800 PSI. NOTICE OAP STARTED INCREASING, MONITOR PRESSURES FOR 1 HR. FINAL WHP'S 1780/760/720. 11/28/03 TIO= 1400/700/700. MONITOR WHP'S. (POST MITOA). lAP DECREASED 60 PSI AND THE OAP DECREASED 20 PSI FROM YESTERDAY. 11/29/03 T/I/O=1400/520/520 CMITIAXOA PASSED TO 2400 PSI. (POST OA DOWN SQUEEZE). IA FL @ SURFACE, OA FL @ SURFACE. PRESSURED UP IA TO 2400 PSI WITH 3.5 BBLS OF METHANOL OAP TRACKED TO 2400 PSI. STARTED TEST, LOST 40 PSI IN THE FIRST 15 MINS ON THE IA AND OA. LOST 15 PSI IN NEXT 15 MINS ON THE IA AND GA, FOR A TOTAL OF 55 PSI. BLED IA AND OA TO 240 PSI. MONITORED WHP'S FOR 30 MINS, IA & OA INCREASED 20 PSI. FINAL WHP'S 1400/260/260. 11/30/03 T/IIO = 1220/260/260, TEMP = HOT. MONITOR WHPS POST-CMIT IAXOA. WHPS UNCHANGED OVERNIGHT. FLUIDS PUMPED BBLS 190 Crude 5 Diesel 35 DC101 Surfactant 210 Fresh Water 69 Arctic Set 1 Cement wI 1/4# per sack Celloflake 16 Methonal 525 TOTAL Page 1 TREE = FMCGEN 1 WELLHEAD = CW ACfUA. TOR = BAKER C KB. ELEV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' DatumTVD = 8800' SS ESllMA TED CMf TOP 13-318" CSG, 72#, L-80, ID = 12.347" TOP OF 4-1/2" TBG 4-1/2"TBG,12.6#,L-80,.0152bpf,ID=3.958" H 8475' ITOPOF7-5/8"TBG H 8475' 7-5/8" lBG, 29.7#, NT-80S, .0459 bpf, ID = 6.875" M in imum ID = .875" @ 9332' CHOKE IN X NIPPLE 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I ITOPOF4-1/2"TBG-PC I ¡TOP OF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ( 19-5/8" CSG, 47#, N-80, ID = 8.681" I 9343' 9453' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I I TOP OF 4-1/2" TBG I PERFORA 1l0N SUMMA RY REF LOG: BI-CS ON 08/31/79 ANGLEATTOP ÆRF: 2 @ 9213' Note: Refer to Production DB for historieal perf data SIZE I SPF I INlERV A L IOpn/Sqzl DATE SEEPAGE2 FOR PERFORATION DATA 4-112" lBG-PC, 12.6#, L-80, .0152 bpf, ID =3.958" ?' LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9780' 03-1 0 SAFETY NOTES: *-RAPID IAxOA COMM. OPER LIMITS: MAX lAP = 2000 PSI, MAX OAP = 2000 PSI (12105/03 W AlVffi) - NOTE: PWI ONLY/NO MIINJ ALLOWED*** 8474' 8498' DATE REV BY CO I\t1MENTS DAlE REV BY COMrvENTS 09/07/79 ORIGINAL COM PLETION 04104/93 LAST WORKOVffi 01/05/02 RNlTP CORRECTIONS 02/09/03 A TD/TP DELETE WAIVER SA FETY NOTE 12120/03 JLA/PAG W AIV ER SA FEfY NOTE 12/03 KCF/TLP ESllMA TED CMf TOP 7" OTIS MRB SL VN, ID = 5.963" 7" X 4-1/2" XO 4-112" FRKR SWS NIP, ID= 3.813" 9-518" X4-1/2" BKR SB-3 PERM PKR 4-112" FRKR SWS NIP, ID = 3.813" 4-112" X 7-5/8" XO 5-112" lBG SlUB FLARED TO 6-1/2" 5-112" OTIS SBR ASSY 5-112" X 4-1/2" XO I 4-112" OTIS X NIP, ID = 3.813" -1 4-112"TTWLEG I 1--1 EUvÐ TT LOGGED 09/18/86 1 7" X 4-1/2" 01lS WD A<R 4-112" OTIS X NIPW/7/8" DOWNHOLE CHOKE(4-1/2"X LOO<) , ID =3.813" -1 4-112" TTL WLEG I -i 7" X 4-1/2" OTIS WD A<R I --1 4-112"AVABA..NIP,ID=3]'W/BA I -i 7" X 4-1/2" 01lS WD A<R I PRLDI-DE BAY LNIT WELL: 03-10 PERMIf t\b: 1790210 AA t\b: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FEL & 1360.22' FNL BP Exploration (Alaska) TREE = Ftv'C GEN 1 W8...LI.EAD = CroN A crUA TOR = SA KER C KB. ELEV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS ÆRFORA TlON SUMMA.RY REF LOG: BI-CS ON 08131/79 ANGLEA TTOP PffiF: 2 @ 9213' Note: Refer to Produetion DB for historieal perf data SIZE SFF INTERV A L Opn/Sqz DATE 3-1/8" 4 09188 - 09208 S 12/01/89 3-3/8" 4 09213 - 09236 0 06/04/92 3-3/8" 4 09240 - 09290 0 02/25/96 3-1/8" 4 09290 - 09292 S 12/01/89 3-1/8" 4 09354 - 09394 S 12/01/89 3-3/8" 2 09406 - 09440 0 07/07/92 3-3/8" 4 09440 - 09450 S 12/01/89 ? 4 09460 - 09474 0 07/24/86 ? 4 09500 - 09512 0 07/24/86 ? 4 09533 - 09555 0 07/24/86 ? 4 09560 - 09576 0 07/24/86 03-10 (f) DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COMPLETION 04104193 LAST WORKOVER 01/05/02 RN/lP CORRECTIONS 02/09/03 ATDIfP 08... ETE WA IV ER SAFElY NOTE 12/20/03 JLA/PAG WAIVER SAFETY NOTE 1 2/03 KCF/TLP ESTIMA. TBJ CMT TOP PRUDHOE BAY UNrr WB..L: 03-10 ÆRMlT No: 1790210 API No: 50-029-20361-00 SEe 11, T10N, R15E, 3871.19'FEL& 1360.22' FNL BP Exploration (Alaska) ( MEMORANDUM ( State of Alaska From: John Spaulding Petroleum Inspector Alaska Oil and Gas Conservation Commission TO: Jim Regg \2-J244: I(Zb\O4- DATE: January 15,2004 P.I. Supervisor l SUBJECT: Mechanical Integrity Tests BPXA OS-03 10-Mar Prudhoe Bay Unit Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 03-10 Type Inj. S TV.D. 7894 Tubing 1400 1400 1400 1400 Interval 4 P.T.D. 1790210 Type test P Test psi 1974 Casing pas 2500 2490 2420 P/F P Notes: CMIT OA 40 2500 2420 2430 Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details M.I.T.'s performed: 1 Attachments: none Number of Failures: .Q Total Time during tests: 1 HR. cc: none MIT report form 5/12/00 loG. mit pbu 03-10 1-15-04 jhs.xls 1/20/2004 ( (' BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 19661 2 Anchorage, Alaska 99519-6612 January 13, 2004 Mr. Winton Aubert, P. E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 03-10i (PTD 1790210) Application for cancellation of sundry #303-012 and application for Sundry Approval for PWI with rapid IA x OA communication. Dear Mr. Aubert: Attached is both an Application for Sundry Cancellation form 10-404 to cancel sundry number 303-012 and an Application for Sundry form 10-403 for well 03-10. Form 10-404 is to cancel sundry 303-012, which gave BP permission to resume injection into 03-10 with a 2 year MITIA frequency. This sundry is being cancelled because the IA x OA communication at 03-10 has become stronger over the past year and the well now requires a CMIT IA x OA to confirm tubing and packer integrity (formerly, the well would pass a standard MITIA). The attached Form 10-403 is for approval to continue injection into a water injection well with rapid IA x OA communication (Le. MITIA fails, but CMIT IA x OA passes). If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. RECEIVED JAN 1 6 2004 Alaska Oil & Gas Cons, Commission Anchorage 5 Attachments Application for Sundry Cancellation form 10-404 Application for Sundry form 10-403 Description Summary of Proposal MIT form Wellbore Schematic 1';'((" /'\I.I\\!¡IR..~(c.~lr II»~ ¡~.fI ~~ iì\ ')00 ~ eJl\\"v1r'Î\1;:J/I'\:If..:: .,.... ~jAli\ll ((.~ Iu ([ fiJ' 'vJ Q A- , I z,o /2-0 otj- ( STATE OF ALASKA ( D'JS. I J2.ol 1- ALASKA OIL AND GAS CONSERVATION COMMISSION <6P I J 1 J APPLICATION FOR SUNDRY APPROVAL ,W 7 20 AAC 25.280 1. Type of Request: 0 Suspend 0 Operation Shutdown 0 Abandon Alter Casinç¡ 0 Repair Well 0 Pluç¡ Perforations 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 PerforateD StimulateD WaiverŒ] Time Extension 0 OtherD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development 0 Re-enter Suspended WeliD 5. Permit to Drill Number: 179-0210 r 2. Operator Name: 4. Current Well Class: BP Exploration (Alaska), Inc. Exploratory CJ 64.00 KB 8. Property Designation: ADL-0028328 StratigraphicD Service [X] 9. Well Name and Number: 03-10/ 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9246.3 9732 9134.3 Size MD TVD 6. API Number / 50-029-20361-00-00 11. Total Depth MD (ft): 9780 Casing Length Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom See Attachment Pe~oration Depth MD (ft): 'See Attachment Perforation Depth TVD (ft): See Attachment Tubing Size: Tubing Grade: 7 " 26 # L-80 4.5 " 12.6 # 7-5/8 " 29.7 # Packers and SSSV MD (ft): Tubing MD (ft): 27 8360 8476 8360 8476 8496 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Otis WD Packer 4-1/2" Otis WD Packer 4-112" Otis WD Packer 5-1/2" Otis RH Packer 7" Otis MBR SSV 12. Attachments: Description Summary of Proposal ŒI Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Cömmencin 0 eration: 8427 8561 9310 9453 9520 2163 16. Verbal Approval: , Commission Representative: 17. I hereby certify that the foregoing is true a d orrect to the best of my knowledge. Date: 13. Well Class after proposed work: Exploratory 0 DevelopmentD 15. Well Status after proposed work: OilD GasD WAG D GINJD Service 00 January 13, 2004 PluggedD AbandonedD WINJ ŒI WDSPLD Perpared by Garry Catron 564-4657. Contact John Cubbon Printed Name Title Signature Phone Wellinte rity Corrdinator 659-5102 1/13/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /, / :ó .- ¿) ,f¿:J Plug Integrity D BOP TestD Mechanciallntegrity TestD Location Clearance D :r~: ~t- (.AJ ~~ ",,-1'1' p~ý~... W'- ~rr r A '/. OÅ e.¡lvï f-wv tpRrr.. JA N 1 6 2004 Other: <; ..X ~ t /'1M "- {h~ ~ ut "f' Ac.:..1 ~ '1 u it;",... v"I.-11"'" «AAJ )" N' ~~MlP~ ~ Gas Cons. Commission Subsequent Form Required: Ol (;, NWr 1:18 S~ER OF Anchorage Approved by: THE COMMISSION Date: I ~1l-OC SUBMIT IN DUPLICATE ( \ (' 03-10 Description Summary of Proposal 01/13/04 Problem: Produced Water Injector with Rapid IA x OA communication Well History and Status: Well 03-10 (PTD 1790210) has been found to have rapid IA x OA communication. /' Mechanical integrity tests indicate competent tubing, packer, and surface casing. Recent Well Events: / >- 07/10/03: MITIA to 2500 psi - Pail. LLR-IA 0.68 gpm @ 2500 psi >- 11/29/03: CMIT-IAxOA Passed to 2400 psi 0'/ This Sundry request is to allow for continued water injection in this well. The following supports the request: . A CMIT IA x OA passed to 2400 psi on 11/29/03, indicating competent / tubing, packer, and surface casing. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a tubing, packer, or surface casing leak. Proposed action plan: 1. Allow well to continue Water injection. 2. Cancel existing Sundry (#303-012). / 3. Record wellhead pressures and injection rates daily. 4. Perform 2-year CMIT IA x GA. / ,'.- 5. Sto '11j'ec ion and notify the AOGCC if there is an indication of a loss of <'"""'\ . ncasing integrity. "".," II '^-~\ ~~¡\- (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ( 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Name: BP Exploration (Alaska), Inc. Development D Stratigraphic 0 9. Well Name and Number: 03-10 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Perforate 0 WaiverD Stimulate 0 Time Extension D Re-enter Suspended WeliD Cancel Sundry 5. Permit to Drill Number: 179-021 0 Other[K] 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. .KB Elevation (ft): Exploratory 0 Service ŒJ 6. API Number 50-029-20361-00-00 64.00 8. Property Designation: ADL-028328 11. Present Well Condition Summary: Total Depth Effective Depth measured 9780 feet true vertical 9246.3 feet Plugs (measured) None measured 9732 feet Junk (measured) None true vertical 9198.3 feet Length Size MD TVD Burst Collapse 82 20" 94# H-40 30 112 30.0 - 112.0 1530 520 68 5-1/2" 17# L-80 8498 - 8566 7965.5 - 8033.2 7740 6820 283 4-1/2" 12.6# L-80 8566 - 8849 8033.2 - 8315.6 8430 7500 1030 7" 29# L-80 8745 - 9775 8211.7 - 9241.3 8160 7020 34 4-1/2" 12.6# L-80 9310 - 9344 8776.3 - 8810.3 8430 7500 78 4-1/2" 12.6# L-80 9453 - 9531 8919.3 8997.3 8430 7500 3166 9-5/8" 47# SOO-95 27 - 3193 27.0 - 3192.9 8150 5080 5874 9-5/8" 47# L-80 3193 - 9067 3192.9 - 8533.4 6870 4760 2701 13-3/8" 72# L-80 30 - 2731 30.0 - 2731.0 4930 2670 Casing Conductor Liner Liner Liner Liner Liner Production Production " Surface Perforation depth: Measured depth: 9213 - 9216, 9216 - 9236, 9240 - 9249, 9249 - 9252, 9252 - 9256, 9256 - 9266, 9266 - 9272, 9272 - 9290, 9406 - 9425 9425 - 9440, 9533 - 9555, 9560 - 9576 " True vertical depth: 8679.33 - 8682.33,8682.33 - 8702.32,8706.32 - 8715.32,8715.32 - 8718.32,8718.32 - 8722.32,8722.32 - 8732.32 , 8732.32 - 8738.32, 8738.32 - 8756.32, 8872.32 - 8891.32, 8891.32 - 8906.32, 8999.32 - 9021.32, 9026.32 - 9042.32 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 27 8360 4-1/2" 12.6# L-80 @ 8360 8476 7-5/8" 29.7# N-80 @ 8476 8496 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 8427 4-1/2" Otis WD Packer @ 9310 4-1/2" Otis WD Packer @ 9453 4-1/2" Otis WD packer @ 9520 5-112" Otis RH Packer @ 8561 7" Otis MBR SSV @ 2163 RECEIVED JAN 1 6 2004 Alaska Oil & Gas Cons. Commission '12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ' Representative Daily Averaae Production or Injection Data \, Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 14. Attachments: 8JMsBFl Copies of LoQs and Surveys run - JAN 2- ," 15. Well Class after proposed work: ExploratoryD ',nQ4 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG D GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 303-012 DevelopmentD Service ŒJ Daily Report of Well Operations- 17. I hereby certify that the foregoing' t e and correct to the best of my knowledge. Contact Printed Name Signature Form 1 Well Integrity Coordinator ne 659-5102 Date 1/13/04 TREE = FMC GEN 1 (" WELLHEAD = CW A CflN\ TOR = BAKER C KB. 8..EV = 64' BF. ELEV = - ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8BOO'SS ES11MA TED CMf TOP 113-318" CSG, 72#, L-80, 10 = 12.347" ( 7" TBG, 26#, L-BO, .0383 bpf, 10 = 6.276" TOPOF 4-1/2" TBG 4-1/2"TBG,12.6#,L-80,.0152bPf,10=3.958" H TOPOF7-5/8"TBG (--I 17-5/8" TBG, 29.7#, NT-80S, .0459 bpf. 10 = 6.875" I Minimum ID = .875" @ 9332' C HOKE IN X NIPPLE 15-1/2" TBG-PC, 17#, L-BO. .0232 bpf. 10 = 4.892" ( 1 TOP OF 4-1/2" TBG-PC I TOPOF 7" LNR 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9-5/8" eSG, 47#, N-80, 10 = 8.681" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" ITOPOF 4-1/2" TBG I 1530' 8475' 8475' 8496' 8566' 8566' 8745' 8848' 906T 9343' 9453' PERFOAA TlON SUMfv1A.RY REF LOG: BHCS ON 08/31/79 Af\.GLEA TTOP FERF: 2 @ 9213' Note: Refer to Production œ for historical perf data SIZE I SPF I INTERVAL 10pn/Sqzl DATE SEEPAGE2 FOR PERFORATION D.A.TA 14-112" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" I FBTD I 17" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" ( TO ( 9528' 9732' 9775' 9780' ( 03-1 0 SAFElY NOTES: ***RAPID IAxOA COMM. OPER LIMITS: MAX lAP = 2000 PSI, MAX CAP = 2000 PSI (12105/03 W AlV~) - NOTE: PWI ONLY/NO MIINJ ALLOWED*** (8 2163' 8369' 8370' 842T 8453' 8474' 8498' 8536' 8561' 8566' 8804' 8848' 883T 9310' 9332' 9343' 9453' 9502' 951T 9528' 9529' 9530' D.A. T E REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COMPLETION 04/04/93 LAST WORKOVER 01105/02 RN'TP CORRECTIONS 02109/03 A TD/l1=> DELETE WAIVER SAFETY NOTE 12120/03 JLA/PAG W AIV ER SA FRY NOTE 12/03 KCF/TLP ESTIMATED CMf TOP -t 7" OTIS MRB SLVN, 10 = 5.963" I 7" X 4-1/2" XO 4-112" FRKR SWS NIP, 10 = 3.813" 9-518" X 4-1/2" BKR SB-3 PERM PKR 4-112" FRKR SWS NIP. 10= 3.813" 4-112" X 7-5/8" XO -1 5-112" TBG SruB FLARED TO 6-1/2" 1 -I 5-112" OTIS SBR ASSY 1 -f 9-518" X 5-1/2" OTIS RH R<R I -I 5-112" X 4-1/2" XO I 4-112" OTIS X NIP, 10 = 3.813" -I 4-112"TIWLEGI 1-1 EUvD TI LOGGED 09/18/86 1 7" X 4-1/2" OTIS WD R<R 4-112" OTIS X NIPW/7/8" DOWNHOLE CHOKE (4-1/2" X LOO<).IO =3.813" -f 4-112" TILWLEG I -i 7" X 4-1/2" OTIS WD A<R I -I 4-112" AVA BA. NIP, 10 =3.7" W/ BA I -i 7" X 4-1/2" OTIS WD R<R I PRUDHOE BAY UNIT WELL: 03-10 PERMrr I\b: 1790210 AA I\b: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' F8.. & 1360.22' FNL BP Exploration (Alaska) TREE = ( Frv'C GEN 1 WELLH:AD = CIW A crUA TOR = BA KER C KB. ELEV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS FERFOAA llON SU\1MA.RY REF LOG: BHCS ON 08131/79 ANGLE A TTOP PffiF: 2 @ 9213' Note: Refer to Production œ for historical perf data SIZE SFF INTERV A L Opn/Sqz DATE 3-1/8" 4 09188 - 09208 S 12/01/89 3-3/8" 4 09213 - 09236 0 06/04/92 3-3/8" 4 09240 - 09290 0 02/25/96 3-1/8" 4 09290 - 09292 S 12/01/89 3-1/8" 4 09354 - 09394 S 12/01/89 3-3/8" 2 09406 - 09440 0 07/07/92 3-3/8" 4 09440 - 09450 S 12/01/89 ? 4 09460 - 09474 0 07/24/86 ? 4 09500 - 09512 0 07/24/86 ? 4 09533 - 09555 0 07/24/86 ? 4 09560 - 09576 0 07/24/86 0 3-1 0 8> DATE REV BY COMMENTS DATE REV BY co Mrv1ENTS 09/07/79 ORIGINAL COMPLEfION 04104/93 LAST WORKOVER 01/05/02 RN/W CORRECllONS 02/09/03 ATDffP DELETE WA IVER SAFElY NOTE 12/20/03 JLA/PAG WANERSAÆTY NOTE 12/03 KCF/lLP ESTIMA. TED CMT TOP ( PRUDHOE BAY UNrr WELL: 03-10 FERMIT No: 1790210 API No: 50-029-20361-00 SEe 11, T10N, R15E, 3871.19' FEL & 1360.22' FNL BP Exploration (Alaska) ( ( 03-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/03/03 T/I/O:::1780/1520/1520. TEMP=HOT. OA FL @ 1938' OR 113 BBLS. (POST LOAO WITH AIL GAS). 11/05/03 T/I/O=1780/1360/1380. OEPRESS OA Flo (PREP FOR OA OOWN SQUEEZE). TEMP HOT. OA FL @ 1950'. PRESSURED OA FROM 1380 PSI TO 1840 PSI IN 4 HRS. WHILE PRESSUREING OA, lAP INCREASEO TO 1820 PSI. OA FL OROPPED TO 24701. MONITORED WHplS FOR 1 HR, GAP OECREASEO TO 1700 PSI. lAP DECREASED TO 1720 PSI. FINAL WHP'S 1780/1720/1700. 11/06/03 T/I/O= 340/147011470. (PREP FOR OA OOWN SQUEEZE) OA FL @ 2400'. lAP DECREASEO 250 PSI SINCE PREVIOUS OA Y. GAP OECREASEO 230 PSI SINCE PREVIOUS DAY. 11/08/03 TIIIO= 174011250/1250. DEPRESS OA FL (PREP FOR OA OOWN SQUEEZE) OA FL @ 2400'. PRESSURED OA UP FROM 1250 PSI TO 1750 PSI IN 3 HRS. OA FL REMAINED @ 24001. lAP TRACKEO OAP. MONITORED FOR 1 HR. lAP ANO GAP OECREASEO 150 PSI. FINAL WHpIS::: 1740/1600/1600 11/09/03 T/I/O= 178011390/1390. (PRE OA OOWN SQUEEZE) OA FL @ 2400'. TBG PRESSURE INCREASED 40 PSI SINCE PREVIOUS OA Y. lAP AND GAP OECREASED 210 PSI SINCE. PREVIOUS OA Y. 11/17/03 TIIIO= 1600/830/830. TEMP= 145/PWI. BLEED IA AND OA PRESSURES. (SUNDRY). IA FL'S NEAR SURFACE, OA FL @ 18901 (110 BBLS). BLEO IA FROM 830 PSI TO 160 PSI, GOT FLUID TO SURFACE IN 15 MINS. GAP REMAINEO UNCHANGEO DURING lAP BLEED. STARTEO BLEEOING GAP. BLEO GAP FROM 830 PSI TO 740 PSI IN 1 HR AND 30 MINS, ALL GAS. lAP INCREASEO DURING OA BLEEO FROM 160 PSI TO EQUALIZE WITH GAP. lAP THEN CONTINUEO TO TRACK GAP OURING OA BLEED DOWN. FINAL WHP'S = 1700/740/740. 11/21/03 T/I/O= 17901620/850. TEMP=HOT. LOAO GA. (PREP FOR OA OOWN SQUEEZE). LOAD OA WITH 110 BBLS CRUDE. FINAL WHpIS=1790/640/850. 11/24/03 T/I/O = 700/6401680. Well is SI. OA Oown Squeeze. MIRU Oowell to OA and LRS to IA. Held PJSM. PT Lines to 3000 psi. LRS will be holding 1500 psi on IA. Start dwon OA with 10 bbls. methanol, followed by 20 bbls OC101 surfactant, 200 bbls fresh water, 15 bbls OC101 surfactant, 5 bbl~fresh water spacer at 6.9 BPM. Pumped 69.2 bbls arctic set 1 ç~ment with 1/4# per sack of celloflake, 5 bbl fresh water spacer at 2.5 BPM. Oisplace cement with 70 bbls of crude at 6.7 BPM, cut rate to 1.0 BPM for 5 bbls, Then dropped the rate to .5 BPM for the last 5 bbls. The total displacement is 80 bbls. GAP slowly increased during the last 10 bbls of crude from 650 psi to 850 psi (Pump pressure). SD and monitor GAP for 15 minutes. GAP slowly decreased from 640 to 500 psi. Estimated cement top @ 15301 RDMOL. Final WHP's ::: 525/700/500. Page 1 ( \ 03-1 0 OESCRI PTION OF WORK COMPLETED NRWO OPERATIONS 11/27/03 TIO= 1780/1150/1170. TEMP= HOT. MIT-OA INCONCLUSIVE. (POST OA DOWNSQUEEZE). OA FL NEAR SURFACE. BLEO OA FROM 1170 PSI TO 400 PSI. BLEO GAS & FLUIO. lAP OROPPEO FROM 1150 PSI TO 1000 PSI. PUMPEO 5 BBlS DIESEL IN OA TO 2400 PSI. 1 ST TEST: FIRST 15 MIN LOSS 80 PSI, 2NO 15 MIN LOSS 60 PSI, TOTAL lOSS IN 30 MIN 140 PSI. 2ND TEST: 1 ST 15 LOSS 60 PSI, 2ND 15 MIN LOSS 80 PSI, TOTAL LOSS IN 30 MIN 140 PSI. 3RD TEST: FIRST 15 MIN LOSS 60 PSI, 2NO 15 MIN LOSS 60 PSI, TOTAL LOSS IN 30 MIN 120 PSI. DURING THE MIT -OA THE IA PRESSURE STEAOIL Y INCREASED STARTING @ 1000 PSI INCREASING TO 1240 PSI. BLED OAP OOWN TO 50 PSI, lAP DROPPED TO 800 PSI. NOTICE OAP STARTEO INCREASING, MONITOR PRESSURES FOR 1 HR. FINAL WHP'S 1780/7601720. 11/28/03 TIO= 14001700/700. MONITOR WHP'S. (POST MITOA). lAP OECREASED 60 PSI ANO THE OAP OECREASEO 20 PSI FROM YESTERDAY. 11/29/03 T/I/O=1400/520/520 CMITIAXOA PASSED TO 2400 PSI. (POST OA OOWN SQUEEZE). IA FL @ SURFACE, OA FL @ SURFACE. PRESSURED UP IA TO 2400 PSI WITH 3.5 BBlS OF METHANOL OAP TRACKED TO 2400 PSI. STARTED TEST, LOST 40 PSI IN THE FIRST 15 MINS ON THE IA AND OA. LOST 15 PSI IN NEXT 15 MINS ON THE IA AND OA, FOR A TOTAL OF 55 PSI. BLEO IA ANO OA TO 240 PSI. MONITOREO WHP'S FOR 30 MINS, IA & OA INCREASED ~O PSI. FINAL WHP'S 14001260/260. 11/30103 TIIIO = 12201260/260, TEMP = HOT. MONITOR WHPS POST-CMIT IAXOA. WHPS UNCHANGEO OVERNIGHT. FLUIDS PUMPED BBLS 13 Methanal 35 DC101 Surfactant 210 Fresh Water 69.2 Arctic Set 190.' Crude 517.2 TOTAL Page 2 1. Type of Request: 0 Suspend 0 Operation Shutdown 0 Perforate D VarianceD Annular Disposal D Abandon Alter CasinQ 0 Repair Well IXJ PluQ Perforations 0 Stimulate 0 Time ExtensionD OtherD ChanQe Approved ProQram 0 Pull TubinQ 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 179-0210 Development D Exploratory CJ 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D Service [K] 50-029-20361-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 KB 03-10 8. Property Designation: 10. Field/Pool(s): ADL-0028328 Prudhoe Bay Field / PRUDHOE Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 9780 9246.3 9732 9134.3 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 7" 26 # L-80 27 - 8360 4.5 " 12.6 # 8360 - 8476 7-5/8 " 29.7 # 1- 8476 - 8496 Packers and SSSV Type: Packers and SSSV MD (ft): 8427 ~CEIVED 4-1/2" Baker S-3 Perm Packer 4-1/2" Otis WD Packer 8561 4-1/2" Otis WD Packer ::1~ . /,'0; 1 ~ 2003 4-1/2" Otis WD Packer 5-1/2" Otis RH Packer 9_'" Oil & G 7" Otis MBR SSV 2163 ., ~ )a~Cans.r^- " . Description Summary of Proposal ŒI 'ið #¡..¡ !i.~ge """""or 12. Attachments: 13. Well Class after proposed work: .,., ",J i,.J .~. Detailed Operations Program IX BOP Sketch D ExploratoryD DevelopmentD Service 00 14. Estimated Date for November 16, 2003 15. Well Status after proposed work: Commencina Operation: OilD GasD PluggedD Abandoned D 16. Verbal Approval: Date: WAGD GINJD WINJ~ WDSPLD Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brian Carlson Printed Name Brian Carlson Title Petroleum EnQineer Signature ~...~ U. -~,,~ ~ Phone 564-5046 11/13/03 -- - - Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number~n~ ,~~"Z """ -"'" Plug Integrity D BOP TestD Mechanciallntegrity TestD Location Clearance D i ~ lUUJ '-, ti}~ Other: øoMS at L t ö .- 404- Subsequent Form Required: 1/ j tic 3--/ BY ORDER OF Approved by: ~ :¿ J.~ 1 D , i r\J~~r.I- ',THE COMMISSION Date: - :ð-- ~I'A. - ~ n, : v'".' ""~'rh ¡MnU 9 11 - - -- "" "JIHrJJ Form 10-403 Revised\ /2003 ,J \" / I 1:_- I '-" 1/ '\ I 11.-" .Jt.. ... ... vo,jJ SUBMIT IN DUPLICATE (' STATE OF ALASKA (' ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 f ( ATTACHMENT Casing Length Size MD TVD Burst Collapse Top Bottom Top Bottom Conductor 82 20" 94# H-40 30 112 30.0 112.0 1530 520 Liner 1030 7" 29# L-80 8745 9775 8211.7 9241.3 8160 7020 Liner 78 4-1/2" 12.6# L-80 9453 9531 8919.3 8997.3 8430 7500 Liner 34 4-1/2" 12.6# L-80 9310 9344 8776.3 8810.3 8430 7500 Liner 68 5-1/2" 17# L-80 8498 8566 7965.5 8033.2 7740 6820 Liner 283 4-1/2" 12.6# L-80 8566 8849 8033.2 8315.6 8430 7500 Production 3166 9-5/8" 47# SOO-95 27 3193 27.0 3192.9 8150 5080 Production 5874 9-5/8" 47# L-80 3193 9067 3192.9 8533.4 6870 4760 Surface 2701 13-3/8" 72# L-80 30 2731 30.0 2731.0 4930 2670 Perforation Depth MD (ft): 9213 - 9216 9216 - 9236 9240 - 9249 9249 - 9252 9252 - 9256 9256 - 9266 9266 - 9272 9272 - 9290 9406 - 9425 9425 9440 9533 - 9555 9560 - 9576 Perforation Depth TVD (ft): 8679.3 8682.3 8706.3 8715.3 8718.3 8722.3 8732.3 8738.3 8872.3 8891.3 8999.3 9026.3 - 8682.3 - 8702.3 - 8715.3 - 8718.3 - 8722.3 - 8732.3 - 8738.3 - 8756.3 - 8891.3 - 8906.3 - 9021.3 - 9042.3 Page 1 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Au bert@admin.state.ak.us; Bob_Fleckenstein @admin.state.ak.us; Jim_Regg @admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / 03 11/29/03 Aaron Brueggeman Packer Depth Pretest Initial 15 Min. 30 Min. Well 03-10 Type Inj. S TVD 7,895' IA 520 2,400 2,360 2,345 Interval V P.T.D. 1790210 Type test P Test psi 2,400 OA 520 2,400 2,360 2,345 P/F P Notes: CMIT IA x OA for sundry evaluation. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: /' Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 03-10 11-29-03.xls bp ( (" To: J. Smart / D. Cismoski Well Operations Team leader Date: November 12, 2003 From: Kai Binkley Petroleum Engineer Subject: 03-10i OA Cement Downsqueeze Procedure PBJD0310 Est. Cost: $25M lOR: Ann Com Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 0 OA cement downsqueeze 2 0 MIT OA cement downsqueeze after wac 03~1 0 is a water injector, waivered for possible slow IA x OA communication. A cement downsqueeze was petiormed on 12/26/02, attempting to repair a leaking casing shoe, leaving 509' of cement in the OA. An OA re-pressure test failed on 6/1/03. A MITIA failed on 7/10/03. A CMIT IA x OA failed on 10/9/03. DHD used artificial lift gas to push the fluid level down to 2400'. The previous downsqueeze reported to have put 54 bbls of cement away, which would have left the top of cement at 2221'. Since the fluid level was pushed to 2400', it is not known exactly where the top of cement is. This downsqueeze is designed to set a 1000' column of cement above the shoe. If there is any cement in the OA from the previous squeeze, the displacement volume will be less than prescribed in this design. The cement volume will stay the same. Please make any changes to this procedure in compliance with the new downsqueeze job design work being done by John Cubbon, Jeff Rea, et al. The procedure includes the following major steps: 1. DHD ~~. DHD 3. 0 4. 0 Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +/~ 200 psi and fluid pack with crude as required. OA Downsqueeze MIT OA after waiting on cement. If you have any questions or comments regarding this procedure, please call Jennifer ..Julian at (W) 564~5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Julian K. Binkley B. Carlson w/o: S. Rossberg (" ( JOB PLANNING DETAILS: Current OA leak rate- 10/9/03: CMIT IA x OA Failed. LLR of 3 BPM at 1400 Q§1 Well is currently waive red for "Possible Slow IA x OA Communication" OA= 13-3/8" 72# L -80 IA= 9-5/8" 47# N-80 Shoe at 2730' OAxlA Annular Capacity=.0581 bbls/ft Volume to shoe=160 bbls 1000' of cement=§Q bbls Displacement= 160 -5 (HgO spacer) - 60 (cement) - 5 (HgO flush) = 90 bbls ****Displacement volume may be less if there is cement in the annulus from the previous squeeze. ðJ2.proximate Fluid Requirements (Downsqueeze Only)..;. Fresh Water: 210 bbls of =80 degree F 60/40 Methanol: .1Q bbls Crude Displacement: 100 bbls at 30-60 degree F Crude: (volume needed to load OA) DS CW101: 35 bbls Arctic Set 1 Cement (15.7 ppg) with Y4# per sack celloflake: the pumping time for 2 3/4+ hrs.) 60 bbls pumpable (design PREP WORK (pre downsqueezet DHD/FB: 1. Shoot FLs and record WHPs. 2. The day prior to the downsqueeze, bleed the GAP to +/- 200 psi. 3. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping (These steps may not be needed if an adequate injectivity is not able to be established) 1. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 2. Flood lines with warm fresh water and pressure test lines to 3000 psi. 3. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent times during the displacement. Current OA leak rate-LLR of 3 BPM at 1400 psi. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity ( ( b. 20 bbls of OS CW1 01 surfactant c. 200 barrels of 80° freshwater to flush OA (approx. 1.5 x annular volume) d. 15 bbls of OS CW1 01 surfactant e. 5 bbls of fresh water spacer f. 60 barrels of 15.7 ppg Arctic Set 1 cement containing V4# per sack of celloflake. g. 5 bbls of fresh water flush h. 90 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 80 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 4. Shut down pumps and leave the well SI. Please DO NOT try to achieve a .§.Queeze or to build squeeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the CA. 5. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post Squeeze: FB: 1. MITOA to 2400 psi. (1.2 times max operating pressure. Historical injection pressure is under 1900 psi.) Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. ( TREE = FMC GEN 1 WELLHEAD = CW ACn..IA. TOR = BAKER C KB. H.EV = 64' BF. ELEV = -_ ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' DatumTVD = 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.34 7" 7" 1BG, 26#, L-80, 0.0383 bpf, 10 = 6.276" TOP OF 4-1/2" TBG 14-1/2" 1BG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" H TOPOF 7-5/8" TBG 7-5/8" 1BG, 29.7#, NT-80S, 0.0459 bpf, 10 = 6.875" Minimum 10 = .875 @ 9332' CHOKE IN X NIPPLE 5-1/2"TBG-FC, 17#, L-80, 0.0232 bpf, 10 =4.892" TOPOF4-1/2"TBG-FC 1--1 TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" f}5/8" CSG, 47#, N-80, 10 = 8.681" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" ¡TOP OF 4-1 /2" TBG I ÆRFOAA TION SUMMARY REF LOG: BrcS ON 08/31/79 ANGLEA TTOPPERF: 2 @ 9213' Note: Refer to Production DB for historical erf data SIZE SFT NTERVAL Opn/Sqz DATE SEEPAGE 2 FOR ÆRFOAA 1l0N DATA 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I 2730' 8369' 8369' 8475' 8475' 8496' 8566' 8566' 8745' 8848' 9067' 03-1 0 9528' 8> 2163' 8369' 8370' 842T 8453' 8474' 8498' 8536' 8561' 8566' 8804' 8848' 883T 9310' 9332' 9343' 9453' 9502' 951T 9528' 9529' 9530' DATE REV BY COMM8'JTS DATE REV BY COMMENTS 09/07f79 ORlGINA.L COMPLETION 01/05/02 RNfTP CORRECTIONS 04/04/93 LAST WORKOVER 02/09/03 A TQ/TP DELErE WAIV ER SAFErY NOTE 12/20/00 SIS-QAA CONVERTED TO CAN\! AS 01/05/01 SIS- M) INIllAL RIDRAW 01/1 % 1 SIS- LG RIDRAW LAST TlME (HOF£) 9343' 9453' 9732' 9775' 9780' ( I SAFElY NOTES: IA X OACOMMUNICATION 7" OTIS MRB SLVN, 10=5.963" 7" X 4-1/2" XO 4-112" ffiKRSWSNIP, 10= 3.813" 9-5/8" X 4-1/2" BKR SB-3 PERM PKR 4-112" ffiKR SWSNIP, 10= 3.813" --1 4-112" X 7-5/8" Xol 5-112" 1BG SlUe FLARID TO 6-1/2" ., 5-112" OTIS SBR ASSY I -i 9-5/8" X 5-1/2" OllS RH A<R I - 5-112" X 4-1/2" XO I -f 4-112"OTISXNIP,ID=3.813" I 4-112" lTL WLEG ELrv() IT LOGGED 09/18/86 -i 7" X 4-1/2" OllS WD A<R I 4-112" OTIS X NIPW/7/8" DOWNHOLE CHOKE(4-1/2"X LOO<).ID =3.813" - 4-112" ITL WLEG I -i 7" X 4-1/2" OllS WD A<R I 4-112" AV A BA.. NIP, ID = 3.7" W/ BA -i 7" X 4-112" OllS WD A<R I ., 4-1/2" X 3-1/2" XO I 3-1/2" OTIS XN NIP, 10 = 2.635" --1 3-1/2" WLEG I PRUDHOE BAY !..NIT WELL: 03-10 PERMIT I\b: 179-0210 A A No: 50-029-20361-00 SEC 11 T10N R15E 3871.19 ÆL 1360.22 FNL BP Exploration (Alas ka) TREE = FM: GEN 1 WElLI-EAD = CIW A CfUA TOR = BAKERC KB. ELEV = 64' BF. ELEV = - _ ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800'SS ÆRFORA 110N SUMMARY RB= LOG: BrcS ON 08131/79 ANGLE AT TOP PERF: 2 @ 9213' Note: Refer to Production œ for historical perf data SIZE SFF INTERV A L Opn/Sqz DAlE 3-1/8" 4 9188-9208 S 12/01/89 3-3/8" 4 9213-9236 0 06/04192 3-3/8" 4 9240-9290 0 02/25/96 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/89 3-3/8" 2 9406-9440 0 07/07/92 3-3/8" 4 9440-9450 S 12/01/89 ? 4 9460-9474 0 07/24/86 ? 4 9500-9512 0 07/24/86 ? 4 9533-9555 0 07/24/86 ? 4 9560-9576 0 07/24/86 03-1 0 e:.~... '*"'...' cw- DATE REV BY COMMENTS DATE REV BY COrvvv1ENTS 09/07/79 ORiGNA L COMA-EllON 01/05/02 Rt--VTP CORRECfIONS 04/04/93 LAST WORKOVER 02/09/03 A TD'TP DELEfEWAIVER SAFEfY NOTE 12/20/00 SIS-QAA CONVERlEDTO CANVAS 01/05/01 SIS-MD INITIAL RB:>RA W 01/10/01 SIS-LG REDRA W LAST TIME (HOÆ) r( PRUDHOEBAY UNIT WELL: 03-10 ÆRrvIIT 1\0: 179-0210 API 1\0: 50-029-20361-00 SEC 11 T10N R15E 3871.19 ÆL 1360.22 FNL BP Exploration (Alaska) 03-10 Failed MITIA ( [ 'I' '~, 4 ,PI'!) j'71,.. 02/ Subject: 03-10 Failed MITIA Date: Wed, 08 Oct 2003 00: 11 :58 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> To: "AOGCC Jim Regg (E-mail)" <Jim_Regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us> CC: "Babcock, Dan" <BabcocDR@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "Engel, Harry R" <EngeIHR@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Julian, Jennifer Y" <JulianJY@BP.com> Hello Jim & Winton. Well 03-10 (PTD 1790210) was classified as a "B3" well and sundry #303-012 was issued on 2/3/03 allowing continued injection. The sundry was based on a passing MITIA conducted 10/7/02. A subsequent MITIA conducted 7/10/03 failed, loosing 260 psi/15 minutes. OA pressure was observed to increase during the test. The OA does not have pressure integrity, an MITOA failed after an OA cement downsqueeze. Tubing appears to be competent, there is a 2000 psi differential between the tubing and IA. The well is currently on injection. Summary of recent events: > 05/05/02: Set TTP, MITT PASSED to 2500 psi, pull TTP. > 10/07/02: MIT-IA Passed to 2500 psi, MITOA Failed, LLR = 5 BPM @ 1520 psi. > 12/26/02: Downsqz OA 4.7 bpm@1500 psi. > 12/29/02: MITOA Failed post OA dn sqz. LLR 2 BPM at 1250 psi. > 02/03/03: Sundry #303-012 issued. > 07/10/03: MITIA Failed, LLR-IA 0.7 gpm @ 2500 psi. OA pressure increased during test. Current plan is to repeat the OA downsqueeze and establish OA integrity. A CMIT IAxOA will then be conducted and the well evaluated for a sundry. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943 -1154 Pager: (907) 659-5100, xl154 Email: NSUADWWeIIIntegrityEngineer@bp.com 1 of 1 10/8/2003 8:28 AM ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: OA CMT SQUEEZE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora e, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 3143'FNL,4641'FEL,Sec.11,T10N, R15E, UM At top of productive interval 1358'FNL,3878'FEL,Sec.11,T10N, R15E,UM At effective depth 1365'FNL, 3872'FEL, Sec. 11,T10N, R15E,UM At total depth 1360'FNL,3871'FEL,Sec.11, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 81' 20" Surface 2666' 13-3/8" Intermediate 9003' 9-5/8" Liner Perforation depth: Prior to well operation SHUT-IN Subsequent to operation SHUT-IN 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations- 17. I hereby certify that the foregoing is true ~Æ~~ ROOMS 8Fl Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X (asp's 713875, 5938191) (asp's 714585, 5940000)' (asp's 714591,5939994)"" (asp's 714591, 5939995) 9780 feet 9246 feet 9332 feet 8798 feet Plugging - Perforate - Repair well _X Other - 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-10 9. Permit number / approval number 179-021 10. API number 50-029-20361-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Ba Pool Plugs (measured) Down hole choke @ 9332'. Junk (measured) Cemented 170 sx AS II 500 sx Fondu, 4000 sx AS II 800 sx Class 'G', 300 sx AS II 1030' 7" 270 sx Class 'G' 8745' - 9775' 8212' - 9241' measured Open Perfs 9213'-9236',9240'-9290',9406'-9440', 9460'-9474', 9500'-9512', 9533'-9555', 9560'-9576'. Sqzd Perfs 9290'-9292',9354'-9394',9440'-9450' true vertical Open Perfs 8679'-8702',8706'-8759',8872'-8906', 8926'-8940', 8966'-8978', 8999'-9021', 9026'-9042'. Sqzd Perfs 8756'-8758',8820'-8860',8906'-8916' Tubing (size, grade, and measured depth) 7" 26# L-80 TBG @ 8369'.7" X 4-1/2" XO @ 8369'.4-1/2" 12.6# 1-80 TBG @ 8475'. 4-1/2" X 7-5/8" XO @ 8474'.7-5/8" 29.7" NT-80S @ 8496'.5-1/2" TBG Stub Flared to 6-1/2". 5-1/2" 17# 1-80 TBG-PC @ 8566'.5-1/2" X 4-1/2" XO @ 8566'.4-1/2" 12.6# L-80 TBG @ 8848', 4-1/2" Isolation Assembly f/ 9310' - 9343'.4-1/2" Isolation Assembly f/ 9453' - 9528'. 4-1/2" X 3-1/2" XO @ 9528'.3-1/2" 9.2# L-80 TBG @ 9530'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BKR SB-3 PERM PKR @ 8427' MD. 9-5/8" x 5-1/2" Otis AH PKA. 7" x 4-1/2" Otis WD PKA's @ 9310', & @ 9453', & @ 9517'. 7" Otis MAS SL VN @ 2163' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaqe Production or Iniect~¡1 & Gas COilS. t;omm 5 . Oil-Bhl G;:¡!';-Md W;:¡ffH-Bhl cAOOOOi!" TlJhinn Prf'.!,;!,;lJrf'. Measured Depth True Vertical Depth 81' 81' 2730' 2730' 9067' 5833' ,," E~ ~~) ,~., ¡,J Ji~\N J '\ 2.00.3 16. Status of well classification as: Oil- Gas- nd correct to the best of my knowledge..... Form 10-404 Rev 06/15/88 . Title: Technical Assistant " I I, Suspended - Service WATER INJECTOR ONLY F¡r-'D CD Date January 16. 2003 Pre ared b DeWa ne R, Schnorr 564.5174 SUBMIT IN DUPLICATE ~ "~r)I'_'~['\_"", 'V ,- I I" '.-.'". -,oJ ( TREE = ., FMCGEN 1 WELLHEAD = CtN A CTUA TOR = BAKER C KB. B...EV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' DatumTVD = 8800' SS ESllMA TED CMT TOP 113-3/8" CSG, 72#, L-80, ID = 12.347" I 17" TBG, 26#, L-80, .0383 bpf, ID = 6.276" I TOP OF 4-1/2" TBG 14-1/2"TBG,12.6#,L-80, .0152bpf, ID = 3.958" 1-1 ITOPOF7-5/8"TBG l-i 17-5/8" 1BG, 29.7#, NT-80S, .0459 bpf, ID = 6.875" I Minimum ID = .875" @ 9332' C HOKE IN X NIPPLE 15-1/2"TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I ¡TOPOF 4-1/2" TBG-PC 1 ¡TOPOF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 19-5/8" CSG, 47#, N-80, ID = 8.681" I 14-1/2"TBG, 12.6#, L-80, .0152bpf, ID= 3.958"( ITOPOF 4-1/2" TBG I 1530' 8475' 8475' 8496' 8566' 8566' 8745' 8848' 9067' 9343' 9453' PERFORA 1l0N SUMMA RY REF LOG: BHCS ON 08/31/79 ANGLEATTOPÆRF: 2@ 9213' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL 10pn/Sqzl DATE SEEPAGE2 FOR PERFORATION DATA 14-112" 1BG-PC, 12.6#, L-80, .0152 bpf, ID =3.958" ( I FBTD ( 17' LNR, 29#, L-80, .0371 bpf, ID = 6.184" I TD I 9528' 9732' 9775' 9780' f 03-1 0 SAFETY NOTES: ***RAPID IAxOA COMM. OPER LIMITS: MAX lAP = 2000 PSI, MAX CAP = 2000 PSI (12/05/03 WAIVER) - NOTE: PWI ONL Y/NO MIINJ ALLOWED*** 6) 2163' 8369' 8370' 8427' 8453' 8474' 8498' 7" OTIS MRB SL VN, ID = 5.963" -1 7" X4-1/2"XO 4-112" ffiKR SWS NIP, ID= 3.813" -i 9-518" X 4-1/2" BKR SB-3 PERM PKR -i 4-112"ffiKRSWSNIP,ID=3.813" -1 4-112" X 7-5/8" XO -1 5-112"1BGS1UBFLARffiT06-1/2" I 8536' -1 5-112" OTIS SBR ASSY I -1 9-5/8" X 5-1/2" OllS RH A<R 8561' -1 5-112" X 4-1/2" XO 8566' -i 4-112"OTISXNIP,ID=3.813" 8804' -1 4-112" TT WLEG I 8848' 1-1 ELMD TT LOGGED 09/18/86 8837' -i 7" X 4-1/2" OllS WD A<R I 9310' 9332' 4-112" OTIS X NIPW/7/8" DOWNHOLE CHOKE(4-1/2" X LOa<) , ID = 3.813" 9343' -1 4-112" TTL WLEG -i 7" X 4-1/2" OllS WD A<R I 9453' -1 4-112" AVA BFt NIP, ID =3.7" W/ BA 9502' -i 7" X 4-1/2" OllS WD A<R I 9517' 9528' 9529' 9530' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COM PLETION 04/04/93 LAST WORKOVER 01105/02 RNiTP CORRECTIONS 02/09/03 A TD/TP DELETE WAIVER SAFETY NOTE 12120/03 JLA/PAG W AIV ER SA FRY NOTE 12/03 KCF/TLP ESllMA TED CMT TOP -i 4-112"X3-1/2"XO -i 3-112" OTIS XN NIP, ID = 2.635" I -1 3-112" WLEG PRUDHOE BAY UNIT WELL: 03-10 PERMrr f\b: 1790210 AA f\b: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19' FB... & 1360.22' FNL BP Exploration (Alas ka) ( TREE = FIVC GEN 1 WE3...LHEAD = CIW A crUA TOR = BAKERC KB. ELEV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datu m MD = 9398' Datum TVD = 8800'SS ÆRFORA llON SUMrv\A. RY RB= LOG: BHCS ON 08/31/79 ANGLEA TTOP PERF: 2 @ 9213' Note: Refer to Production œ for historical perf data SIZE SFf INTERVAL Opn/Sqz DAlE 3-1/8" 4 09188 - 09208 S 12/01/89 3-318" 4 09213 - 09236 0 06/04/92 3-318" 4 09240 - 09290 0 02/25/96 3-118" 4 09290 - 09292 S 12/01/89 3-118" 4 09354 - 09394 S 12/01/89 3-3/8" 2 09406 - 09440 0 07/07/92 3-318" 4 09440 - 09450 S 12/01/89 ? 4 09460 - 09474 0 07/24/86 ? 4 09500 - 09512 0 07/24/86 ? 4 09533 - 09555 0 07/24/86 ? 4 09560 - 09576 0 07/24/86 03-10 8 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07/79 ORIGINAL COMPLEfION 04104193 LAST WORKOVER 01/05/02 RN/TP CORRECllO NS 02/09/03 A TDffP DE3...ETE WA IVER SAFETY NOTE 12/20/03 JLA/PA G WA IVER SA ÆTY NOTE 12/03 KCF/TLP ESTIrv\A. T8) OII1T TOP (' PRUDHOE BAY UNrr WE3...L: 03-10 ÆRMIT No: 1790210 API No: 50-029-20361-00 SEC 11, T10N, R15E, 3871.19'FEL& 1360.22' FNL BP Exploration (Alaska) RE: 03-10 Sundry Application (PTD 1790210) ( ( " Subject: RE: 03-10 Sundry Application (PTD 1790210) Date: Mon, 20 J an 2003 15 :21 :44 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> To: Jim Regg <jim_regg@admin.state.ak.us> CC: Winton GAubert <winton_aubert@admin.state.ak.us> Dear Jim, I have attached the MIT documents that you have requested below. Please note that two competent barriers (the tubing and production casing) were established by the passing MITIA on 10/7/02. The AOGCC witnessed MITOA that was performed on 12/29/02 failed. However, the failing MITOA has demonstrated that the 13-3/8" x 9-5/8" casing annulus has an open shoe and provides a path of escape for any pressure that builds in the CA. f you have any questions, or need additional information, please don't hesisitate to call. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907 -659-5102 pgr.659-5100,x.1154 -----Original Message----- From: Jim Regg [mailto:jim_regg@admin.state.ak.us] Sent: Friday, January 17, 2003 10:41 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: 03-10 Sundry Application (PTD 1790210) John - We received your application for sundry approval for Well 03-10 on 1/16/03, requesting approval to restart produced water injection. Before the Commission can complete our review, please provide the results from following (per Commission letter addressing Category A/B3 wells dated 10/29/03 - copy attached): - MIT-T dated 5/5/02 - MIT - IA dated 10/7/02 - PPPOT dated 12/7/02 - MIT-OA dated 12/29/02 For the MIT-T, please indicate where you set the TTP (x~nipple @ 8804'?) Thanks. Jim Regg lof2 1/31/2003 9:24 AM RE: 03-10 Sundry Application (PTD 1790210) i ~, ( Name: MIT PBU 03-10 MIT-IA 10-07-02.xls ~MIT PBU 03-10 MIT-IA 10-07-02.xls Type: Microsoft Excel Worksheet (applicationlvnd.ms-excel) Encoding: base64 Name: BP Well 03-10 MIT 12-07-02.xls ~BP Well 03-10 MIT 12-07-02.xls Type: Microsoft Excel Worksheet (applicationlvnd.ms-excel ) Encoding: base64 Name: MIT PBU 03-10 MIT-T 05-05-02.xls ~MIT PBU 03-10 MIT-T 05-05-02.xls Type: Microsoft Excel Worksheet ( applicationlvnd.ms-excel) Encoding: base64 Name: MIT PBU 03-10 MIT-OA 12-29-02.xls IMIT PBU 03-10 MIT-OA 12-29-02.xls Type: Microsoft Excel Worksheet ( applicationlvnd.ms-excel) Encoding: base64 2 of2 1/31/2003 9:24 AM 03- i' 0 Sundry Application (PTD 1790210) ( Subject: 03-10 Sundry Application (PTD 1790210) Date: Fri, 17 J an 2003 10:41 :21 -0900 From: Jim Regg <jim _regg@admin.state.ak.us> Organization: AOGCC To: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> CC: Winton GAubert <winton_aubert@admin.state.akus> ( John - We received your application for sundry approval for Well 03-10 on 1/16/03, requesting approval to restart produced water injection. Before the Commission can complete our review, please provide the results from following (per Commission letter addressing Category A/B3 wells dated 10/29/03 - copy attached):./ ? - MIT - T dated 5/5/02 ft>r:ç1/ f::æ.~)? pL~ . - MIT - IA dated 10/7/02 v p~ - PPPOT dated 12/7/02./ ,/ '-r~ ~t,.~. p.u;s ~ :fC,. hA..~J6- ~ f"-:{£Ì4!} .-!Ùi:; ,.ht - MIT -OA dated 12/29/02 ~ ; Ø:~ ,~~ (2ßfl.-\ ,..\~(;h~' !~ ~ ¡ZS'°F~) For the MIT-T, please indicate where you set the TTP (x-nipple @ 8\~) Thanks. ~4!131 tAb Jim Regg Name: a-b3 wells revised 10-29-02.doc [ïàa-b3 wells revised_10-29-02.doc Type: WINWORD File (application/msword) Encoding: base64 Jim Regg <Hrn regg@adrnin.state.ak.us> Petroleum Engineer AOGCC Administration 1 ofl 1/17/2003 10:41 AM ( ( BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 12, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 03-10 (PTD 1790210) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for well 03-10. This request is for approval to continue produced water injection of a class "83" water injection well. A description summary of proposal and wellbore schematic is included for each well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. SinCR.1~ J n Cubbon Well Integrity Engineer 3 Attachments Application for Sundry form 10-403 Description Summary of Proposal Wellbore Schematic ~), , ,',",{"'" (~ ,,',,""-'0),",' ~ \,J' ~,~I"',' ~,I',",'\~" I I i~, I,' I, '\,1 ","- " " ' 1'['. Iii :! ii' \/ , ,;, j \, ' ~ ",~I \'¡."",~,.""":,",,,, ',.' ,~". , 1 6 2003' J!\N I " 'I " : I,' I i \ '¡I i I ~: , Alaska em & Gas COilS. GUjHnH(~;SiU! ~!~~"'h 1)'r""I-""'1 ',' '", ',\,', ',' -'I' '~,',. I ,.' ," ,I " , ' ~,' ,.,1 C,' ft (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: H2O Injection Variance 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3147'FNL,4642'FEL,Sec.11, T10N, R15E, UM At top of productive interval 1359' FNL, 3877' FEL, SEC 11, T10N, R15E, UM At effective depth 1363' FNL, 3872' FEL, Sec. 11, T10N, R15E, UM At total depth 1363' FNL, 3872' FEL, Sec 11 T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Abandon- Suspend- Alter casing - Repair well - Change approved program Effective depth: measured true vertical Casing Length Size Conductor 81' 20" Surface 2699' 13-3/8 Intermediate 9036' 9-5/8" Liner 1030' 7" Perforation depth: Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 713875, 5938191) (asp's 714585, 5940000) (asp's 714591,5939995) (asp's 714591, 5939995) 9780 feet 9246 feet 9732 feet 9198 feet Plugs (measured) Junk (measured) ~. tJ..i(;'~. zf3/0J I^ t-/ð 11../"3(° '3 D7J O:.Jj C' 3/0.3 Re-enter suspended well - Time extensioY Stimulate - Variance X Perforate 6. Datum elevation (DF or KB feet) RKB 64.0 feet 7. Unit or Property name Other Prudhoe Bay Unit 8. Well number / 03-10 9. Permit number / approval number 179-021 10. API number 50-029-20361-00 11 . Field / Pool Prudhoe Bay Field / Prudhoe Bay Oil Pool Cemented Measured Depth 170 sx AS II 112' 500 sx Fondu, 4000 sx 2730' AS II 800 sx Class 'G', 300 sx 9067' AS II 270 sx Class 'G' 8745' - 9775' True vertical Depth 112' 2730' 5833' 8212' - 9241' ", susp~,Wd 1.6 200~~ Name of approver Date approved Service WA TER INJECTOR ONLY *\\'.~Ol! 8~G::i~~wt.~.~~\lï~t:., ~.:;(}~.¡nÜ~¡tÜO¡, 17. I hereby certify that the foregoing is tr and correct to the best of my knowledge. Questions? Call Joe Anders or' 1ì'H '<bö'n' @ 659-5102. measured Open Perfs 9213'-9236',9240'-9290',9406'-9440', 9460'-9474', 9500'-9512', 9533'-9555', Open Perfs (cont) 9560'-9576'. Sqzd Perfs 9188'-9208',9290'-9292',9354'-9394',9440'-9450'. true vertical Open Perfs 8679'-8702',8706'-8759',8872'-8906', 8926'-8940', 8966'-8978', 8999'-9021', Open Perfs (cont) 9026'-9042'. Sqzd Perfs 8654'-8674',8756'-8758', 8820'-8860', 8906'~8916'. 7" 26# L-80 TBG @ 8360'. 4-1/2" 12.6# L-80 TBG @ 8475'. 7-518" 29.7# NT-80 TBG @ 8496'. 5-1/2", 17#, L-80, PCT @ 8566'; 4-1/2", 12.6#, L-80, PCT TBG Tails @ 8849',9344' & 9530'. Packers & SSSV (type & measured depth) 9-518" X 4-1/2" Baker SB-3 Perm PKR @ 8427'; 9-5/8" x 5-1/2" OTIS RH PKR @ 8561'. 7" X 4-1/2" OTIS WD PRK @ 9310',9453' & 9517'. 7" OTIS MRB S~VN S S j 4' 13. Attachments Description. summary of proposal X Detailed operations program B k tch... 14. Estimated date for commencing operation 15. Status of well classification as: Janua 2003 16. If proposal was verbally approved Signed John Cubbon RBaMS BFl Form 10-403 Rev 06/15/88 . Oil- Title: ADW Wellintergrity Engineer rO'". :! .,; Ii ,:; .. Gas- FEB 4 20m FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. _363 --CJ I ;;- Plug integrity - ~p Test - Location clearance - , ~.L. Mechanical Integrity Test .. + . Subse~uent for~ r.eQUired 10-. . r~l2-{.f' LV C< I?-t" ~c..(, s t.Lb ~ c ~ ~fI 0 f'ß t'1ç- ~ 1 t ""1-«----rvc-r- vn-te '5 ~ d P ~'$ t t-{ f1-l ç . \ pq.~~.'~ ¡Vlrr[E'Æ) ~.~ 1-1.(/0 ~cwfs. Approved by order of the Commission Commissioner Date M L Bill SUBMIT IN TRIPLICATE ( ( 03-10 Description Summary of Proposal 01/11/03 Problem: Class "B3" Water Injector. Well History and Status: Well 03-10 (PTD 1790210) has been labeled as a "Class B3" Water injection well. This well was designated as "Class B3" based on a previous variance (#300-106) for IA x OA communication, and uncertainty about the integrity of the tubing.4'he well has undergone thorough diagnostic testing since it was shut-in on 8/29/02. Mechanical integrity tests indicate competent tubing, packer, and production casing. Recent Well Events: ~ 05/05/02: MIT-T passed to 2500 psi aga~st a TTP. / ~ 08/27/02: Well Classified as Class "B3" trouble well, shut-in and secured. /' ~ 10/07/02: MIT-IA to 2500 psi Passed (AOGCC witnessed by John Crisp). , ~ 12/07/02: PPPOT-T Passed, PPPOT-IC was not tested due to sealant having .-/ been pumped into test void (AOGCC witnessed by John Crisp). ~ 12/29/02: MIT-OA failed (AOGCC witnessed by John Crisp). This Sundry request is to allow for continued water injection of this Class "B3" well. The following supports the request: . A MIT- IA passed to 2500 psi on 10/07/02, indicating competent tubing, /' packer and production casing, and wellhead integrity. . Pressure and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. / Proposed action plan: 1. Allow well to continue Water injection. 2. Cancel existing Sundry (#300-106) for IA x OA communication. 3. Record wellhead pressures and injection rates daily. 4. Stop injection and notify the AOGCC if there is an indication of a loss of production casing integrity. / TREE = FMC GEN 1 WELLHEÀD = CW A CflJA. TOR = BAKER C KB. 8..EV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' DatumTVD = 8800' SS 113-318" CSG, 72#, L-80, ID = 12.347" 1 17" lBG, 26#, L-80, 0.0383 bpf, ID = 6.276" I TOPOF 4-1/2" TBG 14-1/2" lBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" H TOP OF 7 -5/8" TBG 7-518" lBG, 29.7#, NT-80S, 0.0459 bpf, 10 = 6.875" 03-1 0 2730' 8369' 8369' 8475' 8475' Minimum 10 = .875 @ 93321 CHOKE IN X NIPPLE 8496' 5-1/2" TBG-Fe, 17#, L-80, 0.0232 bpf, ID = 4.892" I TOP OF 4-1/2" TBG-Fe 1-1 TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, N-80, ID = 8.681" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10= 3.958" ITOP OF 4-1/2" TBG 1 8566' 8566' 8745' 9343' 9453' SEEPAGE 2 FOR ÆRFORA 110N DATA 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I ~ 17" LNR, 29#, L-80, 0.0371 bpf, 10=6.184" 1 I1£] 9528' 8 2163' 8369' 8370' 8427' 8453' 8474' 8498' 8536' 8561' 8566' 8804' 8848' 8837' 9310' 9332' 9343' 9453' 9502' 9517' 9528' 9529' 9530' DATE REVBY COMrvENTS DATE REV BY 00 IVIV1 EN T S 09/07/79 ORIGINAL ooMR.ErION 01/05/02 RN'TP ooRRECTIONS 04/04/93 LAST WORKOVER 12/20/00 SIS-QAA ooNVERTEDTO CANVAS 01/05/01 SIS-MD INITIAL REDRA W 01/1 % 1 SIS-LG REDRAW LAST TIME (HOPE) 9732' 9775' 9780' (' SAFETY NOTES: 5/20100 W AlVERB> WELL- IA x OA COMMUNICAll0N -1000 PSI MAX. 7" OTIS MRB SLVN, 10 = 5.963" 7" X 4-1/2" XO 4-112" FRKR SWS NIP, 10 = 3.813" -i 9-518" X 4-1/2" BKR SB-3 PERM PKR I 4-112" FRKR SWS NIP, ID= 3.813" -J 4-112" X 7-5/8" XO I -i 5-112" lBG SlUB FLARED TO 6-1/2" I -J 5-112" OTIS SBR ASSY 9-518" X 5-1/2" 011S RH A<R 4-112" OTIS X NIP, ID = 3.813" 4-112" ITL WLEG ELMO IT LOGGED 09/18/86 -I 7" X 4-1/2" 011S WD A<R I 4-112" OTIS X NIPW/7/8" DOWNHOLE CHOKE (4-1/2" X LOO<), ID = 3.813" 7" X 4-1/2" 011S WD A<R I 4-112"AVABR.NIP,ID=3.7"W/BA I 7" X 4-1/2" 011S WD A<R I FRUDHOE BA Y UNIT W8..L: 03-10 ÆRMITNo: 179-0210 API I\b: 50-029-20361-00 SEC 11 T10N R15E 3871.19 FEL 1360.22 FNL BP exploration (Alaska) ( TREE = , Flv'C GEN 1 WB.U-EAD = CrN A crUA TOR = BAKERC KB. ELEV = 64' BF. ELEV = ? - - KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS ÆRFORA llON SlJv1MARY REF LOG: BI-CS ON 08131/79 ANGLEA TTOP PERF: 2 @ 9213' Note: Refer to Production 00 for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 3-1/8" 4 9188-9208 S 12/01/89 3-3/8" 4 9213-9236 0 06104/92 3-3/8" 4 9240-9290 0 02/25/96 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/89 3-3/8" 2 9406-9440 0 07/07/92 3-3/8" 4 9440-9450 S 12/01/89 ? 4 9460-9474 0 07/24/86 ? 4 9500-9512 0 07/24/86 ? 4 9533-9555 0 07/24/86 ? 4 9560-9576 0 07/24/86 03-1 0 (I) DATE REV BY COMrvENTS DATE REV BY COM'v1ENTS 09/07/79 ORiGNAL COMA-EllON 01/05/02 RN'TP CORRECTIONS 04/04/93 LAST WORKOVER 12/20/00 S6-QAA CONVERTED TO CANVAS 01/05/01 SIS-rvD INITIAL RI3)RA W 01/10/01 SIS-LG RI3)RA W LAST TIME (HOÆ) ( PRUDHOE BA Y UNIT WELL: 03-10 ÆRMlT f\b: 179-0210 API f\b: 50-029-20361-00 SEC 11 T10N R15E 3871.19 FEL 1360.22 FNL 8P Exploration (Alaska) ( ( ~s Ò 3- \~ 4e.~ ~~~'I @ ~~~ tÆ- :!Ä 1- oA -Á'eJ -to ~\\"oaJ.. t~~S) ~tb11 p\U4feJ J:.f I~c {t!\c~~ ~ to IS ,~ G5/ß o..nL- ~ leæc r~r (Ð M.Þ¡-&4. ~ ~Al/.re ,,5BFM. LLe. ) @ rfeu\~ J..\:PrJ.A-~~ rM~ / . - !Jðrt l..k J Ie eorcJ. I kj 0 ~ } R.;J:. ~ ~ ~ - 'f'~f}lr4Lt of- ~t ~ ~~â ~ - MJ1-~ G~es. ,,/ ~\. 1 ~ ¡.{" Cc ~ 1J\A.1..{,1 S MEMORANJUM (" State of AI as ka Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder t! r:) <¡My BPX P.I. Supervisor ¡~ -L PBU \ f. -0 / OS 3-10 FROM: John Crisp \~ Injector Petroleum Inspector Prudhoe Bay Field NON. CONFIDENTIAL fl'"t,\¡ DATE: Oecember 29, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well 03-1 0 Type Inj. S T.V.D. 7895 Tubing 0 0 0 0 Interval 0 P.TD. 1790210 Type test P Test psi 2500 Casing 2500 380 380 380 P/F F Notes: OA MIT failed wI leak rate of 2 BPM 1200 psi. Well Type Inj. TVD. Tubing Interval P.T.D. Type test Test psi Casi ng PIF Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casi ng PIF Notes: Well Type Inj. TVD. Tubing Interval P.T.D. Type test Test psi . Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details M.I.T.'s performed: 1 Attachments: Number of Failures: 1 Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 loG. MIT BPX PBU 3-10 12-29-02 JC.xls 1 119/2003 12/13/2002 12/15/2002 12/16/2002 12/18/2002 12/19/2002 12/25/2002 12/26/2002 12/26/2002 12/27/2002 12/27/2002 12/29/2002 12/29/2002 01/07/2003 12/13/02 12/15/02 12/16/02 12/18/02 12/19/02 12/25/02 12/26/02 (- " (" 03-1 0 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SECURE WELL: AC-BLEED; AC-FLUID LEVEL; AC-MONITOR SECURE WELL: AC-MONITOR SECURE WELL: AC-EVAL; AC-MONITOR SECURE WELL: AC-MONITOR SECURE WELL: AC-FLUID LEVEL CEMENT SQUEEZE: AC-BLEED CEMENT SQUEEZE: AC-LLRT; CEMENT SQUEEZE CEMENT SQUEEZE: CEMENT SQUEEZE SECURE WELL: AC-MONITOR SECURE WELL: AC-FLUID LEVEL; AC-MONITOR SECURE WELL: AC-MITOA SECURE WELL: MIT-OA TESTEVENT --- INJECTION PRESSURE, PSI: 1,901 TYPE: PW VOLUME: 0 BWPD. EVENT SUMMARY T/I/O = VAC/20/30. TBG, IA AND OA FL, PRESSURIZE IA (OA BUR MONITORING) TBG FL @ 1400'. IA FL @ 40'. OA FL NEAR SURFACE. RIGGED UP CHART RECORDER TO IA AND OA. BLED OA FROM 20 PSI TO 0 PSI IN 5 MINUTES (ALL GAS). PRESSURED IA UP WITH AL GAS (FROM 3-01) TO 1900 PSI. OA PRESSURE INCREASED TO 400 PSI WHILE IA WAS PRESSURING UP. BLED OA FROM 400 PSI TO 100 PSI IN 2 MINUTES (FLUID TO SURFACE). MONITORED FOR 20 MINUTES. OA PRESSURE INCREASED TO 260 PSI. FINAL WHP's = V AC/1900/260. T/I/O=VAC/780/780 (MONITOR OA BUR) REPRESSURIZED IA TO 1900 PSI WITH 3-01 AL GAS. OA PRESSURE STAYED THE SAME WHILE PRESSURING UP IA. PUT 7 DAY CHART ON, MONITORED OA FOR 30 MINUTES, GAP STAYED THE SAME. FINAL WHP's --- VAC/1900/780. T/I/O= VAC/720/780 (MONITOR OA BUR) MONITOR WHP's. T/I/O = VAC/600/630. R/D CHART RECORDER. (MONITOR OA BUR). T/I/O=0/540/540 (PREP FOR OA DOWN SQZ) IA FL @ 341. OA FL @ 2701. T/I/O = 0/450/300. BLEED DOWN WHP's (PRE-OA DOWN SQZ). OA FL @ 2701 BLED TO 0+ PSI IN 30 MINUTES. IA FL NEAR SURFACE,BLED TO 0+ PSI IN 15 MINUTES. FINAL PRESSURES; 0/0+/0+. ESTABLISH LLRT = 4.7 BPM @ 1600# ON OA. HOLD PRESSURE ON IA FOR CEMENT SQUEEZE. Page 1 . 12/26/02 12/27/02 12/27/02 12/29/02 12/29/02 01/07/03 ( ( 03-1 0 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS MIRU LRS, CONFIRM OA INJECTIVITY AT 4.7 BPM AT 1500 PSI. RU LRS ON IA FOR PRESSURE MAINTENANCE. RU DS ON OA FOR CEMENT SQUEEZE (SEE SEPARATE LRS AWGRS DATED 12/26/02 FOR ADD'L REPORT). PUMP 240 BBLS WATER, 35 BBLS SPACER, AND 54 BBLS OF 15.7 PPG ARCTIC SET 1 CEMENT. DISPLACE TO SHOE WITH CRUDE. HESITATE TO SQUEEZE WITH 15 BBLS OUT OF SHOE AND CONTINUE FOR 10 BBLS. NO SIGNIFICANT INCREASE IN WHP. SHUT IN WITH 300 PSI OVER INITIAL SIP. RDMO. «< NOTIFY DSO TO LEAVE SHUT IN »> TIIIO = S1/400/230. (MONITOR POST OA DOWN SQZ). TIIIO = S1/400/230. (OA FL PREP FOR MITOA). OA FL @ SURFACE. TIIIO = V AC/320/170. MIT - OA TO 2400 PSI. FAILED. (AOGCC WITNESS, JOHN CRISP). OA FL NEAR SURFACE. PRESSURED OA 1000 PSI WITH <2 BBLS OF DIESEL. AT 3 BBLS AWAY OAP DROPPED TO 800 PSI. CONTINUED PUMPING WITH NO INCREASE IN OAP. INCREASED PUMP RATE TO 2 BPM. OAP INCREASED TO 1250 PSI. PUMPED AN ADDITIONAL 12 BBLS AT 2 BPM WITH NO INCREASE IN PRESSURE. ESTABLISHED LLR OF 2 BPM AT 1250 PSI WITH 12 BBLS OF DIESEL. SD AND OAP DROPPED TO 800 PSI. MONITORED PRESSURE FOR 30 MINUTES. OAP DROPPED TO 440 PSI. FINAL WHP's = V AC/360/440. ATTEMPT TO PT OA. WOULD NOT PRESSURE UP. SID & RID. 20 BBLS DIESEL. TESTEVENT --- INJECTION PRESSURE, PSI: 1,901 TYPE: PW VOLUME: 0 BWPD. Fluids Pumped BBLS 16 NEET METHANOL 30 DI ESEL 120 CRUDE 246 FRESH WATER 35 CW-101 SURFACTANTISPACER 54 15.7 ARCTIC SET 1 CEMENT (1/4# CELLOFLAKE IN FIRST 25 BBLS) 501 TOTAL Page 2 TREE = FMCGEN 1 (" WELLHEAD = CtN A CTIJI\ TOR = BAKER C KB. 8.EV = 64' BF. ELEV = ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS 113-318" CSG, 72#, L-80, 10 = 12.34 7" I 7" TBG, 26#, L-80, 0.0383 bpf, JD = 6.276" 'TOP OF 4-1/2" TBG I 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf.ID =3.958" H TOP OF 7 -5/8" TBG 7-518" TBG, 29.7#, NT-80S, 0.0459 bpf. JD = 6.875" Minimum 10 = .875 @ 9332' CHOKE IN X NIPPLE 5-1/2" TBG-Fe, 17#, L-80, 0.0232 bpf. 10 = 4.892" 'TOPOF 4-1/2" TBG-Fe l-f TOP OF 7" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 9-5/8" CSG,47#, N-80, ID= 8.681" 4-1/2" TBG, 12.6#, L-BO, .0152bpf, JD= 3.958" ¡TOPOF 4-112" TBG I SEEPAGE 2 FOR F£RFORA 110N DATA 14-1/2"TBG-PC,12.6#, L-80,O.0152bpf,ID=3.958" I ~ 17" LNR.29#, L-80, 0.0371 bpf,ID=6.184" I [I£I 2730' 8369' 8369' 8475' 8475' 8496' 8566' 8566' 8745' 8848' 9067 9343' 9453' 03-1 0 9528' 6> 2163' 8369' 8370' 8427 8453' 8474' 8498' 8536' 8561' 8566' 8804' 8848' 8837 9310' 9332' 9343' 9453' 9502' 9517 9528' 9529' 9530' DATE REV BY COMIv1ENTS DATE REV BY COM'v1ENTS 09/07/79 ORIGINAL COMR...EfION 01/05/02 RN'TP CORRECTIONS 04/04/93 LAST WORKOVER 12/20/00 SIS-QAA CO NV ERfED TO CANVAS 01/05/01 SIS-MD INITIAL REDRA W 01/1 % 1 SIS-LG REDRA W LAST TUllE (HOPE) 9732' 9775' 9780' SAFETY NOlES: 5/20/00 W AlVERED WB.l- IA x OA COMMUNICATION -1000 PSI MAX. -J 7" OTISMRB SLVN,ID=5.963" I 7" X 4-1/2" XO 4-1/2" FRKR SWS NIP, ID = 3.813" 9-518" X 4-1/2" BKR SB-3 PERM PKR 4-1/2" FRKR SWS NIP, 10= 3.813" -f 4-1/2" X 7-5/8" XO I 5-1(2" OTIS SBR ASSY I 9-518" X 5-1/2" 011S RH A<R I 5-1/2" X 4-1/2" XO 4-1(2" OTIS X NIP, ID = 3.813" 4-1/2" TTL WLEG EUvÐ TT LOGGED 09/18/86 -J 7" X 4-1/2" 011S WD A<R I 4-1/2" OTIS X NIPW/7/8" DOWNHOLE CHOKE (4-1/2" x LOO<) , ID = 3.813" 4-1/2" TTL WLEG -J 7" X 4-1/2" 011S WD A<R I -f 4-1/2"AVABR...NIP,ID=3.7"W/BR I -i 7" X 4-1/2" OTIS WD A<R I -f 4-1(2" X 3-1/2" XO I -I 3-1(2" OTIS XN NIP, ID = 2.635" I -f 3-1/2" WLB3 FRUa;OE BA Y UNIT W8.L: 03-10 ÆRMIT No: 179-0210 API f\b: 50-029-20361-00 SEC 11 T10N R15E 3871.19 FEL 1360.22 FNL I3P exploration (Alaska) /" ( ( TREE = FM:: GEN 1 WB...LHEAD = CIW ACTUATOR = BA KER C KB. ELEV = 64' BF. ELEV = --_ ? KOP= 4100' Max Angle = 45 @ 5900' Datum MD = 9398' Datum TVD = 8800' SS ÆRFORA 1l0N SUMMARY RB= LOG: BHCS ON 08ß1179 ANGLE A TTOP PffiF: 2 @ 9213' Note: Refer to Production œ for historical perf data SIZE SA= INTffiV A L Opn/Sqz DATE 3-1/8" 4 9188-9208 S 12/01/89 3-3/8" 4 9213-9236 0 06/04/92 3-3/8" 4 9240-9290 0 02/25/96 3-1/8" 4 9290-9292 S 12/01/89 3-1/8" 4 9354-9394 S 12/01/89 3-3/8" 2 9406-9440 0 07/07/92 3-3/8" 4 9440-9450 S 12/01/89 ? 4 9460-9474 0 07/24/86 ? 4 9500-9512 0 07/24/86 ? 4 9533-9555 0 07/24/86 ? 4 9560-9576 0 07/24/86 03-1 0 8 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/07'/79 ORiGNAL COMA..EllON 01/05/02 RNiTP CORRECTIONS 04104/93 LAST WORKOVER 12/20/00 SS-QAA CONVERTED TO CANVAS 01/05/01 SIS-rvD INrrlAL REDRA W 01/10/01 SIS-LG REDRA W LAST TIME (HOÆ) PRUDHOE BAY UNIT WELL: 03-10 ÆRMlT I'b: 179-0210 API I'b: 50-029-20361-00 SEC 11 T10N R15E 3871.19 FEL 1360.22 FNL BP Exploration (Alaska) ,{ ( ( \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD J UNIT J PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay J PBU / 3 12/29/02 Iveson John Crisp Production Casing Surface Casing 0 F Tubing Casing Tubing Casing Tubing Casing Tubing Casing Test Details: MITOA Failed. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 03-10 MIT-OA 12-29-02.xls (' ( WE:LLHEAD PACKOFF TESTING FORM I WEll: DS 03-10 DATE: 12/7/2002 TESTED BY: CoxlFMC TEST FOR: TYPE & GEN FMC I Well Status: TBG: CONTROL: INITIAL PRESSURE DATA TYPE: 0 IA: 180 OA: 160 0 BALANCE: 0 Tubing Hanger Test PASS Pressured To: 5200 Press. @ 15 min: 5000 Press. @ 30 min: Test Port Press. @: 0 Bled to 0 Psi YES I Were Lockdown Screws Tightened? YES I Torqued to Comments: Test was witness by John Crisp with AOGCC 4975 450 ftllbs Inner Casing Hanger Test PLASTIC PACKED Pressured To: Press. @ 15 min: Press. @ 30 min: Test Port Press. @: Bled to 0 Psi YES I NO Were Lockdown Screws Tightened? YES I NO Torqued to Comments: Void has been plastic packed and cannot be tested ftllbs { ( October 29, 2002 Mr. Randy Frazier Wells Delivery Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Frazier: BP Exploration (Alaska) Inc. (BPXA) was approved to proceed with startup of Category A/B3 production wells by letter dated October 22, 2002. The approval addressed wells within the Prudhoe Bay field that exhibit rapid pressure communication between the inner annulus (IA) and outer annulus (OA), and in some instances exhibiting pressures that equalize across tubing, lA, and OA when the well is shut in. During discussions with Jim Regg (AOGCC) on October 28, 2002, Steve Rossberg (BPXA) raised some questions regarding the approval conditions attached to the October 22, 2002 letter. During that discussion, Mr. Rossberg provided clarification about BPXA's start-up and operating procedures for the Category A/B3 wells. This letter is intended to replace the October 22, 2002 approval, providing conditions that clarify start-up procedures and operating parameters for these wells with annular pressure communication. BPXA is approved to proceed with startup of Category A/B3 wells at Prudhoe Bay subject to these revised conditions: 1. Producing wells only are approved for start up. Injection wells must comply with the requirements of 20 AAC 25.252(e) for disposal injection and 25.402(f) for enhanced oil recovery operations. BPXA must resubmit Sundry applications requesting approval to continue operating the following injection wells that have been categorized as A/B3 wells: DS 3-10; DS 12-2; DS 12-23; and DS 12-30. 2. BPXA must demonstrate at least two (2) competent barriers (one must be the tubing) in each well. The term "competent" as used here means no communication. A pressure test or tubing integrity fluid level test must be performed to confirm tubing integrity. A pressure test must be held 30 minutes at 3000 psi, with less than 10% pressure loss and a stabilizing trend. Deviation from the noted tubing test methods must be requested by Sundry application (Form 10-403) with justification. Mr. Randy Frazier 'October 29, 2002 Page 2 of 2 (, ( 3. Provide test records for the tubing, casing annuli, and wellhead seals on a Mechanical Integrity Test form (or similar format) within seven (7) days after initiating production; the report must include pre-test pressures in all casing annuli and the shut in tubing pressure. 4. Operating pressure shall not to exceed 80% of outer annulus mechanical integrity test pressure. 5. Well must be attended continuously during startup by a qualified person until the flowing conditions have stabilized. The AOGCC defines "continuously" as meaning a qualified operator must be at the pad and the well startup must be his primary responsibility. 6. Record all pressures in the well daily. These records must be maintained and available for AOGCC inspection upon request. 7. Should pressures in any of the casing annuli reach 2000 psi, BPXA must notify the AOGCC and secure approval to continue operating the well. 8. Any well exhibiting communication across more than two 0 barriers must be secured. The Commission shall be notified the next business day of such loss of well integrity. Be aware that the Commission has scheduled a hearing for November 14, 2002 at 9:00 am, during which a rule will be considered to govern the operation of development wells in all pools within the Prudhoe Bay Field with pressure communication or leakage in any casing, tubing, or packer. The conditions outlined in this letter may be revised at such time the Commission completes the public hearing process. We appreciate the responsiveness BPXA has demonstrated to date regarding AOGCC requests, and the frequent updates of restart activities. Should you require clarification regarding the contents of this letter, please contact Jim Regg at 793-1236. Sincerely, Cammy Oechsli Taylor Chair COT:~jc " " , (' (' PrD "79-ð '2-/ ~ subject: RE: DS 03-10 Date: Tue, 15 Oct 2002 02:01:46 -0500 From: "NSU, ADW well Integrity Engineer" <NSUADwwellIntegrityEngineer@BP.com> TO: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> cc: "Barton, Kira" <kira.barton@BP.com>, "Jim Regg (E-mail)" <jim_regg@admin.state.ak.us> Hi Tom. well 03-10 received a variance on 5/7/00 for IAxOA communication. Below is a chronology of events: pbu_ds3-10_integrity_hist.txt > 01/07/00: MITIA Failed, CMIT IAxOA Failed, LLR IA into OA = 8.7 GPM @ 1450 psi. MITOA Failed could not get OA to pressure up. PPPOT-T Passed (pre-cTD testing). > 01/17/00: MITOA Failed, LLR = 1.7 bpm @ 2000 psi. > 01/18/00: Initiate operations to set TTP, stripped fishing neck on sssv, ended up using coiled Tubing to fish sssv. > 03/09/00: TTP set 8438' > 03/10/00: pumped sealTite into IC hanger void, PPPOT-IC passed to 3000 psi. > 03/12/00: MITT Passed (state witnessed) @ 3000 pSl > 03/13/00: TTP pulled > 03/16/02: MITIA Failed, LLR = 1.1 GPM @ 2125 psi. > 05/05/02: SL set TTP, MITT PASSED to 2500 psi, Pull TTP. > 08/29/02: SI as part of IAxOA communication project. well was classified as having IAxOA communication. > 10/07/02: MIT-IA passed to 2500 psi, MITOA Failed, LLR = 5 BPM @ 1520 psi. This well passes an MIT-T against a TTP. However, MITIA'S have failed in the past. The OA pressure was noted to increase with the IA pressure and IAxOA communication was diagnosed 1/00. SealTite was pumped into the IC hanger void on 3/10/00 and the IA leak rate was observed to have decreased from 8.7 GPM on 1/7/00 to 1.1 GPM on 3/16/00, indicating a possible leak path through the wellhead. On 10/7/02, the MITIA passed. I'm not too surprised - well conditions change and occasionally things get better. Another recent example is 12-02 that has a variance for slow TxIA communication - recent MITIA'S and pressure observations indicate no current TxIA communication. The leak on 3-10 was potentially through the wellhead and it could have gotten plugged with debris from the injection stream. Rather than cancel the sundry, we've continued with the enhanced testing required by the sundry. We set a TTP and conduct an MIT-T every 2 years, last done 5/5/02. Let me know if you have any other questions or would like to discuss further. Note I return to Anchorage on Tuesday, John cubbon is coming up to take my place. Kira is continuing to work on gathering MIT information and coordinate AOGCC witnessed MIT'S on some of the new injectors and producer-injector conversions. Joe 659-5102 -----original Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, October 14, 2002 7:39 AM To: NSU, ADW well Integrity Engineer; Barton, Kira Cc: Jim Regg subject: DS 03-10 page 1 4 ( (" pbu_ds3-10_integrity_hist.txt Joe, Kevin and Kira, On october 7, John crisp witnessed MITs on 01-15A (producer OA) and 03-10 (waivered injector). In the case of 03-10, John's information shows that the well passed the standard MIT since the well is on waiver due to rapid IA x OA communication, this is a little surprising. what do you all make of this?? John further noted that the OA on the well was to be MITed as well, but that he was not able to witness that event. what was the outcome on the OA test? Thanks. Tom Maunder, PE AOGCC page 2 ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor ut",.t'Þ Chair SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder cI G 1yý) BPX P.L Supervisor tX/r \0, \:\""0::>. PBU OS 03-10 \ PTO 1790210 FROM: John Crisp Category AIB3 Petroleum Inspector Prudhoe Bay Field t!QN: ~ DATE: October 7, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well 03-10 Type Inj. N T.V.D. 8427 Tubing 0 a 0 0 Interval 0 P.T.D. 1790210 Type test P Test psi 2500 Casing 0; ....... 2500 2475 2475 P/F P Notes: This well has AOGCCwaiverforlAtoOAcommunication. 2 yearMIT required. Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I~ Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details This well has waiver to continue water injection. Safety notes on waiver 5/20/00 IA x OA communication - waivered 1000 psi. max. PT of OA was scheduled after MIT lA, I don't have information about OA test. OA supposedly has open shoe & a leak rate can easily be established. Due to PT on A-22 I did not see OA test on this well. M.LT.'s performed: 1 Attachments: . Number of Failures: 2 Total Time during tests: ~ ~ MIT report form 5/12/00LG. 021007-MIT PBU 03-10 JC:xls 10/14/2002 . ~ ~: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD J UNIT J PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU J 3 10/07/02 Olsen Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Well 03-10 Type Inj. S MD/TVD 8,427' 7,895' Tubing 0 0 0 0 Interval 0 P.T.D. 1790210 Type test P Test psi 2500 Casing 0 2500 2500 2500 P/F P Notes: MITIA Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: MITIA to test tubing and casing integrity. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 03-10 MIT-IA 10-07-02.xls ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU /3 05/05/02 Romberg Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Well 03-1 0 Type Inj. S MD/TVD 8,427' 7,895' Tubing 0 2500 2485 2460 Interval 4 P.T.D. 1790210 Type test P Test psi 2500 Casing 0 60 70 80 P/F P Notes: TTP was set in 4-1/2" SWS Nipple at 8453' MD. Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: MIT-T Passed. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 03-10 MIT-T 05-05-02.xls l ( " { $ ARCO Alaska Inc. Post Office Box 1 0-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 ~~ ~~ April 16, 2000 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: DS 03-10 Sundry Notice Variance Request Dear Mr. Wondzell: Attached is an Application for Sundry Approval form 10-403 variance request for well 03-10 (PTD 179-021). The request is for approval to continue PWI injection into the well with known production casing leak. Also attached is a proposed Action Plan and a wellbore schematic. If you require any additional information or clarification, please feel free to contact either Jerry Dethlefs or me at (907) 659-5102. Sincerely, þ~ Joe Anders, PE ARCO Problem Well Specialist Attachments RECE\VED /\PR 20 2000 ,A\aska OU &. Gas Cons. Commission Anchorage { ( <8 Co ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SU N DRY APPROVALS .., 1. Type of request: Abandon- Suspend- Alter casing - Repair well - Change approved program - 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3143' FNL, 4641' FEL, Sec. 11, T10N, R15E, UM At top of productive interval 1359' FNL, 1403' FWL, SEC. 11, T10N, R15E, UM At effective depth At total depth 1360' FNL, 3871' FEL, Sec. 11, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor , Surface Production Liner Length 81' 2666' '9003' 1030' 7" Size 20" 13-3/8" 9-5/8" Perforation depth: " measured true vertical Tubing (size, grade, and measured depth Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service _X (asp's 713875, 5938191) (asp's 714585, 5940000) (asp's 714591, 5939995) Re-enter suspended well- Time extension - Stimulate - Variance X Perforate 6. Datum elevation (OF or KB feet) RKB 64 feet 7. Unit or Property name Other - Prudhoe Bay Unit 8. Well number 03-10 9. Permit number / approval number 179-021 10. API number 50-029-20361 11. Field / Pool Prudhoe Bay Oil Pool Plugs (measured) Down hole choke @ 9332' Measured Depth 81' 2730' 9067' 9775' True vertical Depth 81' 2730' 5833' 9241' 9780 feet 9246 feet 9332 feet 8798 feet Junk (measured) ORIGINAL Gas- Suspended - 9213' - 9236'; 9240' - 9290'; 9406' - 9440'; 9460' - 9474'; 9500' - 9512'; 9533' - 9555'; 9560' - 9576'. 8679' - 8702'; 8706' - 8759'; 8872' - 8906'; 8926' - 8940'; 8966' - 8978'; 8999' - 9021'; 9026' - 9042'. 7",26#; L-80 Tbg @ 8360' MD; 4-112", 12.6#, L-80 Tbg @ 8475' MD; 7-5/8",29.7#, NT-80 Tbg @ 8496' MD; 5-1/2",17#, L-80, PCT @ 8566' MD; 4-1/2",12.6#, L-80, PCT Tbg Tails @ 8849',9344' ,& 9530' MD. Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2".Baker SB-3 Perm PACKER @ 8427' MD; 9-5/8" X 5-1/2" OTIS RH PACKER @ 8561' MD. 7" OTIS MRB SLVN SSSV @ 2164' MD. 7" x 4-1/2" Otis WD Packers @ 9310',9453', & 9517' MD. 13. Attachments Description summary of proposal -->< Detailed operations program - BOP sketch - 14. Estimated date for commencing operation 15. Status of well classification as: Approval of Sundry 16. If proposal was verbally approved Cemented 170 Sx AS II 500 Sx Fondu & 4000 Sx AS II 800 Sx Class G.& 300 Sx AS II 270 Sx Class G Oil- Name of approver Date approved Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed JeffY Defh,Ç u4c D ~ Title: Problem Well Specialist / (~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity - BOP Test - Location clearance - 75f)Ó -I ()h Mechanical Integrity Test_Q. "2. Y.J!Q;~ Subsequentform required 10- MGIlßL.I Rel1~ðfDl"\ '..1- 'JA\~ 4- d GOP'J ~ yu., &M. ::¡ ('!.J vu<; '"t' í~ t. (, f'r "",¡RIGINAl S'~NED'BY ,,\'?)f',.("t~:{f\ec\. p,A9;,~ Approved by order of the Commission Hobert N - Chnstenson Re . 0""" 0 Ò --Commissioner Date $ - 9 - 0° Form 10-403 Rev 06/15/88 .3.u:~~ SUBMIT IN TRIPLICATE X Water Injector On Iv Questions? Call Joe Anders at (907) 659-5102 Date April 20, 2000 ( ( DS 03-10 Waiver Request SUNDRY DISCUSSION AND ACTION PLAN 4-16-00 DISCUSSION Well 3-10 (PTD 179-021) is a water and gas injector that failed a recent MIT-IA. An MIT-IA conducted on 1/7/00 failed with a leak rate of 8.7gpm at 1450 psi. An AOGCC witnessed MIT - T against a tubing tail plug passed to 3000 psi on 3/12/00 indicating competent tubing. Wellhead sealant was pumped into the wellhead on 3/15/00 and another MIT-IA was conducted on 3/16/00. The MIT-IA failed with a leak rate of 1.1 gpm at 2125 psi. Because the leak was substantially reduced after sealant was pumped we suspect that the production casing hanger seals are leaking. This sundry request is to allow for continued injection of water into Well 03-10. The following supports the request: . A passing MIT-Tubing was performed on 3/12/00 to 3000 psi against a tubing plug, demonstrating competent tubing. ACTION PLAN 1. Allow well to continue water-only injection. 2. Perform MIT-Tubing every 2 years. 3. Record wellhead pressures and injection rates daily. 4. Submit a monthly report of daily pressures and injection rate. RECEiVED I\PR 20 2000 Aiaska OU & Gas Cons. Commis6ion Anchorage Well:O3-10 . Spud Date: 08-08-79 Original RKBE:64' Top of Formation: 9185' Annular Fluid:Diesel/SW 8.5 =ference Log:Diesel/SW 8.5 !f ARCO Ala81: [DC. - Prudhoe Bay API #:50-0¿~-20361-00 Completion: 04-04-93 Hanger Type: FMC Max Hole Angle: 45° @ MD: 5900' Type : rnJECTOR Status:Workover Hanger:27 , Angle @ TS:2° Angle @ 'I'D: Date: 00-00-00 Date:08-3l-79 Tie In: ALL DEP'l'BS ARE JUœ DRILLING MD TO TOP OF EQUIPM!:N'l' EXCEPT WB!:RJ!: NOTED. J L-1 ~-1 J-2 J-3 J-4 J-5 J.6,7 C-3 J-9 J-10 J-11 J-12,17 J-13 J-14,15 C-2 J-18 J-19 J-21,22 J-23 P.3 J-24 J-25 Jewelry (J) Depth Description 2163' 7' Otis MRB SLVN ID=5.963' 8358' Crossover 7' x 4-1/2' S369' 4-1/2' Parker SWS Landing Nipple ID=3.813' 8427' 9-5/S' x 4-1/2' Baker SB-3 Hydro Set Perm Packer 8453' 4-1/2' Parker SWS Nipple ID=3.S13' 8475' Crossover 4-1/2' x 7-5/S' S476' 7-5/S' Muleshoe CUt on End & Beveled Inside & OUt ELM Tubing Tail (Not Logged) 1 2 3 4 5 6 7 P-1 Min ID: 4-112. Parker SWS Nipple ID-3.813. 9 849S' 5-1/2' Top of Tubing Stub Flared to 6-1/2' 10 S536' 5-1/2' Otis SBR Assembly 11 S561' 9-5/S' x 5-1/2' Otis RH Packer 12 S566' Crossover 5-1/2' x 4-1/2' 13 SS04' 4-1/2' Otis X Nipple ID=3.S13' 14 SS48' 4-1/2' W/L Re-entry Guide 15 SS49' 4-1/2' Tubing Tail 8837' ELM Tubing Tail (Logged 09/18/86) 17 8566' FISH: Part of Tubing CUtter (Lost 03/93) Min ID: 4-1/2. Otis X Nipple ID-3.813. 18 9310' 7' x 4-1/2' Otis WD Packer 19 9332' 4-1/2' Otis X Nipple 1D=3,813' 20 9332' 7/8' Downhole Choke w/4-1/2' X-Lock ID=0.875' 21 9343' 4-1/2' W/L Re-entry Guide 22 9344' 4-1/2' Tubing Tail P-2 Min ID: 7/8. Downhole Choke w/4-1/2. X-Lock IDaO.87S. 23 9453' 7' x 4-1/2' Otis WD Packer 24 9502' 4-1/2' AVA BPL Nipple ID=3.7' wI BPI ID=3.34' 25 9517' 7' x 4-1/2' Otis WD Packer 26 9528' Crossover 4-1/2' x 3-1/2' 27 9529' 3-1/2' Otis XN Nipple ID=2.635' 28 9530' 3-1/2' W/L Re-entry Guide Min ID: 3-1/2. Otis m Nipple ID-2,63S' J-26 J-27 J-28 P.4 Casing and Tubing (C) Size Weight Grade 1 13-3/8' 72# L-80 2 9-518' 47# N-80 3 7-5/8' 29# NT-80S 4 7' 29# L-80 7' 26# L-80 5-1/2' 17# L-80 4-1/2' 12.6# L-80 4-1/2' 12.6# L-80 4-1/2' 12.6# L-80 4-1/2' 12.6# L-80 4-1/2' 12.6# L-80 4-1/2' 12.6# ,L-80 Top Bottom Description 0' 2730' Casing 0' 9067' Casing 8475' 8496' Casing 8745' 9775' Liner 0' 8369' Tubing 8498' 8566' Tublng-PC 8360' 8454' Tubing 8454' 8465' Tubing-Perfed 8465' 8475' Tubing 8566' 8849' Tublng-PC 9310' 9344' Tubing-PC 9453' 9530' Tubing-PC C-4 Perforation Data (ELM DEPTHS) (P) Interval Zone P'T spr Date COIIIIII8ntl 9188- 9208 4 2G 0 12-01-89 SOZ 9213- 9216 4 3 4 06-04-92 APERF 9216- 9236 4 20 4 06-04-92 RPERF 9240- 9249 4 9 1G 02-25-96 RPERF 9249- 9252 4 3 6 02-25-96 APERF 9252- 9266 4 14 10 02-25-96 RPERF 9266- 9272 4 6 10 02-25-96 APERF 9272- 9290 4 18 6 02-25-96 APERF 9290- 9292 4 2 0 12-01-89 SOZ 9354- 9394 3 40 0 12-01-89 SOZ 9406- 9440 2 34 2 07-07-92 RPERF 9440- 9450 2 10 0 12-01-89 SOZ 3 9460- 9474 2 14 4 07-24-86 STR 9500- 9512 2 12 4 07-24-86 STR 4 9533- 9555 2 22 4 07-24-86 RPERF 9560- 9576 211B 16 4 07-24-86 RPERF rRAC 06/06/92 Datum 8700' SS= 9298' MD 8800' SS: 9398' MD PBTD= 9732' TD= 9786' Revision Date: 03-15-96 by BMJ Reason: APERF/RPERF Previous Reason: 11-20-94 Well 03-10 (' RECEIVED þJ)R 20 lOOO Alas~a on & Gas Cons, Commission Anchorage Re: 3.:10 'jv1ITT Passed ( (" Subject: Re: 3-10 MITT Passed \ \ ~ - a èJ.. \ Date: Mon, 13 Mar 2000 13:52:20 -0900 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P1 041 @maiLaaLaroo.com> CC: tom_maunder@admin.state.ak.us Internal Jerry, Thanks for the additional information. I agree that tr)lng to repair the 9-5/8" failure before re-cementing the shoe is probably a good idea. Because you have demonstrated tubing integrity, and have some thoughts on the other failures, you have our approval to oontinue water injection for up to 30 days from today - April12 - to fix the problem(s) or request a permanent waiver. BlairWondzell 3/13/99. PRB Problem Wells wrote: > Blair and/or Tom: Yesterday John Crisp witnessed a passing MITT @ 3000 psi on > 3-10; it appears the tubing is in good shape. I am requesting temporary > permission to put the well back on water injection while we figure out how to > repair the IA x OA problem or decide to request a permanent variance via Sundry > Notice. The well injects a large volume of water (30k bwpd) and pressure support > in this area is important. I have some ideas on how to locate the IA x OA leak; > if we can find it we can decide if it's possible to fix it. > We will keep you posted on the repair status. Let me know about the temporary > injection request. Thanks! > Jerry Dethlefs > ARCO Problem Wells > ---------------------- FolV6rded by PRB Problem WellslAAI/ARCO on 03/13/2000 > 10: 14 AM --------------------------- > > 01/13/2000 12:55 PM > PRB Problem Wells > PRB Problem Wells > PRB Problem Wells > 01/13/2000 12:55 PM > 01/13/2000 12:55 PM > > To: Blair - Wondzell@admin.state.ak.us > cc: PRB Problem WellslAAI/ARCO@ARCO, Stephen L Ward/AAI/ARCO@ARCO > Subject: 3-10 MIT Failed > > Blair: As a follow-up on the previous message, our intent is to do the following > on OS 3-10 injector: > 1. Run a TTP and MITT to 3000 psi to verify tubing integrity. > 2. Cancel immediate plans for the CTD sidetrack. A sidetrack will be > re-evaluated if repairs are made to the wellbore. > 3. Consideration is being made for repairing the IA x OA leak, and OA x > formation leak with a cement squeeze. Considerable diagnostics and well > activities will be required for this option, but the end reSJlt should be full > pressure integrity on each annulus. > 4. Should the repair to the v.ell not be feasible, or should it fail, ARCO will > submit a Sundry request for injection into the well as-is. > Please let me know if you have any questions or concerns. > > Jerry Dethlefs > ARCO Problem Wells 1of2 3/13/00 2:13 PM Re: 3~1ÓMITT Passed (" ( > ---------------------- FofVt8rded by PRB Problem Wells/AAI/ARCa on 01/13/2000 > 12:33 PM --------------------------- > > 01/08/2000 05:38 PM > PRB Problem Wells > PRB Problem Wells > PRB Problem Wells > 01/08/2000 05:38 PM > 01/08/2000 05:38 PM > > To: blair_lMJndzell@admin.state.ak.us > cc: john_crisp@admin.state.ak.us > Subject: 3-10 MIT Failed > > Hello Blair. Well 3-10 is an injector, currently injecting 30,000 BWPD at 2000 > psi. It is scheduled for a Coiled Tubing sidetrack starting Feb. 2000. During > pre-rig pressure testing conducted on 1/7/00, the tubing x 9-5/8" MIT failed. > While attempting to conduct the MIT, the 13-3/8" pressure tracked the 9-5/8" > pressure. We were unable to get the Vltell to pass a combination MIT 9-5/8" x > 13-3/8" as the 13-3/8" shoe leaks. Pressure tests on the 9-5/8" hanger indicate > at least one of the seals has failed. > > The 7" tubing appears competent. The 9-5/8" pressure is 0 psi. If there was a > tubing leak, I would expect to see significant pressure on the 9-5/8" wth the > 2000 psi injection pressure. > > We would like to keep the well on injection while repair options are evaluated. > Shutting in the Vltell and allowing it to cool could complicate further > evaluation. The well is currently on injection at 30,000 BWPD, 2000 psi. We > reviewed the well with John Crisp on 1/8/00. > > I'll give you a call early next week to discuss well conditions. > > Joe Anders > Problem Well Specialist > ARCa Alaska, Inc. > 659-5102 > p1041@mail.aai.arco.com 2 of2 3/13/002:13 PM (' f TO: S tate of AI as ka Alaska Oil and Gas Conservation Commission Robert Christenso~ DATE: March 12,2000 Chairman MEMORANDUM THRU: ~ Blair Wondzell, ~ P. I. Supervisor 3'((~'à¿) John criSP~~ Petroleu~spector SUBJECT: MIT ~ PTD 179021 FROM: March 12. 2000: I traveled to Arco Alaska's DS 3 in the Prudhoe Bay Field to witness the MIT Tbg. test on well #10. The inner annulus pressure before test was 75 psL The tbg. pressure was 60 psi. The inner annulus valve was found to have a tag stating that the last MIT on the annulus leaked 1.2 gpm @ 2500 psL The tbg. was pressured up to 2960 psL The inner annulus pressure came up to 500 psL Tubing pressure stabilized @ 2630 psi after 15 minutes. Pressure on the tubing after 30 minutes was 2630 psL The inner annulus pressure was 500 psL during 30 minute test. The AOGCC MIT test form is attached for reference. SUMMARY: I witnessed the MIT on the tubing on AAI's PBU DS 3-10. OS 3-10, passed tubing MIT Attachments: MIT PBU DS 3 3-12-00jc cc. .::.:J. NON-CONFIDENTIAL MIT PBU DS 3 3-12-00jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Prudhoe Bay / PBU / DS-3 DATE: 3/12/00 Arco Alaska Inc. FIELD I UNIT I PAD: .' :};;Wj::~::. .." " " " , ' ' '" '" , , ' " """" """, , '" , " 15 MlN ' , "" "', ,',' ",',""',' ,",',,',',' " " " ," ::PRETEST ", ~T ART " , 3() MIN ' ' '" ' " :,':',", ",: '::",';:", ,'> '::,': ,;-:,', ::, ,::":' ':: , ,',' , ""', ,> ' , '" " " '" , ',..;, '::' ",;, ,':-:",',:-: ':' " '," '", ",',' "", ",' ,'" ' , ' , , " ':, :', ' """:',"",:: "':,, ,':' ,': ',' : ' '" :,::' , , " " " ,~~~~~ ..,' ::""",:",:"",'::':':",',,:"':, ',', , '" ':"TBG" .. " '::-:'.. !y~E",:,:-:: ': " ", ,,' ,,'," ':, ,'" ",', ',", :,',':.. :":::REG1,: " TSG,' ", " TIME: " TIM~ ,', TIME ' ", ".. ," ..,,' .., .. '," .. , , .. " '".. ":', ," "" :,', ' ': ',' ,':,..::' " , ,',',",'," "'..: "",:,,: '," ':.. ,',', , , ,..,', ",.., .." '" ,'....'..' , ' , ' " " ,',,',,'..' ': ,':, ':'" ',: ," ':' ': ': '" .., , \$f~lrN&i~~R' :,: ..' :,..:, " ~~J,'" ,::1EST'" ':':,A~N~:',,::' ",', ',' "CÃSING""':'::"""" 1:.~~:,',::;': :):: !~~T:,': ':",CSG ..::: ': ,":TBG ,," TaG' 'TBG START P F ,: :'~~.t¡~t~}i.~t~:'. ::' ,: rLYI,O:, 'rfP~': -:.. FLUID' ,;,::,:,::'Mlj";:::,::}::) :::~~~::::, :-:,PRES~" '::, ,P~ESS : ," ,CSG ,CSG CSG 'TIME '" , ',',,' ":'::'<:::,::;"',<;:::'?::' ':::,';' ";:"'::: , :',':' ',;' " , 'PRESS ' " ' ' ' ,.. .. , .. ',PRESS,,' PRESS " , " ..' PTD: 179021 Diesel 7,895 60 2,960 2,930 2,930 L- - Well #: 3-10 S M SW 8,427 95188/47#/ N-80 41/28 1974 75 500 500 500 1520 P COMMENTS: TIP set in nipple @ 8438'. Most recent test on IA leaked @ 1.2 gpm wI 2500 psi. PTD: Well #: 0 COMMENTS: PTD: Well #: 0 COMMENTS: PTD: Well #: 0 COMMENTS: PTD: I I Well #: 0 COMMENTS: ~- '-'" TBG. INJ. FLUID CODES TEST TYPE: ANNULAR FLUID: P.P.G. Grad. WELL TEST: F = FRESH WATER INJ. M = ANNULUS MONITORING DIESEL 0.00 Initial G = GAS INJ. P = STD ANNULUS PRESSURE TEST GLYCOL 0.00 4 - Year S = SALTWATER INJ. R = INTERNAL RAD. TRACER SURVEY SALTWATER 9.5 0.49 Workover N = NOT INJECTING A = TEMPERATURE ANOMALY TEST DRILLING MUD 0.00 Other X D = DIFFERENTIAL TEMPERATURE TEST OTHER 0.00 Distribution: orig - Well File Jerry Dethlefs , AOGCC REP SIGNATURE: John Crisp OPERATOR REP SIGNATURE: c - Operator c. Database c . Trip Rpt File MIT PBU DS-3 3-12-O0jc (Rev 9/23/99) c - Inspector 3-10 MIT Failed ( ( 79 - é) 2 } Subject: 3-10 MIT Failed Date: Sat, 8 lan 2000 17:38:54 -1000 From: "PRB Problem Wells" <P1041@mai1.aai.arco.com> To: blair - wondzell@admin.state.ak.us CC: john_crisp@admin.state.ak.us = Hello Blair. Well 3-10 is an injector, currently injecting 30,000 BWPD at 2000 psi. It is scheduled for a Coiled Tubing sidetrack starting Feb. 2000. During pre-rig pressure testing conducted on 1/7/00, the tubing x 9-5/8" MIT failed. While attempting to conduct the MIT, the 13-3/8" pressure tracked the 9-5/8" pressure. We were unable to get the well to pass a combination MIT 9-5/8" x 13-3/8" as the 1,3-3/8" shoe leaks. Pressure tests on the 9-5/8" hanger indicate at least one of the seals has failed. The 7" tubing appears competent. The 9-5/8" pressure is 0 psi. If there was a tubing leak, I would expect to see significant pressure on the 9-5/8" with the 2000 psi injection pressure. We would like to keep the well on injection while repair options are evaluated. Shutting in the well and allowing it to cool could complicate further evaluation. The well is currently on injection at 30,000 BWPD, 2000 psi. We reviewed the well with John Crisp on 1/8/00. I'll give you a call early next week to discuss well conditions. Joe Anders Problem Well Specialist ARca Alaska, Inc. 659-5102 p1041@mail.aai.arco.com da 'e. cl~. 'Þ ~ to P- Þ t2.O^- P afA"; ~. < PGLt-f>-7 (II. f." ~ ¥'"<B 5 C(flA- e ('é 7'0 1 of 1 1/1 0/009:25 AM If STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0, 1." 1. Operations performed: Operation shutdown Pull tubing - Alter casing - 2. Name of Operator ARCO Alaska, Inc. 3. Address P .0. Box 1 00360, Anchorage, AK 9951 0-0360 4. Location of well at surface 21341 FSL & 6381 FWL, Sec 11, T10N, R15E, UM. At top of productive interval 13591 FNL & 14031 FWL, Sec 11, T10N, R15E, UM. At effective depth 13571 FNL & 1403' FWL, Sec 11, T10N, R15E, UM. At total depth 13571 FNL & 14031 FWL, Sec 11, T10N, R15E, UM. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surlace Production Liner Length 801 27011 90401 10301 9311 feet 8777 feet Size 20" 13-3/8" 9-5/8" 7" Stimulate Plugging - Perforate lL Other - 6. Datum of elevation(DF or KB) 641 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-10i 9. Permit number/approval number 79-21 10. API number feet 50 - 029-20361 11. Field/Pool Prudhoe Bay Oil Pool 9780 feet 9246 feet Plugs(measured) PBTO Tag @ 93111 MO (2/25/96). - 23294 - Repair well - 5. Type of Well Development - Exploratory - Stratigraphic - Service lL ORIGINAL Junk(measured) Cemented 170 Sx AS II 500 Sx Fondu & 4000 Sx AS II 800 Sx G & 300 Sx AS II 270 Sx Class G Measured depth 81' 27311 90671 8745 - 97551 True vertical depth 811 27311 85331 8211 - 9241' measured 9213 - 92361; 9240 - 92901; 9406 - 94401; 9460 - 9474'; 9500 -95121; 9533 - 95551; 9560 - 95761 true vertical 8679 - 87021; 8706 - 87561; 8872 - 89061; 8926 - 89401; 8966 - 89781; 8999 - 9021'; 9026 - 90421 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 85661 MO; 4-1/211, 12.6#, 1-80, Tbg Tails @ 88491, 93441, & 95301 MO. Packers and SSSV (type and measured depth) Baker 8B-3 Perm Packer @ 8427' MD; Otis RH Packer @ 8561' MD; Otis WD Packers at 9310',9453', & 9517' MD; Otis MRB 8LVN @ 2163' MD. -, - ___-811. 11""", 13. Stimulation or cement squeeze summary ~~ t L r I V I: U Intervals treated(measured) see Attached Perforation depth: APR 1 7 1996 Treatment description including volumes used and final pressure AI~ska 011 & Gas Cons. Commission 14. Representative Daily Average Production or Injection Data AnCI10rage Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations lL Oil- Gas - Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation Signed ~~ ~. ~. Form 10-404 Rev 06/15/88 - - - 24612 16. Status of well classification as: -- 2081 -- 2068 Service injector Date '1-/5 - r h "" Title Engineering Supervisor 9 SUBMIT IN DUPLICATE " t (' 3-10i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/25/96: MIRU & PT equipment. RIH w/perforating guns & tagged PBTO at 93111 MO, then PU & shot 501 of perforations as follows: Reperforated: 9240 - 92491 MO (24) 9252 - 92901 MO (24) Ref. Log: BHCS 8/31/79. Added Perforations: 9249 - 92521 MO (Z4) Ref. Log: BHCS 8/31/79. Used 3-3/811 carriers & shot all perforations at 6 spf at 60 degree phasing with well overbalanced. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. RECEIVED APR 1 7 1996 ... ka on & Gas Cons. Commission Alas ~.nchorage ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9134 Company: Field: Well Log Description BL 12/5/94 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay RR Sepia RF Sepia Mylar PWDW 3-1 1 1 D.S. 3-7 1 1 D.S.3-10 1 1 D.S. 3-32A 1 1 D.S. 4-19 1 1 D.S. 7-19 1 1 D.S.9-21 1 1 D.S.9-21 1 1 D.S. 9-47 1 1 D.S. 9-49 1 1 D.S. 11-31 1 1 D.S. 11-32 1 1 D.S. 15-41 1 1 D.S.16-21 11-22-94 1 1 D.S. 17-7 11-16-94 1 1 D.S. 17-13 11-16-94 1 1 ~ J~ SIGNED: ~~-------------------- Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE:/) ¡f~C~I' ~8Ær ~C !/ ~ ^ q 4¡ 0 6' <iJ cf ~~ ~9. ~c).'f Co~ ? "FO~~ cs: C ~ð o~~. rcS:r¿, ,,~~ i'" ARCO Alaska, Inc. l P.O. Box 100360, A~!'" ¡rage, AK 99510 ~ ~ Transmittal #: 94012 ~" Date: Jan 19, 1994 Subject: ARCO Cased Hole Finals From/location: John E. DeGrey/ATO-1529 (907) 263-4310 Telephone: To/location: Distribution ~{'-I'2.z. 9t.t'2.c." -'\'\ßO 9Y- fø3 9c:.so - q~ro <6l-(QCø ~O-'Î?ca 2..- 7"1' 2. \~ I~~I~ ß':iSD -'1 (, --r':> . ¿ <1~ -t ~ ~ l~e~6<UÒ J 4R 't...\ so - J'l:~ 7- q~-d.~ \\~~-\"2..\I.o,-\' %~-~ ~e.~l~JG~}~'~ 98"Sö-lo\OO ~~4 ~ ~(~~(t,(~1 ~~~ ~SDO- 'ìC;;(g-¡ I~r.t-<;J~~J G,\<.Jco... ð'-"to~o q ~ Ll '1 1~SO - '1-::r-'èO 11-1~ 10000 -IO4'\.~ --=r-=r-oß ~Ooo -~l\D 0 ~-\q~ q~t>-\D\SO <12.. -In.. \'2.'-\b-\\~u.40 ~\.-t~ ~¡\rl"~6P.. \oo-~lqTO '\;- \535 \D$CO-\\ ¿cCo I D?oo - t \?L\. c:g 1'ß--S3 t~/~ 6m.å I2À.ÒO....vv-<,"1-\ IlO-GJ-::I It?O-\\-:r-=h> D T Ib1o- \800 q\- '?ß loocso - \bl{~O S If-l-:;c C;\ÞOO.,: '\.ß 2D * 02-08 The correct max. depth is 9850.0 F & the correct min. depth is 9550.0F ** 3-25A The correct API# is 50-029-21021-01 *** 14-04 The correct API# is 50-029-20320-00 ,~.;um,'",b,e"""of,.Reco, rds:'22,'.,"",.',,',',',i,',.,',"..,,"','.,ii,.,;.',.,'.,:.",',.".,:'":,',,...,',','.',:,.,','.','.',','.".,.,'.,""...",".""..'..,: ,"'" , """~':,' ,;ç¡)~~/':'T~r:'~" . John E. DeGrey""", PBOE Document Control Well Log Date Tool Type Run, Scale Co ntrado r Nurmer (M-D-Y) 1-33 01-05-94 CNL 1,511 Sch *02-08. 01-09-94 CNL 1,511 Sch 02-22 01-04-94 Perf Record l<o~ c.t\- 1, 511 Sch \ 03-10 01-~94 \n\~. GMt 1,5" Sch ~ 1\ 3-15A 01-08-94 Prod Prof 1,511 Sch~(" **3-25A 12-26-93 Pref Record 1,5" Sch A 4-30ST 01-07-94 Prod Profile 1,211&511 Sch {6<0. I < 4-32 12-26-93 Prod Profile 1, 111&511 Sch¥ 4-32 01-04-94 Leak Detect 1,511 Sch ~", 6-01 01-07-94 Oual Burst TDTP 1, 5" - Sch 6-02 12-27-93 CNL 7,5" Sch 9-13 01-05-94 Alpha TubinQ~ ' ~ ^, 211&5" Sch 9-29 01-03-94 1'1 BridQe PluQ 1 5" Sch c , 11-01A 12-28-93 Perf Record \ 1,511 Sch I 5 11-12 01-06-94 Leak Detect 1,111&511 Sch ~~ \ < 14-01 A 01-09-94 Complet Record 1,511 Sch 14-01A 01-09-94 Perf Depth Cntl 1,5" Sch ***14-4 12-27-93 Prod Profile 1,5" Sch '~~ < 15-22 12-27-93 Perf Record 1,5" Sch I 15-22 01-06-94 Perf Record 1,511 Sch I 16-09A 12-28-93 Perf Record 1,5" Sch 17-13 01-08-94 Patch Set Record 1 511 Sch , ð.' ' -~. "\rJ.\tJ- L n:PYn ,.,CQ}",~. c\ {ò~ 'C-Q.'UA,. ,~,.t ~;'::'>'~:'^"'1 ": . ,.;-,,« ',! " ' , r\:'1?~ M~~ Tv.,'o~ ~o.kck"~. ' Distribution: Central Files Chevron BPX State of Alaska Phillips ANO-8 Geology Exxon Mobil ARca Ala.. Inc. I. . Subsidiary of AtlanllcRlchfteidCornpeny Please acknowledge receipt by signing and returning a copy of transmittal. By: ~/~~, Date: RECEIVED ,:,." ,JAN21 '1994' ",,:,', , , , ' ',,', '\,":ì"':,,; , . , ' ' , ' AlasIca Oil & Gas ColIs. ~, ~"gi.,~p¡i; , :'.',"""",'" "c,':,:" ",',',",.,'~,,:¡:.',;,~,,!.",!,,',,',,"."',',,':,' ' .. ... " . ' ' .' ':. . ':" . '~' .. :,.;',. ..,,:: ",' " " ' { ( . ARCO Alaska. Inc. P. O.Box 100360 Anchorage. Alaska 99510 DATE: 4-30-93 REFERENCE: ARCO ~~ 75- 3(0-1-9 4-16-93 1-20ß.?- )q", 4-11-93 78"-<i -1-16 4-13-93 ~~ -- 2"'Z... 4-9-93 3-gf 4-10-93 ,r?"'~::I:œl" - 3-10 4-1-93 3-3184-qz..... 4-11-93 W"~ 24 -4-19 4-&-93 9-5A q3"'~((! 4-1-93 C¡õ-tf:?::> /9-28A 4-3-93 'Ð- 28A 4-4-93 14-23 ß';).-ßl 4-7-93 ~?- ,~'?> -14-34 4-12-93 14-41 q ~ -Cf t, 4-10-93 q)"-IO~ -14-43 4-9--93 16-31 q:Þ-'15 4-&-93 q~- t)&/ AGI~ 3-24-93 CfB -a.1 AGI-7 3-24-93 13- 3G) AGI-I0 3-29-93 Please sign and return Inßatab1e mp Setting Dual Burst TDTP (Borax) Production Static Press/Temp Pelf Record Tubing Cutter Production Static Pressure/Temp Pelf Record SBL/GR/~ PFC / CCL (packer Setting) Dual Burst TDTP ¡Temp (Borax) Production Dual Burst TDTP (Borax) Dual Burst TDTP (Borax) Production SBL/GR/~ SBL / GR/ CCL SBL / GR/ CCL /7 ~~ ~", Run I, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1,.15" Sch Run 1, 15" Sch Run 1, IS" Atlas Run 1, Z'&B' Sch Run 1, 5" Sch Run 1, 15" Sch Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 15" Sch . Run 1 , 5" Sch Run 1, 15" Sch Run 1, IS" Sch Run 1, fl' Sch Run 1, 5" Atlas Run 1, IS" Atlas Run 1, IS" Atlas attac~ed c;py 7 receipt of data. RECEIVED BY ---- - ~ R EyCOE ~ ~;3 D APPR OVED_~- MA Transl# 93054 A18sØ 01 & Gas c- ~l&I1 A't\ØIØI. # CENTRAL FILES ## PmLLIPS 1# CHEVRON PB WELL FILES D&M R&D 1# CLINT CHAPMAN , BPX 1# EXXON ## STATE OF ALASKA MARATHON TEXACO ## MOBIL Have A Nice Day! Sonya WaUace ATO-1529 ( STATE OF ALASKA ( ALAsKA OIL AND GAS CONSERVATION COMMISSiUI~ REPORT OF SUNDRY WELL OPERATIONS ,', 1. Operations performed: Operation shutdown - Stimulate - Plugging- Pull tubing ..JL Alter casing - Repair well- S. Type of Well: Development - Exploratory - Stratigraphic - Service .lL- 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2134' NSL, 638' EWL, SEC. 11, T10N, R15E, UM At top of productive interval 1359' SNL, 1403' EWL, SEC. 11, T10N, R15E, UM At effective depth At total depth 1357' SNL, 1403' EWL, SEC. 11, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Plugs (measured) 9780 feet 9246 feet 9732 feet 9198 feet Junk (measured) Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Size Cemented Length measured true vertical q: 4 Perforate- Other - 6. Datum elevation (OF or KB) '"/' KBE = 64'f1Jet 7. Unit or Property name Prudhoe Bay Unit 8. Well numb~ 3-1 0 ~ \ 9. Permit number/approval number 79-21/ConseNation order 258 10. API number 50- 029-20361 11 . Field/Pool Prudhoe Bay Field/Oil Pool Measured depth True vertical depth Tubing (size, grade, and measured depth) 7", 26#, L-80 to 8360~ 5-1/2", 17#, L-80 tubing stub @ 8498' flared to 6-1/2'~ x-over to 4-1/2" @ 8566~ 4-1/2", 12.6#, L-80 to 8476' Packers and SSSV (type and measured depth) 9-5/8" BakerSB-3permanentpacker@8427', 9-5I8"X5-1/2"OtisRHpacker@8561', 7"x4-1/2"Otis WD packer@ 9310', 7" x 4-1/2" Otis WD packer@9453', 7" x 4-1/2" Otis WD packer@9517' MAY - 51993 Alaska Oil & Gas Cons. commission Representat~yAveraÇle Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations .lL Oil Gas Suspended 17. I hereby certffy ~a\the foregoirg is !rue and correct to the best of my knowledge. Si ned V/~ Jc::>L,,- Title Drillin En ineerSu eNisor Form 1 0-404 Re'v 06/15 8 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 16. Status of well classification as: Tubing Pressure Service - ') é:~) Date,~ /.J~ 1:) SUBMIT IN DUPLICATE r .. ( DAILY OPERATIONS (' 1 BP/AAI SHARED SERVICE WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: PAGE: 3-10 NORTH SLOPE PRUDHOE BAY PRUDHOE BAY 50- ACCEPT: 03/31/93 03:00 SPUD: RELEASE: 04/05/93 12:01 OPERATION: DRLG RIG: WO/C RIG: DOYON 16 03/31/93 ( TD: 9786 PB: 9732 04/01/93 ( TD : 9786 PB: 9732 04/02/93 ( TD: 9786 PB: 9732 04/03/93 ( TD : 97 8 6 PB: 9732 04/04/93 ( TD: 9786 PB: 9732 04/05/93 ( TD: 9786 PB: 9732 SIGNATURE: 1) 2) 3) 4) 5) 6) CIRC OUT FREEZE PROTo FLUID MW: 0.0 MOVE RIG TO 3-10, TAKE ON SEAWATER, R/U HI-PRESSURE LUBRICATOR ON TREE, PULL BPV, CIRC OUT FREEZE PROTECTION F/WELL CIRC OUT GAS BUBBLE MW: 0.0 DISPLACE FREEZE PROTECTION FROM WELL, SET BPV TO NIPPLE DOWN, N/D TREE, N/U BOPE & TEST, BOLDS, ALL SCREWS VERY TIGHT, WORK FREE, ATTEMPT TO PULL TBG FREE, UNABLE TO MOVE SBR, CBU, GAS PRESENT, CIRC UNTIL WELL STABLE RIH W/WASHOVER PIPE MW: 0.0 CBU, GAS PRESENT, RU ATLAS, RIH W/JET CUTTER, CUTTER DID NOT FIRE, O-RING LEAK, RIH & CUT TBG & 8495', CIRC, PUL 5-1/2" TBG, TEST 9-5/8" CSG @ 3800 PSI FOR 15 MINS, MU BHA #1 & RIH W/WASHPIPE JAR ON FISH @ 8940' MW: 0.0 RIH W/WASHOVER PIPE, p/U DP, RIH TO 8244', p/U STORM PKR, SET PKR @ 30' BELOW KBE, N/D BOPE, CHG OUT FMC TBG SPOOL, INSTALL NEW 9-5/8" PACKOFF BUSHING, INSTALL WEAR RING, RELEASE STORM PKR. L/D SAME, RIH W/5" DP, WASH & REAM OVER FISH F/8464'-8517', TOP OF SBR, CBU, POH W/WASHPIPE, M/U SPEAR TO CATCH 5-1/2" TBG, RIH, SPEAR INTO FISH @ 8490', JAR ON FISH, WORK PIPE RIH W/7" TBG & COMP MW: 0.0 JAR ON FISH, NO MOVEMENT, RELEASE SPEAR @ 8490', CBU. DUMP & CLEAN PITS, REV CIRC & CHG WELL OVER TO SEAWATER, ADD INHIBITOR, POH W/SPEAR, L/D DP, PULL WEAR RING, RIH W/ 7" TBG, RIH W/7" TBG, M/U BVLN & HOOK UP CONTROL LINE RIG RELEASED 24:00 MW: 0.0 RIH W/7" TBG, M/U SSLN, HOOK UP CONTROL LINES, TEST TBG TO 5000 PSI, N/D BOPE, N/U TREE, SECURE WELL & DISPLACE TO 130 BBLS DIESEL FOR FREEZE PROTECTION, U-TUBE DIESEL, DROP BALL TO SET PKR, PRESSURE UP ON TBG TO 4000 PSI TO SET PKR, SET BPV, SECURE WELLHEAD & TREE, RELEASE RIG @ 24:00 DATE: (drilling superintendent) RE(EIVED Mú~ Y - 51993 , . n Alaska Oil ,& Gas Cons. comm\SS\O Anchorage ( "t \ . ARCO AJaska. Inc. P. O.Box 100360 Anchoraget~ka 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS íS--'?;:I..¡, 1-9 3-29-93 Leak Detect 1-11 7ï-57 4-2-93 Production 'iéf.-I'd-S 1-19 3-22-93 Production 1-22 %ê).-\Îl.\ 4-6-93 Perf Record '8to-l~ 1-29 4-6-93 Production 1-33 ß~- \ d,;\ 4-4-93 Perf Record ï~-lo~2.:8 3-27-93 InJ Prome 2-'11 77-lo ~ 4-9-93 Perf Record 7~-7~ 3-8 """"i~,' 3-28-93 Production 3-10;\"~' 3-28-93 Tubing Puncher 7 0 -(o~ 4-2 3-20-93 CNL 4-29 ~5-;lô'2.3-26-93 Static Pressure ~(þ-~ 5 4-33 3-25-93 Preas/Temp/Spin 5-11 77- 30 3-29-93 Static Pressure '1? - 7 ~ 6-3 4-6-93 Production/Gas Entry 6-9 7q -- 7'J; 4-6-93 Perf Record C'i)~ -Gf\ 6-18 3-30-93 Leak Detect 8-22 <ßd-- ß \ 3-26-93 Production I Ð J9-4A 3-22-93 Perf Record q?>-d., ~-4A 4-3-93 Perf Record qô-ô \ '-9-36A 4-1-93 Static Pressure 9;Þ- \ \ 0 -11-13A 4-9-93 Perf Record 12-11 ~\...-'-r~ 3-31-93 Production ~~-'~-l3-20 3-21-93 Perf Record 14-16 ~'-gtj 3-30-93 Production q ;t-~~ ~::~~~ ::~::: :~;: Record 16-30q~-7to 3-21-93 Perf Record q~\\S ~;:~g :::~~:3 ;:~ ::~::: ~"3-05 -<l::~: ::::::: ~~}~cressure ~;}-/4~ <~:::~ ::::::: ~~Y~crreS8ure Please sign and return th attached copy as receipt 1of data. RECEIVED BY -- --., d;¿~t£iJ(;) Have A Nice Day! "9"., ~ , \ Sonya Wallace % '~~ ~ APPROVED -....dJJ1- ATO-1529 ~~g ~~ ~,Trans. 93050 , CENTRAL FIŒS ~ <g; <:i , PHJLUPS , CHEVRON ' ~ ~ PB WElL FILES , CLINT CHAPMAN ' ,~. f BPX , EXXON"~ I STATE OF ALASKA IMOBL ~ Run 1. 1",5"&:25" Run I, 6" Run 1. 5" Run I, 5" Run I, 5" Run 1. 6" Run 1. 5" Run I, 5" Run I, 5" Run 1, 5" Run 1, 5" Run I, 5" Run I, 2"&5" Run I, 5" Run 1, 5" Run 1, 5" Run 1. 1"&5" Run I, 5" Run 1. 5" Run 1, 5" Run I, 5" Run 1, 5" Run 1, 5" Run 1. 5" Run 1, 5" Run 1. 6" Run 1. 5" Run 1. 5" Run 1, 5" Run 1, 5" Run 1. 5" Run I, 5" . Run I, 5" Run I, SIt (g ~~ ~, Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch . Sch Sch Sch Sch Sch Sch Sch Sch Sch ( (" ~~ ~.~ ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 11-3-92 ARCO CASED HOLE FINALS 10-3-92 Prod Prome Run I, 5" Cameo 9-28-92 Leak Detect (Flezatak) Run I, 5" Cameo 9-14-92 Inj Prome Run I, 5" Cameo 9-29-92 Inj Prome Run I, 5" Cameo 10-2-92 Prod-Inj (Flezatak) Run I, S" Cameo 9-19-92 Leak Detect Run I, 5" Cameo 9-26-92 GR/Collar Run I, 5" Cameo 9-27-92 GR/Collar Run I, 5" Cameo 9-25-92 Prod Prome Run I, 5" Cameo 9-14-92 Prod Prome Run I, 5" Cameo 10-2-92 Inj Prome Run I, 5" Cameo 9-4-92 Prod Prome Run I, 5" Cameo 10-4-92 Inj Prome Run I, 5" Cameo 9-26-92 Prod Prome Run I, 5" Cameo 9-26-92 GR/Collar Run I, 5" Cameo 10-5-92 Inj Promo/PITS Run I, 5" Cameo 9-2 9-27-92 Inj Prome Run I, 5" Cameo . -4 9-19-92 Leak Detect Run I, S" Cameo .'. - 't<. -45 9-27-92 Prod Promo Run I, 5" Cameo ~: ::: 10-4-92 Inj/Sh u t-In Temp Run 1. 5" Cameo "B .... . 14-1 - 10-2-92 Inj Prome Run I, 5" Cameo ~. " :i 10-2-92 InJ Prom. e (Flezatak) Run I, 5" Cameo ~..... 16- -~ 10-1-92 ' Inj Pr~mc Run I, 5" Cameo - 18-~~ 9-15-92 Inj Prome Run I, 5" Cameo ~. '~- i~ : '. 9-17 -92 Prod Prome (Fle".tak) Run I, If' Cameo \,.~1 16- 10-1-92 Prod Prome Run I, 5" Cameo <i? ~... ~ O." - -, 9-28-92 GR/Collar Run I, 5" Cameo ~~;: = 9-28-92 Prod Prome Run 1. 19' Cameo Û,.:>70 1 - 9-15-92 Prod Prome Run I, 5" . Cameo ~ 1 ; -:", - 10-1-92 Prod Profile Run 1. ." Cameo ~ D . Please sign and return e attac e copy as receipt of AGe E I V E D DATE: REFERENCE: RECEIVED Have A Nice Sonya WaUace ATO-1529 . MAR 0 9 1993 Alaska Oil &AGas Cons. Commission ftnc~,~g~ ) APPRO.YED_~- Trans' 92245 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON 'EXXON , MOBIL # PIDLLIPS . PB WELL FILES IBPX . # STATE OF ALASKA ,( ARca AJaska. Inc. P.O.Box 100360 Anchorage,AJaska 99510 DATE: 9-18-92 ( J ~~ ~", ARCO CASED HOLE FINALS 6-4-92 5-8-92 5-29-92 6-12-92 7-2-92 6-9-92 6-9-92 4-18-92 7-3-92 Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Run 1', 5" BLS Run I, 5" BLS Run I, 5" HLS Run I, 5" HLS Run I, 5" BLS Run I, 5" HLS Run I, 5" BLS Run I, 5" HLS Run I, 5" BLS REFERENCE: ?, - z, I 9- 1 0 $:::&_- ~ ~~-29-. Þ¡a-14-18 gt:íi 14-28 ~6g 14-29 =ð'3-(3~ 14-34 ,9l¿( ð~ 18-3 ~ ,; Please sign and return th at~A'" c~Of data. RECEIVED BY. ?/~- HaveANiceDa I CEIVED . ~ Sonya Wallace OCT 0 5 1992 APPROVED_- -- ATO-1529 Trans' 9220 Alaska Oil & Gas Cons. Commission Anchorage , CENTRAL FILES . CHEVRON D&:M # EXTENSION EXPLORATION 'EXXON MARATHON , MOBIL , PlDLLIPS PB WELL FILES R&:D 'BPX , STATE OF ALASKA TEXACO (' ARCO AJaska, Inc. P.O.Box: 100360 Anchorage,}Uaska 99510 DATE: 7-31-92 REFERENCE: ARca CASED HOLE FINALS 2...11 77-¿J 7-14-92 . 2...23STJ.2-/.).ø 7-14-92 71-/~ 1 2...35 7-13-92 3--7 ?¿-S-j 7-6-92 3--10 19-....1./ 7-7-92 3--141?-tY:;... 7-10-92 ~25 3¿-~' 7-5-92 if/-I 'I; 4-42 7-5-92 5-3 ?y-$I'r 7-6-92 g..2 76 -16 7-4-92 g..27 ¡J-~ 7-10-92 g..29J.r-I?¿ 7-7-92 g..363.)-~) 7-5-92 12-2 7?-):J.. 7-14-92 12-23 t9st-.ri 7-14-92 1,-2] 13--23A 7.4-92 j';J. -7/ 13-25 7..7..92 li'-~/ 14-2 7..11-92 ßõ-~1Jlfj...18 7-11-92 Prod Profile Prod Profile (Flexstak) Leak Detect Inj Profile IJ}j Profile Prod Profile Static Temp Inj Prome/Temp Prod Profile Prod Profile (Flexstak) Leak Detect Prod Profile Prod Profile Inj Profile Inj Profile Inj Profile Inj Profile Gas Entry Prod Profile (Flexstak) ( Run 1, 5" Run 1, 5" Run 1, Z' Run 1, 5" Run 1 5" Run 1: 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1. 5" Run 1, 5" Run 1, 5" Run 1,5" Run 1, 5" Run 1, 5" Run 1. 5" Run 1, 5" Run 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED B~--~'!.--9--Ä- Have A Nice Day! Sonya Wallace ATO-1529 APPROVED__- Trans# 92167 H CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION HEXXON MARATHON # MOBIL IS ~~ ~~ Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo # PIDLLIPS PB WELL FILES- R&D #BPX # STATE OF ALASKA TEXACO * The correct wen name is 2-23ST. RECEIVED AUG 1 0 1992 Alaska 011 & Gas Cons. Commission Anchorage (" ( ARCO Alaska, Inc. P.O.Box: 100360 Anchorage,J.Uaska 99510 DATE: 7-31-92 REFERENCE: ARCO CASED HOLE FINALS 1-4 'Ie ....)..6 7-12-92 CCL/Perf . 1-13 7?-r¡ 7-18-92 CCL/Perf 91-/J¡ 2-31 7-6-92 Prod/Press/Spin/Temp/Trap 3--10 7I-~ 7-6-92 CCL/Perf 91-3D 3--35 / 7..13-92 CÇL/Perf 9--9 11-1" 7..12-92 CCL/Perf 9--11 16 -11/ 7..13-92 CCL/Perf 11"'73/-117 7..11-92 CCL/Tubing Cutter a6,-78 ~11-16ST 5-30-92 MAl Acoustic Filtered Waveforms l11-1GST 5-30-92 BHC MAl Camp Slowness Curves a ø 12-6A?~-.s-y 7-11-92 PFC/GR ~ -100 15-9 7..13-92 Collar/Perf 15-28 7d -I) 7-12-92 PFC/GR. 8D-?1 17-3 7-12-92 CCL/Perf 77-30 NGI-l1 7-19-92 CCL/Tubing Cutter Please sign and return the attached copy as receipt of data. RECEIVED BY --þ;t.6.---- Have A Nice Day! Sonya Wallace ATO-1529 APPROVED_- Trans# 92173 (J ~~ ~", Run 1. 5" Atlas Run 1, 5" Atlas Run 1, 5" Sch Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas Run 2, 5" Atlas Run 2, Z' & 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas Run 1, 5" Atlas # PHILLIPS PB WELL FILES R&:D #BPX # STATE OF ALASKA TEXACO RECE\VED AUG 1 0 '992 Commission 110 01 & Gas Cons. A\asl\a' Anchorage # CENTRAL FILES 4# CHEVRON D&:M - 4# EXTENSION EXPLORATION # EXXON MARATHON 4# MOBIL ( ARCO Alaska, Inc. P.O.Box 100360 Anchorage,}Uaska 99510 DATE: 7-10-92 REFERENCE: (' ARCO CASED HOLE FINALS '73-1) 8 '! -..} 9/-/~ 2-32 9/-111 6-21-92 3-10 71->/ 6-20-92 3-26!)-I$"/ 6-28-92 4-14,J>-J¿ 6-28-92 5-5 7.>...1,17 6-22-92 7-5 . 6-23-92 9-38 6-30-92 9-39 6-30-92 12-1783.,fI 6-29-92 13-1£58..2 -IS? 6-27-92 13-29 8J -1; 6-19-92 13-32 J~ ...¡;¿.J 6-27-92 14-14J /-/tJ). 6-26-92 14-3683 -/63 6-26-92 16-73S"'.,)..()Ý 6-19-92 Prod Profile Inj Profile Prod Profile Temperature Prod Profile Prod Profile Inj Profile Inj Profile Leak Detect Inj Profile Prod Profile Inj Profile Inj Profile Inj Profile Prod Profile Run 1. 5" Run 1.5" Run 1. 5" Run 1. 5" Run 1. 5" Run 1. Ej" Run 1. 5" Run 1.5" Run 1. 5' Run 1.5" Run 1. 5" Run 1. 5" Run 1, 5" Run 1, 5" Run 1. 5" I¡L ~~ ~" Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Please sign and return the attached copy as receipt of data. RECEIVED BY__~-ß- Have A Nice Day! () . ) Sonya Wallace APPROVED_~__- ATO...1529 Trans# 92150 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PlfiLLIPS PB WELL FILES R&D #BPX # STATE OF ALASKA TEXACO II~\: " ,-, .: ~ " j , .. ".... ","'" f /"1 J .' STATE OF ALASKA 0 R ALASKe( '1- AND GAS CONSERVATION C( VtISSION I G J N A ¥ REPORTvF SUNDRY WELL OPì::RATIONS 'J) 1. Operations performed: Operation shutdown - Pull tubing - Stimulate L Plugging - Alter casing - Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2251'FLS, 613'FEL, Sec. 11,T11N,R15E, UM At top of productive interval 1033' FSL, 1156' FWL, Sec. 3, T10N, R15E, UM At effective depth 1488' FSL, 796' FWL, Sec. 3, T10N, R15E, UM At total depth 1531' FSL, 761' FWL, Sec. 3, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Liner Length 81' 2701' 9040' 1030' 5. Type of Well Development Exploratory = Stratigraphic - Service .2L. 9780 feet 9246 feet Perforate .2L. Other 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-10i 9. Permit number/approval number 79-21/92-146 & 92-182 10. API number 50 - 029-20361 11. Field/Pool Prudhoe Bay Oil Pool feet Plugs(measured) Fill @ 9497' MD (7/7/92) 9732 feet 9198 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 170 sx AS II 81' 81' 13-3/8" 500 sx Fondu & 4000 sx AS II 2731' 2731' 9-5/8" 800 sx CI "G" & 300 sx AS 9067' 8533' 7" 270 sx CI "G" 9775' 9241' Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 29550 43187 16. Status of well classification as: .j;;¿. J,L, C, f Title Sr. Area Operations Engineer Date 7. ' t(. SUBMIT IN DUPLICATE c¡ measured 9213-9236'; 9240-9249'; 9252-9272' 9406-9440'; 9460-9474'; 9500-9512'; 9533-9555'; 9560-9576' true vertical 8679-8702'; 8706-8715'; 8718-8738'; 8872-8906'; 8926-8940'; 8966-8978'; 8999-9021'; 9026-9042' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tails @ 8849'MD; 9344'MD & 9529' MD 13. Stimulation or cement squeeze summary Packers and SSSV (type and measured depth) Otis RH 9-5/8" pkr@ 8561' MD; Otis WD pkr@ 9310' MD; WD pkr @ 9517' MD & Bal-O SSSV @ 2156' MD R,ECE~VED JUL301992 . OJ. Casing Press~horagftubing Pressure 1713 1675 Service »'\.. Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation depth: 14. Prior to well operation Signed Form 10-404 Rev 06/15/88 849/9 JCA cc: SW, JWP ( 3-10i DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF ZONE 4 6/4/92: Reperforated: 9216 - 9236' MD (Z4) 9240 - 9249' MD (Z4) 9256 - 9266' MD (Z4) Ref. Log: SHCS 8/31/79. Added perforations: 9213 - 9216' MD (Z4) 9252 - 9256' MD (Z4) 9266 - 9272' MD (Z4) 6/5/92: Set a PXX plug at 9332' MD & dumped CaC03 cap on top of plug. Final tag at 9310' MD. Ref. Log: SHCS 8/31/79. 6/6/92: MIRU & PT to 8400 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant through the perforations (listed above) located above the PXX plug. Pumped: a)400 bbls Pre Pad, @ 55 bpm, followed by b) Shutdown. ISIP @ 1600. Resumed pumping: c) 951 bbls 50# Crosslinked Pad, followed by d) 1091 bbls Slurry, w/proppant stages @ 2 - 10 ppg, followed by e) 164 bbls Flush, followed by f) Shutdown. Placed a total of 194,277 Ibs of proppant in the formation. Rigged down. 6/7/92: Performed a proppant fill cleanout down to 9325' MD. 6/18/92 : RIH & retrieved the PXX plug from tubing tail. 7/6/92: Reperforated: 9406 - 9440' MD (Z2) Ref. Log: SHCS 8/31/79. 7/7/92: Performed an Injection Profile & tagged bottom fill at 9497' MD. Returned well to produced water injection & obtained a valid injection ratB. e Cf E I V E D ~lq -'0 "ß...I,I.( "\,! lIi10Ø'l;, '- '1.,- \J Û ,J ...It,: l\Ja«:'k" O. .~ IIJ> f' .., ,çt At CJ:. ~;¡as Cons. Gornmissi,on Anchorage STATE OF ALASKA. 0 RIG J N A 1 ALASKA{ '- AND GAS CONSERVATION cg I1lsSlð}J APPLICÄ liON FOR SUNDRY AP~ROV ALS ~ 1. Type of Request: Abandon Suspend - Alter casing Repair well Change approved program Operation shutdown - Plugging Pull tubing Variance Re-enter suspended well Time extension Stimulate Pertõråte X õiiiër 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at suriace 2134' FSL, 638' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1359' FNL, 1403' FWL, Sec. 11, T10N, R15E, UM At effective depth 1357' FNL, 1403' FWL, Sec. 11, T1 ON, R15E, UM At total depth 1357' FNL, 1403' FWL, Sec. 11, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development - Exploratory - Stratigraphic Service X 6. Datum of elevation(DF or KB) 64 7. Unit or Property Prudhoe Bay Unit 8. Well number feet 3-10 9. Permit number Casing Conductor Su rface Production Liner Length 80' 2701' 9040' 1030' 79-21 10. API number 50 - 029-20361 11. Field/Pool Prudhoe Bay Oil Pool RECEIVED "oj tad:;tJ It ¿ P lløt:.dJu N!&. 0 k JUL - 8 ;992 Qf.~4(. 9732' MD feet 9198' TVD feet Junk(measured) Alaska OU.& Gas C~ns. Corom\SSlOJ\ Size Cemented . , {A»911_épth True vertical depth 20" 170 sx AS II 81' 81' 13-3/8" 500 sx Fondu & 4000 sx AS II 2731' 2731' 9-5/8" 800 sx Class G & 300 sx AS II 9067' 8533' 7" 270 sx Class G 8745'-9755' 8211'-9241' 9780' MD feet 9246' TVD feet Plugs(measured) Effective depth: measured true vertical Perioration depth: measured 9213-9236'; 9240-9249'; 9252-9272'; 9460-9474'; 9500-9512'; 9533-9555'; 9560-9576' true vertical 8679-8702'; 8706-8715'; 8718-8738'; 8926-8940'; 8966-8978'; 8999-9021'; 9026-9042' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tails @ 8837' MD; 9530' MD Packers and SSSV (type and measured depth) Otis RH 9-5/8 pkr @ 8561' MD; Otis WD pkr @ 9310' MD; Otis WD pkr @ 9517' MD & Bal-O SSSV @ 2156' MD 13. Attachments Description summary of proposal L. 14. Estimated date for commencing operation July 1992 16. If proposal was verbally approved Detailed operations program - 15. Status of well classification as: BOP sketch L Oil- Gas- Suspended - Name of a rover Date a roved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Injector Date Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Approval No. .\pproved Copy Returned -1.: llo' C¡:J Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- 1(0"1 Commissioner Date 7 - I L.I . SUBMIT IN TRIPLICATE ~ 1 DEl _UPTION SUMMARY OF PROP( ,;AL ARCO Alaska, Inc. proposes to perforate produced water injector DS 3-10i at selected intervals within the Sadlerochit Sand of 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. The well is currently injecting produced water. Produced water will be in the wellbore during perforating operations. These perforations are in the Victor waterflood zone. The reservoir pressure at the perforation depths is approximately 3650 psi. Proposed Perforation Interval: 9406' - 9440' Ref: BHCS 8/31/79. R£C.£\\J£D JUL - ß ,gg~ . .. ro.\SS\ot\ . Gas cons. com A\as\<a 0\\ &.1~nc\1otagà. WDM: 6/26/92 ( 4 :5 2 , ( -. 1. ~OOO PSI 7" WELLHEAD CONNECTOR FLANCe 2. ~OOO PSI WIRELIN[ RAMS (VARIABLE SIZE) 3. ~OOO PSI 4 '1'" LUBRICATOR 4. ~OOO PSI 4 '1'" rLOW TU8E PACK-orr R£ßE\\JtD - ß ,~~?. J U L .. mm\Ss\Q~\ l'ons. co. . 0'\ &. Gas u A\as\<:a \ . 1~t\cbo.tagè, HIRELINE BOP EQUIPMENT ..... STATE OF ALASKA (t< ALASKAf - AND GAS CONSERVATION eet' AISSIONO II G AI A l ~ APPLICA'. ION FOR SUNDRY AP'~ROV Al.S . ~~ 4) ,. 1. Type of Request: Abandon Suspend - Operation shutdown - Alter casing Repair well Plugging Change apprõVëd' program Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2251'FSL,613'FEL,Sec. 11,T11N,R15E, UM At top of productive interval 1033' FSL, 1156' FWL, Sec. 3, T10N, R15E, UM At effective depth 1488' FSL, 796' FWL, Sec. 3, T10N, R15E, UM At total depth 1531' FSL, 761' FWL, Sec. 3, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Su rface Length 81' 2701' Size 20" 13-3/8" Production Liner 9040' 1030' 9-5/8" 7" 5. Type of Well Development - Exploratory - Stratigraph ic Service X 9780 feet 9246 feet Plugs(measured) Re-enter suspended well - Time extension Stimulate X pertõrãte õitiër 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-1 Oi 9. Permit number 79-21 10. API number 50 - 029-20361 11. Field/Pool Prudhoe Bay Oil Pool feet 9732 feet 9198 feet Junk(measured) RECEIVED JUN - 2 1992 Alaska Oil .& Gas Cons. Co.mm\S5Ïon Measure~gø;rrue vertical depth 81' 81' 2731' 2731' 9067' 9775' 8533' 9241' Cemented 170 sx AS II 500 sx Fondu & 4000 sx AS II 800 sx CI 'G' & 300 sx AS 270 sx CI 'G' Perforation depth: measured 9460-9474'; 9500-9512'; 9533-9555'; 9560-9576' true vertical 8926-8940'; 8966-8978'; 8999-9021 '; 9026-9042' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tails @ 8849' MD; 9344' MD, & 9529' MD Packers and SSSV (type and measured depth) Otis RH 9-5/8" pkr @ 8561' MD; Otis WD pkr @ 9310' MD; WD pkr @ 9517' MD & Bal-O SSSV 2156' MD 13. Attachments Description summary of proposal lL 14. Estimated date for commencing operation June, 1992 16. If proposal was verbally approved Detailed operations program - 15. Status of well classification as: BOP sketch JL Oil- Name of a rover Date a roved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Z-v Gas- Suspended - Injector Title Date ~!I !?v Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- 4c)Lt ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Form 10-403 Rev 06/15/88 840/9 JCA cc: SW, JWP Commissioner Approval No. c¡," - ..pprov0 Returned -~....~..._-~--~~ Date fo - 4 - q ~ SUBMIT IN TRIPLICATE 9~ I( Drill Site DS 3-10i ( dydraulic Fracturing Procedure ARca Alaska Inc. proposes to fracture stimulate well 3-10i. The stimulation will be designed to treat the interval to be perforated from 9213' to 9272' within the Zone 4 sand. The basic procedure is summarized below. 1. Perforate & isolate the interval 2. Pressure test tubulars. 3. Rig up Fracturing Service Company. 4. Pump propped fracturing treatment at 50 BPM using 200,000 lbs of 16/20 proppant and 2110 bbls of crosslinked gel 5. Pump Schedule 1100 bbl pad 70 bbl 2 ppg stage 10° bbl 3 ppg stage 120 bbl 4 ppg stage 130 bbl 5 ppg stage 140 bbl 6 ppg stage 150 bbl 7 ppg stage 150 bbl 8 ppg stage 150 bbl 10 ppg stage Flush stages 6. Rig down Service Company 7. Resume Produced Water Injection. RE€£\\}£D JUN - 2. 1992- rom\Ss\ot\ 0'\ &. Gas Cons. co Alaska 1 'Anchoragè (' ~ ( 4 " 3 5 2 4 3 2 , 1 COll[D TUBING UNIT BOP EQUIPMENT HJRELINE BOP EOUIPMENT v ,. ~oo PSI 7" WELLHtA[) CONNECTOR FLANGE 2. ~OOO PSI" '/16"PIPE RAMS , 3. ~ PSI" '1'" tM>RAULIC SliPS 4. ~ PSI" '1'" SHtAR RAMS 5. ~ PSI 4 1/6" BLIND RAMS 6. ~OOO PSI 4 1/1'" STUrFING BOX 1. ~OOO PSI 7" WELLHEAD CONNECTOR FLANGE 2. ~OOO PSI WIREllNE RAMS (VARlABl [ SI2E) 3. ~ooo PSI" 1 /6" LUBRICATOR 4. ~OOO PSI 4 1/6" rLOW TUBE PACK-Orr (' ARCO AJaska. Inc. P.O.Box 100360 Anchonge,~ka 99510 DATE: 5-1-92 ( REFERENCE: ARCO CASED HOLE FINALS ;Jø -~ð 1-4 3-24-92 'b -~S' 3-2 3-19-92 1i - -.., 3-10 3-20-92 "'-I'~ 3-17 3-21-92 a3-1 %3 3-22 3-20-92 81,./J1 3-24 3-22-92 4-1 ,.-'i~ 3-23-92 6-8),7g_~ 3-23-92 6-81 3-23-92 . 9-4 ?¿ -I/o 3-20-92 76-'18 9-6 3-20-92 80-ðÞ 11-4 3-30-92 ¡r,t-t1r 11-12 3-22-92 J¿-f'2Jf 11-24 3-23-92 32-/9/ 12-20 3-23-92 18-16~1-9/ 3-24-92 Prod Profile Prod Profile InjProfile Inj Profile Prod Profile Prod Profile Prod Profile OR/Jewelry Prod Profile Prod Profile Prod Prome Prod Prome Prod Profile Prod Profile InjProfile PITS Run 1, 5" Run 1, 5" . Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run I, 5" Run I, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" IV ~~ ~", Cameo Camco Cameo Camco Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Cameo Please sign and return the attached copy as receipt of data. RECEIVED BY_~_.£5::. . . BaveANiceDay! RECE1VED ~ Sonya Wallace' MAY 1 1 1992 . APPROVED- - - --- ATO~1529. Trans' 92090 AJaska Oil & Gas Cons. Commission Anchorage , CENTRAL FILES , CHEVRON D.&:M , EXTENSION EXPLORATION 'EXXON MARATHON , MOBIL , PmLLIPS PB WELL FILES R&:D 'BPX , STATE OF ALASKA TEXACO ,:) ¡:;. C tJ (I L :-"1 .:.~ t< (:i, I N C ^ (' ( ( F:' ^ (J. r: :J \ 1 0 ø 3 Ó c\ ANCHORAGE, ALASKA 9'?~) ,¡ ø ./ D(~ Tl: i '21-23-'~ii ". -'. .. , . - - ~ " . ",' ...,.. !:;.:I:: F E ¡~~ [NCE : i~F~CI] Ci~SED !-iDLE FINtlL.~~ 7t.t.-ó! :;:'-'7.)V :3-2i -9i F'F;~E'-FF;~I:iC INJ F'FdJFILE FUhl í, 511 C{'-¡MCO 'ð ;;. -1.>-0 2 - 2 3 ~ 9 - ,,~ - 9 í F' I:;~ 0 D F' I:;~ D F I L I:: b.: U i\/ i.. :5 B C Pt /1 C: U ':);;.. - 96 .'-:, .... .-:. l. /" C) -. '-:' 7 - C:O ~ F' ITS h: U N 1., 5 II C I::j Ì") C [I q Q ."\À 2 - 2 '~i:~"""'-- 8 - 2 :3 - 9 .j PIT S F: U N i.. ~) II C tÜ1 C 0 :-: *, 2 - 3 0...- 9 - 4 - 9 i G R / eeL F~ U N i, 5 p C ~~ M C [I t\ \' \ () > I ~5,-'j (~~ 9 -'í 6 -~' i I N .J F' F: 0 1::- I !- I:: ¡:;: U ~"! i.. 5 n C i~'1 h ~:: Ct 7/:>3 ~:; ..- i:.¿......-- 9 -- i 5-17' i I i~~.J F' F:() FILE F;.:UN i 5 II C ~:'I h C [I 7~'" 'II 3 - i 3 L-- 9 - i 5 - 9 1 L E f~ K DE TEe T r~: U N i., 5 II C (=Ü'i C [! ,,9,.'1). 3- i s.~ 8-3Ø-9 i F'¡:;~(ID F"F~OF I LE ¡:'.:UN i I 5 If CAf1CO ( 7_.i '7../" (j>-í 9-9i JEWELRY' !:;.:Ur\! i .' 511 C(~.¡i'iCIJ ).. ....' 11,/0 3.-. i ''?v S)-'í 9-9 i I NJ PF:DI:;' I L.E Fo:I..Ji\! 'j, 5 ij [(-¡r'IL:] 3tf--a3 3 -- 30"'" 8-28-9 í ppü D PI~~UF I LE I:;:UN í.. 5 II Cf'1ivojCû . .,. ,It! -'11 3~ 34 ....- .8-:- 2 9-9 i . ::,:~;;:~~':~f'R 0 D .. P R I] FI L E ,;" 'i¡'::::~.'.i',.'..'.,:;,."'. RUN : i;,~:~':5~.:,::¡~:t:,;~ii,~;:::,~;;,C-AM~: û. . 1'''''/ ')HH~ 4-4"'- ß-3'¡ -91'.' P~-;:OD F'F:OF ILf::. PUN. i.. ~) a-"""."""tAi\iCú 7 f - 1'1 -4 ...."? v- 9 ... :2 .- '7' 'j P ¡:;~ 0 D ¡::. F;~ U F I !... [ F: U i"'~ 'j ::~ " c ~~ r'¡ C I] 11-) ? l~. .... ,¡ 5 \--" (.~.),.-:2 3 - ':,? í ,j E !.4 E !..J~.~ "'j' ¡/ G h:....¡ C: c: L .... ït; G. I~~ U (.! 'i., ::: II C (:1 Iv) C tJ 8}~" J" -4 '-' :~ ,;;. ~. (;,:' - .j t~ - 9 i PIT S f:~ U N '1! 5 II C tl f'1 C 0 C\ \. ~ \. -4 -.. :.3 7 '--'" '7' .- i 3 - ? i L E (:11< DE T E:: C T !~~ U N í., ,.¡ (1 I C .-:-:\ (1 C D I"L[(',5'E SIGN A:;?TLJF\N l;E r~TT(,'CHREër\ V'E ÖECEIF'T OF DAïA. F:ECEIV[Ð B~~_"._-_. -------- OCT 2 8 1991 H (:.1 \l E: tt N ICE:. J:> ,;:¡ Y' ! ......: Alaska on & Gas Cons. commiSSion~. . SONYA WALLACEr.,,-,~"::~.:.:... ...,..:.:ÞJ1C~O~gF~PF\OVED . ....__..~. ::' i~:: T I] ",,'í ~:) ~.::: (.;.:0 T F: ti N :'::... :::: (.;.:' ,¡ .5 l~ :::~; D I STP I E:UT ION JI. ... .R.. ... CENTF~AL FILES CHEVF~ON D ~, ì1 E ::( TEN S' I U N E:. ~< F i... U ~< ('1 .,. I I::) i.'~ EX>::üN MAF~A THON M D B I L, ... ... PHILLIPS PB WELL. r':ILES h: '~": D E.:!.;'/ S'1 t1 -¡ I::: U F ¡:1 L (1 ::';: 1< f~ T[Xf-=¡CD .11. ,1' .a. ... .a. T JI. ... .It. or .)i; THE c:: Ct F: [ E eTA F' I ~:: F C) ¡:;~ :::: .... 9 I S' :~: () ... () ~.:: S;' -.. 2 ø ,¡ :; 3 . :I~ 1\- THE:: C (j F: h: E eTA F' I:::: F U F: ~? .-. 3 () I S ~5 () ..- 0 ~~ (,;:< - :2 2 2 0 ;~: " .j(. :¡(. ':A: THE c:: 0 F: E E eTA F' I ~:: F () ¡:;~ 4 .m 4 T S' ~:; () -. (:1 :~ 9 .-. 2 ø 0 '~;' 6 4 CD~r (:1 h: c:: U (::11... (I S 1< tl ¡ I (,) C ^ :::', C) ^ I.;: 0 )( i 0 (-) 3 Ó 0 ANCHCRA~E1 ALASKA D(~TE: -." ......,. . 4--4....<11 ( ~ï<?~) i ø REFERENCE: ARC a CASED HOLE FINALS )""1 ? :.':)"-2 :":).... :~~ 3",,4 ~':~; .... i (.) 4 -- ~;.~ 6 ó.... ;.~ 'j "(',,,,16 "?,..J4 ~II: 'j '1 .... <y 1 .j .... ~,:: i:~ 13....1('; i :3....20 i 3""~!.3A .t ~:).... 'j 'í 1 t)'-2 i B.... i i 2 .... 'j 1 -- <;> i 3,-, i 6'-<;' i '1"" 'j }3-"91 3--17-91 :::~ -. 'j ..? -.. <¡i 1 'i ....~:> ....9 i 3""Ó....9'1 3,,,,'i 4..-9 i :::~ .... 'j ~:>.... \;;' i 'j .... '7 .... (? i 'j ",,'j :..~.... 9 1 ::3"-16--91 3 ",,'j "?.... 9 1 :'3,-1 6--<y 1 2-"13--91 2-,,2:3,,-91 3....B....<?1 .. .,.., "''',.'"". . . PRODUCTION PROFILE I...Ef'il< DETECTIDN SP I NNEf~/'rEi'rjp INJECTION I N,.JECT I ON PITS PITS PITS I N..JEC'"j I ON,/TEiv¡P PITS PRODUCTION PROFILE IN,JECTIDN INJECTION I N,JECT I ON P E F~ F B F~ E (.~ I< .... D 0 I/~ N SPINNER/INJECTION PITS . , '..' - ,~.. '."." '." ,,~," ..,' " (" I:~ 1...1 N 'j I ::; n I~: U N i., 2 n ,~~) II ¡:~~ UN. 'j I ~:> II F:: U N í I ~} n F:UN 'j ¡ ~:~: II F~I.JN í" 5 u F;: U N 2 ¡ ~::; II F~ U N 1" ~:> n ¡:::UN 'j., 511 F, U N 'j I ~:) II ¡:~UN '1 ¡ ~:~. n I~ UN; I ~) u f~ LJ N i ¡ ~~: II I~ U N i., ~>' F<UN i 1 ~:~:. I~~ U Ni" 5 II HUN '1, 5u PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT Of DATA~ RECEIVED BY 00. ..,..,.',.. ;~,;.:".'."'."'. . ... r,\ -. ,... . .... ~,~ AÌ\I\A f\ A 1M .-. .... - .. - -- - ..~ L _..~ ~'.J! ~'_I.\ot~... 1 H A V E A NICE DAY I... S'H~~F~()N ~ I I...SON A TO'M' i ~:>2<j> .>r"';:. ",DI STI:~ I BUT I ON ., .- ..,"..L".":,LJ?t~~I~~!@~;,.;:~2;,:.:" ;::.. ,,,." . :::: CENTRAl..'.I)f ~J':E$.>. ~~.~ CHEVRON ~:: :~~;,;;:.:, .j'!~~~".",' .~........ D', ð. '~M":'.~¡o",,,~>:.;.. ¿'~,T:' :U: EX.f~~...þl~}!,;PN.t~,þ:~F;:::~q.f~A.T I ON--". .II. EXX "r'~"'.~. ".,,;;:,'->.'¡"i\'.'.~¡"" 'W' ::, ;' .~";'ii.","" ~'. '.."" '; ;,~i. . MAF~^ I HON.}.,";¡ ~'../~:" ',:",¡j- .'~,..__.,. ... . .II., MOB I~:' ,;~,.:.t'.!:', ":' ,'. :,..., :,':~' L. '11' .......,. .~!' " , '., " , . '''' .............. "''''''''''''''''''HIfI'I'\''~'''~r.:::''r,t,~~'IIT''''''I''.'''''.''.''''''' ",~.' . , . ~,(. THE cor-':HECT AP I~: FOR:.:,;f6~2, I oS' 50'M'029-20~>44" II" ,,,. '''''""'11'-' '.., .':" ..~'" .....",..,...".,,,,1, , .\. "'.' ..... . ,:.".,~ ....... . .. . ., .. ..~...' '..'"'' .,' ,'... "'" . . .,.,..~.J ." .., ; ,..:. ,'.' , '" ;... ¡ . ,.oJ. ' ..... ..."......~.. . :,¡ """ ."''''-'''...' .. ""'"','" .....~ ..l "'''''''''''' ,..,." .....,..¡...,,~.I<\IoW..~.......~,...,,~ ~""""""'-"""" " ",........"......,. "". .-",. ."""."~".'" .....".. ...,., . . ,.'" .., .... . . ...........". . ~.'" ."... ,..... ..... . .....,.....,~,.~ ... (.~PPI"'OV ... 1ï~ A~ s:~ " ~ 10 ~7 2 M.o . '.".""""'''''''"'', ,''',Ih'~.'' ' .IL 'W PHILLIPS PI? WELL. F'ILES ' F\ & D BPX..,.~. ..-". ...' ......"'., STATE OF ALASK(.~ TEXACO ,II. 'II' ,II. "If , ¡ , .......,...-......~._., ...........l.. ......_~'..~,....,~..-. .."'-' l . . f/. ... .. .. ~«: '9'~~) ~:() {<'/ .~'~ ," f .I ¡". .---- .~~.s:~. ,9 {9 0 ,,\~ l..ò - ç -:.,:.}, ~t? ~:;- (0 'C) Ç/t$' . -0,. '~ .~. t~, ~~ HI:;~S C (~'I ì'1 C 0 HI:;~S C¡::'II'iCD C(ìi"\CD H¡:;.:S !--iF< ::;' Ctìì"jCU C i:~ r..j C CJ H¡:;~S HI;\~ S C f~1 [,'j C U C I:~ r" C (J C i~~ !,.t C U H/:<'s' ~ H¡:~S . HI';~S t , 'f' STATE OF ALASKA, ALAS~'.- .AND GAS CONSERVATION f" .mSSION REPORl uF SUNDRY WELL OIJt:ñATIO 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2251' FSL, 613' FEL, Sec. 11, T11N, R15E, UM At top of productive interval 1033' FSL, 1156' FWL, Sec. 3, T10N, R15E, UM At effective depth 1488' FSL, 796' FWL, Sec. 3, T10N, R15E, UM At total depth 1531' FSL, 761' FWL, Sec. 3, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 1. Operations performed: Operation shutdown - Pull tubing - Effective depth: measured true vertical Casing Conductor Surface Production Liner Length 81' 2701' 9040' 1030' Stimulate - Plugging - # ~ Perforate lL Other lL 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-10i 9. Permit number/approval number 79-21/9-813 10. API number 50 - 029-20361 11. Field/Pool Prudhoe Bay Oil Pool feet Size Cemented Measured depth True vertical depth 20" 170 sx AS II 81' 81' 13-3/8" 500 sx Fondu & 4000 sx AS II 2731' 2731' 9-5/8" 800 sx CI 'G' & 300 sx AS 9067' 8533' 7" 270 sx CI 'G' 9775' 9241' Intervals treated(measured) See attached Treatment description including volumes used and final pressure Alter casing - Repair well - 5. Type of Well Development - Exploratory - Stratigraphic - Service X 9780 feet 9246 feet Plugs(measured) Perforation depth: measured 9460-9474'; 9500-9512'; 9533-9555'; 9560-9576' 9732 feet 9198 feet Junk(measured) true vertical 8926-8940'; 8966-8978'; 8999-9021 '; 9026-9042' Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tails @ 8837' MD; 9530' MD Packers and SSSV (type and measured depth) Otis RH 9-5/8 pkr @ 8561' MD; Otis WD pkr @ 9310' MD; Otis WD pkr @ 9517' MD & 8al-0 SSSV @ 2156' MD , .""" 'If 13. Stimulation or cement squeeze summary UUL 21419911 iUa::)j~(il.oil.& Gas CÒns.. Comm[ssXt,lf! Reoresentative Dailv Averaae Production or Iniection Data f - C lorag'i:. Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. r C-. ~ 14. Prior to well operation Si ned Form 10-404 Rev 06/15/88 429 SLW cc: J. Gruber, ATO-1478 25036 33335 16. Status of well classification as: 753 1870 Service Injector Title Sr. Area Operations Engineer r(2c>/9D Date SUBMIT IN DUPLICATE 0 SH (' ( ( DS 3-10i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR INJECTION PROFILE MODIFICATION 11/25/89 : MIRU, & ran Temperature and SBHP Logs. POOH. Rigged down. 11/29/89: MIRU. RIH and spotted 2.635" PXN plug at 9510' MD. PT 9-5/8" to 2000 psi. Tested good. POOH. Rigged down. 12/1/89: A CTU squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. Fluid packed backside of wellbore w/250 bbls of seawater. RIH w/CT and layed in 45 gals of 16.7 ppg mud on top of PXN plug. Pumped 85 bbls of Class G cement, squeezing perforations at: 9118 - 9208' MD Ref. Log: 8/31/79. 9216 - 9236' MD 9240 - 9249' MD 9256 - 9266' MD 9272 - 9292' MD 9354 - 9369' MD 9369 - 9394' MD 9406 - 9425' M D 9425 - 9450' M D Sqz'd (possibly leaking) Placed 66 bbls of cement behind pipe at 1450 maximum squeeze pressure. Contaminated cement with 120 bbls of bentonite/borax contaminant. Circulated out contaminated cement from wellbore. POOH. RD. 12/2/89: A CTU resqueeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. Fluid packed backside of wellbore w/seawater. Pumped 69 bbls of cement, resqueezing perforations at: 9118 - 9208' MD Ref. Log: 8/31/79. 9216 - 9236' MD 9240 - 9249' MD 9256 - 9266' MD 9272 - 9292' MD 9354 - 9369' MD 9369 - 9394' MD 9406 - 9425' MD 9425 - 9450' MD Sqz'd (possibly leaking) Placed 27 bbls of cement behind pipe at 1500 maximum squeeze pressure. Contaminated cement with 150 bbls of bentonite/borax contaminant. POOH. RD. 12/3/89: MIRU. RIH & circulated out contaminated cement. POOH. Rigged down. ( DS 3-10i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR INJECTION PROFILE MODIFICATION 12/4/89: RIH & tagged bottom at 9439' MD. 12/29/89-12/30/89: MIRU, and underreamed cement from 9250 to 9479' MD. 1/1/90: RIH to pull PXN plug. Plug pull failed due to fill on top of plug. POOH. 1/2/90: RIH and performed a fill cleanout to 9514' MD. RD. 1/3/90: RIH to pull PXN plug. Pull attempt failed. POOH. 2/1 6/90: MIRU, & RIH w/fill bailer. Tool string stuck at 9457' MD. Fished out tools. RD. 2/24/90 : MIRU, & RIH w/fill bailer, and bailed fill to 9481' MD. RD. 3/3/90 : RIH and performed a fill cleanout to 9508' MD. RD. 3/4/90: RIH to pull PXN plug. Pull attempt failed. Fill & scale on top of plug. POOH. 3/14/90 : RIH w/CT to 9498' MD. Pumped 15 bbls of 15% HCI, followed by 5 bbls 12-3% HCL-HF. Attempts to make hole below 9498' MD failed. POOH. Rigged down. 4/5/90-4/8/90 : Drilled out fill to 9501' MD. POOH. RD. 4/20/90: RIH w/CT to bottom, and jetted to 9506' MD w/47 bbls 15% HCI. Displaced w/gel. RD. 4/24/90: RIH w/fill bailer, and bailed fill on top of PXN plug. Pulled plug. RD. Returned well to injection and obtained valid injection rates. ARCD ALASKA, INCA P"O.. BDX íO()3o:SØ ANCHORAGE, ALASKA DATE: 6-1-90 REFERENCE: ARCO CASED HOLE FINALS 1 -17 5-3-90 ;-19 5-4-90 2-13 5-;3-90 2-13 5- i 4,-90 2-.2B S:-8-\j'0 3-10 5-10-90 4-9 5-14-90 7-20 5-1f}-90 7-23 5-1 1-90 7-28 5-10-90 i .t -22 5~.4-90 i 1-22 5-4.-90 ; 2-; 5--9-90 15-13 5-10-90 i 7--; 2 5-; 1-90 18-20 5-9-9<1 ( Si ii ~::: i (~t PERF RECORD PEF.:F RECORD PERF ¡:;~ECORD POST FI~~(~C TEl1P SUF~VEY PRODUCTION PROFIL~ INJECTION PROFILE INJECTION PROFILE PEr~F F~ECOF~D POST FRAC TEi"tP PERF I~EC()I~~D ÃCOUS CEMENT BOND PULSE ECHO CEMENT (PET) PRODUCTION PROFILE eCL TEì11:' SU\,VEY COLL~,R PRODUCTION PROFILE RUN 1, 5 I ¡::~ '-' N i 5 I RUN i 5 I F~UN;, 51 F\~UN 1. 51. HUN i., 5 II FUJN 1 I 5 I I~~ U Ni,S 11 RUN i., 5: I I:;~UN i.. 51 F~UN i, 5 It r~UN 1 I ~) I HUN 1, :~ø r~~UN i., 51 f\~UN 1, 511 I:;~UN i I ~51 PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA4 F.:ECE I VED BY .;~E'VED _M____-_-_M---....--.-----.- I-IAV'E A NICE DAY! Sf-'LL Y HOFFECKER ATO-1529 ... c 11" .ft, ". .L .'11" ... '11" ... 'If" . JUN - 4 1990 (ffz . iss\on A1áSRa QU & Gas Cons., corom A P P F~ 0 V E D - --- ~nchorage TF.:ANS::= <1<1203 DISTRIBUTION .a. 11" PHILLIPS F'B l,JEl..L FILES ~~ ~ D . BPX STATE OF ALI~SKA TEXACO CENTRAL FILES CI-IEVFHJN D & M EXTENSION EXPLORATION EXXON ~1ARATHON MOBIL .R. ,.' .11. 11" HLS HLS HLS CAì"~CU Ctoil"ICU C ¡:1 i"'í C I,] C¡::,hCC:r HLS C?ihCO Hl..S I-II._S HLS Cf~t'tCO C A ì'i C 0 ct.,~'tCD Cr;ì'iCO (' ¡::'I h~ [: 0 ,.i l- ¡:; S ¡< ¡; .. I (,) C ... F' ... C). F::U>< i (')()36') (?~'~5 i () ANCHORAGE, ALASKA D(iTE:: i:;~EFE!~ENCE : i .- i ¡:'~I 2--~3 ....' 3--'j.0 4'-:~2 i -'.r 1::- i .- ._~ ,¡ 3-,:::: í 3-'7' 'i ::)'-22 ,,4,-13 '1 -'}-2"? i 4,,-3 i i 4-36 ~~- ,) 4-90 ARCO PRESSURE DATA i '\ -:23-i:39 i i -'30--8\,;,:' i 2'-4--8S,:; i i -25,-,89 BHP--ST j:~ TIC BHP---ST ¡; TIC: BHP-'-ST (:¡ TIC :8HP-"-ST ¡; TIC ( G¡:~I::ìD lENT GF~¡:1)).!: ENT C;. ¡~ {:¡ DIE NT GF~Aj)IEi'~T Gr';~~~D lENT GP¡;D I F':NT G r-:~¡:,~ D I Ei\!'r GPt.¡D I Ei"'~ r Gí::~~~D lENT G¡:;~¡~ID I ENT GF~r:-~DIENT GI:;~~1DIENT G¡:;'~I:~ID I ENT C(.~hC[l C (1 ¡v¡ C C) C I:':' ;',\ C C) C(~~iCO C(liv\CO C {~ i'i C U C t.¡ j'''i c:: 0 CI{:¡(1CD C tl j\') C [I C(iMCO Cl:ìl1CO G{it"¡CD Cl1MCCi PLEASE SIGN AND RETURN THE ATTACHED COpy AS RECEIPT OF DATA~ ¡:;'~ECE I VED B'Y I-Iti\lE A NICE i i -:24-t39 1:: (,.1 FI -. - ~; -r A ..c I C; ?-4--+-- 2 7 -. 8 '7' 'j "i -24-'B'7' '1 2--i Ò'-G? BHF"'-'-S'T r; TIC :t:HF'-'--ST ¡:~ TIC:: BHP,--STI:'-ï TIC BHP-'-ST ~~ TIC BHP-'-ST ¡; TIC BHP'--ST ¡::¡ TIC BHF'~--ST ¡:'.¡ T'[ G BI-IF'---ST{~TIC i 2- i ,~,-a9 i 2-.;S--B9 i 2,-, i 7..-89 i 2-."'~.-8'~;1. i 2--1 ¿,--8Si ß~ --------------------- DAY! RECE\\JEO fEB 1 Ó 1990 . m\ßß\Q.t\ A\aska Oi\ & Gas cons., CoIn Anchorage . DISTRIBUTION Sf~LLY' HDFFECKEF\~ ¡:~TO-i 529 .ø. 'r CENTRAL FILES CHEVRDN. D ê't ì"'i EXTENSION EXPLORATION EXXON" . MARA'fHON' MOBIL .a. y .II. .y :. F',r' R...' 'E'!) ~ I~'i . J_' I U ',' . - -'- -- T¡:;~(:'.¡NS;::: '7'ø~ 63 ,II. 'K' PHILLIPS' PH WEI,_L FILES JL 'II" f;~ & D ,j'. T .a. 'W' ,II. '\I- BPX ST (~TE OF (~LASI< I~ TEXACO ~.? ~ tUl ~? ~ V; ;:;/7Þ- ~A Á.W~ - ar!.- if U/ V" ( ARCO ALASKA, INCA P .., D 4 BOX 'f OØ:3é:.t' ANCHORAGE, ALASKA Df:~ TE : i:;,:EFE¡:~ENCE : ::~;".. i ø .4....2 i "{'''..5 i i ",,4 'f 'j .... i ~5 'i i .... i 7 'f 'f ....23 ..¡ :,3""Ó i 4....3B 9 (j' ~:) 'f 0 12"..20....a9 ARCO CASED HOLE FINALS i ,} .../ :~.:: ~.:š uu ::.:: ~:~: ,/ ~:~ <? T E h ¡:.r S 1...1 F~ V' E \( (F' F\~ E ,... F ¡:~ {i C ) PITS F' f\~ CJ D 1...1 ClIO N ¡::, :;~ () F I I... I::: PRODUCTION PROFILE "ï E i"i P PF;~ODuc'r I Dì",~ PI:;~OF I 1...1:: PI"ïS I... E tll< DE 'f E:: C T I I] N I...Ef~l< DE"¡EC"¡ I ON ( F~ 1...1 i\! 'f, ~:::: II F: 1...1 t--.! i.1 ~5 II h~ 1...1 N :::,::, ~5 II RUN i ,I ~:~: II F~ U N 'f" ::~:~ II F;~ 1...1 (".1 ", 5 II ¡:;~ 1...1 N 'j" ~:) II ¡:;~I...IN i" 5 II F~UN 'f, ~:::: II c.: ('I ¡"'f C; I:] L{:',hCIJ c.: I::} ¡Vi C (] Ct¡f'.'iCU c.~ (:¡ h L: U C ('I ;""1 C C) Cf:':',i"iCCI C (:', i"'1 [: iJ C ('I ¡"'j C CJ i i .... ::? 4 ,... B (? 1 i.... 2 7 ".. B ? 1 'i ,... 2 5 .... B ':;,) i i ,... 2 5 .... n (7' 'f 'f "";;~6""ß9 i i ....22....B9 i i ....24....::39 i 'f .... 2 ~:) .... B I:;;' PI... E i~ S' E S' I G N (.~I N D F~ E T U F( N 'f H E t:¡ T T f::¡ C H ¡::: D CUP 'Y {~I S ¡:;.~ E C E :I. P l' 0 f D {~I 'r {~ ., ¡:;~ECE I VED B'( Hf~:¡VE {~ NICE ~~-R..Ë-CE.\V W DEr2s1969 .~ Cons I'n",m\S$\QØ.. p" \aska AU &. üas . ~~\UI' . . "~ Anchorage. Sf;~LI... Y HOFFECI< EI:~ ~I TO"" ì ~:>29 D I STI:\~ I BUT ION .1\. '11' ,II, 'II' CENTF\I~L F II...ES CHEV¡:~ON D ê,< f'i EXTENSION EXPLORATION EX~(DN riAI:~~~ THON MDBIL ,II, ...' ,IL 'ar JL 'II' 1:~P¡::r¡:<()VFI" ~ ''''I'' . , I ." JI "'.~ '" ..; ':~ .... I ..~ i:~1 (\ ::} '11: ~:~ I,)' .., ~.. (:) ,1\. '11' PHILLIPS PI-:: l~EI...I... F II...ES F\: ~, D BPX ST A TE OF 1{:¡l...f~,-';"I< {:¡ 'rE)<f::tCD ./1. '11' ,iI. 'II' .u. .u. ARCO Alaska( Prudhoè 6-..." ~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 t 0 R , G , N A<~ Donald F. Scheve Operations Engineering Manager September 12, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-10, Permit No. 81-87 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, ¡Jr?fdljl~ D.F.Scheve DFS/SLW/jp Attachment cc: T. B. Gray, BP J. Gruber, ATO-1478 P1 (DS 3-10)W1-3 RECEIVED S[P 1l 198'1 Alaska Oil & G 9 An:O~ Coll/Il/ission ARca Alaska, Inc. is a Subsidiary 01 AtlanticRichfieldCompany AR3B-6132-C STATE OF ALASKA , ALA( JIL AND GAS CONSERVATIO~' \IIMISSION APPLlliM TION FOR SUNDRY J.\r-PROV ALS 1. Type of Request: Abandon - Suspend - Operation shutdown - Alter casing - Repair well - Plugging - Change approved program Pull tubing 5. Type of Well Development L Exploratory - Stratigraphic - Service 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2251' FSL, 613' FEL, Sec. 11, T11N, R15E, UM At top of productive interval 1033' FSL, 1156' FWL, Sec. 3, T10N, R15E, UM At effective depth 1488' FSL, 796' FWL, Sec. 3, T10N, R15E, UM At total depth 1531' FSL, 761' FWL, Sec. 3, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Measured depth True vertical depth 81' 2731' 9067' 9775' RECE\VED SEP 141989 A\asI<a Oil & Gas Cons. CommisSion Anchorage Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tails @ 8837' MD; 9344' MD; 9530' MD Packers and SSSV (type and measured depth) Otis RH 9-5/8" pkr @ 8561 " Otis WD pkr @ 9310' MD; Otis WD pkr @ 9517' MD & Bal-O SSSV 2156' MD Effective depth: measured true vertical Casing Conductor Surface Production Liner Length 81' 2701' 9040' 1030' 9732 feet 9198 feet Size 20" 13-3/8" 9-5/8" 7" Variance 9780 feet 9246 feet Plugs(measured) Junk(measured) Cemented 170 sx AS II 500 sx Fondu & 4000 sx AS II 800 sx CI G & 300 sx AS 270 sx CI G Perforation depth: measured See attachment true vertical See attachment 13. Attachments Re-enter suspended well - Time extension Stimulate Pertõr~lte X õtt;r X 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-10 feet 9. Permit number 79-21 10. API number 50 - 029-20361 11. FieldlPool Prudhoe Bay Oil Pool 81 ' 2731' 8533' 9241' Detailed operations program - 15. Status of well classification as: BOP sketch L OilL Gas- Description summary of proposal L 14. Estimated date for commencing operation August 1989 1 6. If proposal was verbally approved Name of a rover Date a roved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Suspended - Operations Engineering Manager Title Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10- !vir A proved by order of the Commissioner Form 10-403 Rev 06/15/88 114 S. L. Ward, 263-1305 ORIGINAL SIGNED BY LONNIE C. SMITH - R/.1 APprove Returned,- ~ Date tf ~.~ / B .-89 SUBMIT IN TRIPLICATE Commissioner ff ( { APPLICATION OF SUNDRY WELL OPERATIONS PERFORATION DEPTHS WELL 3-10 (cant.) MD 1VD 9188-9208' 9216-9236' 9240-9249 ' 9256-9266' 9272-9292 ' 9354-9369' 9369-9394' 9406-9425' 9425-9450' 9460-9474 ' 9500-9512' 9533-9555' 9560-9576' 8654-8674' 8682-8702 ' 8706-8715 ' 8722-8732 ' 8738-8758' 8820-8835' 8835-8860' 8872-8891 ' 8891-8916' 8926-8940' 8966-8978 ' 8999-9021 ' 9026-9042 ' RECE\VED SEP 141989 I\\asl<a Oil & Gas Cons. col1llt\ÌßSiort . Anchorage SLW/017 ( D53-101 i CTU Cement Squeeze IPN~ Project AFE #AP1115 Procedure Summary 1 . 2. 3. 4. 5. 6. 7. 8. 9. To cement squeeze the Zone 3 thief interval and allow better reservoir conformance. Make a slickline run to PBTD. Last PBTD was 9713' WLM on 12/29/88. Pull the ported AVA BPL sleeve from the BPL nipple at 9302'. Run a Temperature survey to determine the formation temperature variations. Set a PXN plug in XN nipple at 9529'MD ( nipple has an ID = 2.635"). Install a blank sleeve in the BPL nipple at 9302'. Spot 16 ppg mud above plug and up to +/- 9450'MD. Ensure the mechanical integrity of the tubing string. RIH with CT and fluid pack the wellbore with filtered seawater. Pump 75 bbls of cement followed by 2 bbls water and 150 bbls contaminant. Hold 1500 psi surface pressure for 60 minutes. Squeeze off the following intervals: ~ 4 4 4 4 4 3 2,3 2 2 Perforations 9188-9208' MD 9216-9236' MD 9240-9249' MD 9256-9266' MD 9272-9292' MD 9354-9369' MD 9369-9394' MD 9406-9425' MD 9425-9450' MD s.e.E (Ref.: BHCS 8/31/79-) 4 4 4 4 4 4 1 /8 1 SQZ'D (Possibly leaking) Jet or reverse out the contaminated cement and wash out mud down to plug at 9529' MD. Pull plug from nipple. Wait a minimum of 2 weeks. Put well on injection and run injection profile log. III" RECEIVED Sf? 141989 A1aska Oil & Gas Cons. Commission Anchorage (' DS3-101 ( CTU Cement Squeeze IP~I Project AFE #AP1115 Procedure Summary Reperforate the following intervals: ( Drill Site Engineer will specify timing of perforating each interval) Z2M Perforations 4 9188-9208' MD 4 9216-9236' MD 4 9240-9249' MD 4 9256-9266' MD 4 9272-9292' MD 4 9334-9338' MD(APPROVED) 2,3 9354-9394' MD(DEFER) 2 9406-9425' MD 2 9425-9450' MD 10. SHCS 8/31/79) Shot Density (Ref.: FSD FSD FSD FSD LSD LSD LSD LSD LSD Current status: Expected static BHP: Expected fluid in wellbore at perforation: Injecting seawater. 3810 psi @ 8800'ss Seawater RECEIVED SEP 141989 A\aska Oil & Gas Cons. commission Anchorage ( 5 4 3 2 1 COll£D TUBING UNIT BOP EQUIPMENT ,. ~ooo PSI 7" WELlHtA[) CONNECTOR FLANGE 2. ~OOO PSI 4 1/16" PIPE RAMS 3. ~OOO PSI 4 1/6" HYDRAULIC SLIPS ~. ~OOO PSI 4 1/6" SHtAR RAMS 5. ~ PSI 4 1/6" BLIND RAMS 6. ~OOO PSI 4 1/1688 STUffiNG BOX ( RECE\VED Sf? 141989 , . ska Oil & Gas CortSm (;omm\ssio.~ A\ Anchmaga 4 3 2 , HIRELINE BOP EQUIPMENT 1. ~OOO PSI 7" W[LlHtAD CONNECTOR FLANGE 2. ~OOO PSI WIRELIN[ RAMS (VARIABLE SIZE) 3. ~OOO PSI 4 1/6" LUBRICATOR 4. !>OOO PSI 4 1/6" FLOW TUB[ PACK-Orr ( (' ARCO ALASKA, INC. F' .. o. BOX i 0(:)360 ANCHORAGE, ALASKA 99510 DATE: 8-29-89 REFERENCE: ARCO CASED HOLE FINALS * 1 - 1 1 3-10 4.-3 5-3 7-B 7-33 9-4 9-12 9-28 ** i .¡ -5 11-17 12-23 14-12 16-1B 1 ('--9 18-20 8-' i 2--89 8.-7-89 8--19--89 8-1 2,-89 8- 1 0-'8S> 7-20-D9 7-19-BS> 8-3--89 7-'j 9-89 7-23-89 8-11-B9 8-7'-8<¡ 8-1 é)--89 8-21-89 8-9-89 8-11-89 PRODUCTION PROFILE INJECTION PROFILE TUBING CUTTER PITS PRODUCTION PROFILE F'EI~~F I~~ECD~:D F'EF~F F~ECORD INJECTION PROFILE PEF~F RECORD PERF r-<ECDRD L.EAK DETECTION INJECTION PROFILE COLLAR/PERF TEMP/CAP/GRISPINNER PRODUCTION PROFILE FLUID ID/PITS/LEAK DETECTION F\lJN 1, 5 I ~~ U N i, 5 I RUN 1, 5 I ~:UN 1,. 51 RUN 1, 5: I I:;:UN 1, 5 I F~UN 1, 5 a F~UN 4, 51 F~UN 1, ~>I I~UN 1, 5 II RUN 1, 5 I I~UN 1, 5 I RUN 1, 5 . RUNS 1&2, 51 RUN 1, 5 II r~UN 1, 5 I PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA A DISTRIBUTION ... ... .ø. or .II. 'II" CENTRAL FILES CHEVRON D ~ M EXTENSION EXPLORATION EXXON MARATHON MOBIL ... ... .L 'r ... ... ... ... PHILLIPS PB WELL FILES I~ & D . BPX STATE OF ALASI<A TEXACO .u. 'II" .u. 'r * THE CORRECT API~ FOR 9-4 IS 50-029-20212A ** THE CORRECT APII FOR 11-5 IS 50-029-20670.. C~~MCO CAi".;CD ~~ TLAS C(~~ì1C(J Cf~t1CO '.iLS HLS CAMCO HLS HLS CAMCO CAMCO ATLAS HRS CAMCO C(~MCO t\ F;: C (j (i I... (i S k f::'.. I N C ,. ¡:;' r. o. CD>: .\ O()3ÓO ANCHORAGE, ALASKA Ü,(~ TE : ~:> M" 2 Ó - B 9 ( ';) ? ~:> i () i -.. :::!} REFERENCE: ARCO CASED HOLE FINALS :~ ....1 1 :? -. 2 4 ]''''9 3-"9 ~:S-'1 0 :-5"" 1 :? 4-2 4""~>" 4....1 4"" i ~~: 4-'~~Ø 4....26 ,... I'" -)"";} ~> .-. 1 (' 7",,30 1....30 9....28 i i ....1 0 11 "'<~6 1 B...., 18....9 i B....:?3 ~:> -"é'- B9 5",,4....09 ~:>-"20-"B9 ~:) -.. 1 ~:~ .... B 9 ~)''''1 B....H9 5 .... ..5 ..., B ''i ~:> .... 3 .... B <'I ~:>""20''''B9 ~:> ..., '1 9 .... ß 9 5,-1 ''i....ß'' ~:> .... ~:> .... B <1' 4 ..- i u- Ü <¡ ~:>.... i B....Bç¡' ~5 .... ;;.~ ''I'''' 8 \'1 ~~-"::?9""B9 ~5""1 {,-"O('i ~>",,'j 7....B9 3..-~'50-'B9 ~>''''1 O....B') ~5 .... ~:> - B 9 ~>''''B''''B9 ~5''''Ü''''B('r 3-'21.)""B9 (' PROD. PROfILE/LlAK DET~C1ION 'fEMP/FLUID DENSITY C C) 1...1... (.~ F~ / P E F;~ F CN!... ''''GAri(\if~ D I FF TE~iP INJECTION PRUFILE INJECTION PROF'ILE/TfMP CN!... '-Gf~l"il\1A CNL ""GÞlt'jrj(.~ CN!... ""b'~l"ir1('~ INJECTION PROFILE C()I...!...AI:~/PEI~F CNl.. ....(; (-ir) MA CO'-L.f:iR/PEF~F C () I... L I~~ F,: / P E I:~ F DUAL BURST TDT""P CNL.. C()LLAr~ TO SET PATCH I...Ef~l< DETECTION INJECTION PROFILE/TEMP FLU I D DENS I TY /TEtv1P FLUID DENSITY/TEMP C C) Ll.. (.~ I:~ /P E I:~ F I;;~ 1...1 N i, ~> II I~~ U N 1, 1 H.~~:5" I:;: 1...1 N i, 5" I;;:UN i, ~>II :~ U N '1 ~> II I~: U N ì 5 1\ F~ U N i ~> II I:;~UN ì, ~> II I:~ U N 'j ~:> II I~ U N 1., 5 II :..~UN i, ~> I I~UN 1, ~:>I I:~ U N 1 I ~> II I;;~UN i, ~:>.. I:~UN ; ~~: R HUN 1, ~:>I F~UN i, ~>I I~UN 1 ~:>I I:;~ U N i, :~~ " ;;:UN 1 51 I:~UN 'j ~> ÌI I~UN i ~>" F~ U N '1, S\ II PLEASE SIGN AND F~ETUHN THE ATTf'CHED COpy AS HECEIPT OF I)AT('~.. I:~ECEIVED BY HAVE A NICE DAY! ._...--..---_._-_..~_'_M_"_'~.~._---_.. S A L..I... Y H () F FEe 1< E F~ ATO""; ~>2<-¡ .L ... .11. ,r .... '1' .n. '11' JI. ... Alaska Oil & Gas Cons. Commission Anchorage DISTF~IBUT ION .110 V PHILLIPS PB WEL.L. F 11..F.:.S I~~ ~ D BPX STAll:~ OF ALf:~SI<f~ lEXACD CENTI~AL FILES CHEVI~ON D & ~1 EXTENS:I. ON EXPL()F~A l I UN EXXDN t1(.~F~f~ THON MOBIL .11. ..' ..10 '11' JI. '... '2'2- C I~~ j'.'i C [I C f:~ Ì'Ì C IJ f~TL.f~'S {,TL.(~S f:~TL.t,S C f:'~ d I.~ U Cf~ncu f:~ r L f~ S ¡::, fl...t,S f:il Lr:"iS Cf'~t'}LU Hl..S f;~ Tl..AS HL.S Hl..S SCH SCH HLS Cf~~iCO CAt1CO Cf~~')CU Ci:~hC() HLS r.'=\¡:~C(j f~LI~~SK I;.. I NC.. F' ~ D ~ BO:< i 003\-S() ANCHORAGE, ALASKA Di~ TE : F~EFERENCE : * '1 -'j 3 1-16 .-) - .-:' ~ .:.. 3-1Ø *~.: 4-12 4-i5 4..-"j ::; .- , .)-0 5-9 ".'-30 1 i -'. i i5-14 16--21 PWDW2-1 P~~Dl'J2-' i PWDW3-i 1-31-89 ( ( ~;I '7. ~5 í a:) ARCO CASED HOLE ~INALS PRODUCTION PROFILE COLLA¡:;~/PERF PRODUCTION PROFILE COLLi~R/F'E¡:;~F PRODUCTION PROF'ILE DIFFERENTIAL TEMP T E-: M P COLLA¡:;~/'PEHF C()LL~:i¡:;.~/PEF:F LEl~l< DETI::CTION DIFFERENTIAL TEMP PRODUCTION PROFILE PRODUCTION PROFILE FLOWMETER LEAK DETECTION TEMP . COLLAR/PERF--SET PLUG F\:UN 1.. Sit RUN 1, 5. . F;':UN 1} ~~. II F~ U N ~; 1 - -3.. 5: II I:;~I...IN i., ~5 II I:;~UN 'j, :5;¡ F;~UN 1.1 5 II F~ U N 'í, 5 II F<UN i., 5 It RUN 'j 2¡¡~,:~511 F~UN i., :2 iI F'~Uì"'~ i :; II F\:UN 2.. ~:~ II F;~UN 'J 2 n &5 II RUN "1 5 II I::':UN 1, 5" 1-6-89 ;-4-89 1-1'1-89 12-23-88 1 - i 5.-.89 1-15-89 1 -1 ~,)-B<;' 1 - ,¡ S:'-89 1-21-89 1 --6--89 'i~13-89 i --9-89 i -." 0 - 8 (.:.:. 1 -. i 3-8\» i-í<?-B9 12-24-88 PLEASE SIGN AND RETURN THE ATTACHED COpy AS RECEIPT OF DA1'A.. I:;~ECEI\"'ED BY"_.__---------_.."_._--_._~- r= C E IlLE.. D H(.~\;'E ~~I NICE DI~Y ~ d.. ~;6Y /"L. SALL Y HOFFECKER 'E' -~6 198~ --- ~} 'r ij - 1 ~) 2 9 Alaska Oil & Gas Cons. Commission Anchorage 'Tï=~~~~~ ~~'?ø~ ~11..IF.II"~UVE.D -~-- DISTF~IBUTI(JN === CENTI:;~C:Ü- FILES :::= CHEVRON D & M ~ "EXTENSION EXPLORATION ~ EXXON MARATHON ::= MOBIL ,IL ". PHILLIPS PB l~ELL FILES ¡:;~ .& D S ~1 F' C STATE OF i-~LASl<i~ "EX~1CO ..; ... JL "II" ... ... 'iI: HLS (HALLIBURTON LOGGING SERVICES) IS THE NEW NAME FOR GEARHARTA ** THE API 0 ON THIS LOG IS INCORRECT; IT SHOULD BE 50-029-20254.. C{;i"~CO HLS' CAt1CtJ G Ei;~-;~ CI~r'''iCÜ ClqriCI.] CI~~hCO i:~ 'r L i:~ S' f:' T L 1-:" S Cr::1r-1C D CAt-iCC) C f~ i'i c:: I,] c: f~1 Ì'i C D Ct'=1(1CD Cf1MCO G Ei~ h~ ARCO Alaska, Inc. (' Prudhoe Bay t:.ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 ( ~~ """ fl ~ Donald F. Scheve Operations Engineering Manager February 1, 1989 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 3-10 Approval/Permit Number: 8-956/79-21 Enclosed is the Report of Sundry Well Operations detailing work perfonned on the above-referenced well. Very truly yours, J~j~ D. F. Scheve DFS/SAD:bw Enclosures ~ '!î, ;r~; C cc: Standard Alaska Production Company JoAnn Gruber, ATO 1478 File Pl(DS3-10)Wl-3 OHJ~t Gas Cûlls. - ~nc;h().ra9.e~:) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6132-C (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown - Stimulate - Plugging - Perforate _x- Pull tubing - Alter Casing - Repair well - Other- 2. Name of Operator ARCO Alaska, INC. 3. Address P.O. Box 100360, Anchorage, AK 5. Type of Well: Development 2- Exploratory - Stratigraphic - Service - 6. Datum elevation (OF or KB) 64' RKB feet 7. Unit or Property name Prudhoe Bay Unit 8. Wpll nllmhor OS 3-10 99510 4. Location of well at surface 2251 'FSL, 613'FEL, Sec. 11, T11 N, R15E, UM At top of productive interval 1033'FSL, 1156'FWL, Sec. 3, T10N, R15E, UM At effective depth 1488'FSL, 796'FWL, Sec. 3, T10N, R15E, UM A t total deem 1531'FSL, 761 'FWL, Sec. 3, T10N, R15E, UM 12. Present well condition summary: Total depth: measured true vertical 9. Permit/ADDroval Numbers 79-21/8-956 10. API number 50-029-20361 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical 9780 feet Plugs (measured) 9246 feet 9732 feet Junk (measured) 91 98 feet Casing Conductor Surface Liner Perforation depth: measured (See attachment) true vertical (See attachment) Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tail @ 9531' WLM Packers and SSSV (type and measured depth) RH 9-5/8" pkr @ 8561', WD Hydril pkr @ 9453', WD pkr @ 9518'WLM & BAL-O SSSV @ 21p(3'F~" 1 030' Size Cemented Measured depth 20" 1 70 sx AS 11 81 ' 13.-3/8" 500 sx Fondu & 2731' 4000 sx AS 11 9-5/8" 800 sx Class G & 9067' 300 sx AS 7" 270 sx Class G 8745-9775' True vertical depth 81 ' 2731 ' Length 80' 2701 ' Production 9040' 8533' 8211-9241' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure N/A , "".,. ,- r.'., ,.",,~. 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 15,000 15,000 16. Status of well classification as: 550 550 15. Attachments Copies of Logs and surveys run - Oil - Gas - Suspended - Service _x Signed Form 10-404 Rev 06/15/88 Title Oper. Engr. Manager Date /3, ~ SUBMIT IN DUPLICATE ~ ( (' REPORT OF SUNDRY WELL OPERATIONS PERFORATION DEPTHS Well 3-10 (cont'd) MD TVD 9188' - 9208' 8654' - 8674' 9216' - 9236' 8682' - 8702' 9240' - 9249' 8706' - 8715' 9256' - 9266' 8722' - 8732' 9272' - 9292' 8738' - 8758' 9354' - 9369' 8820' - 8835' 9369' - 9394' 8835' - 8860' 9406' - 9425' 8872' - 8891' 9425' - 9450' 8891' - 8916' 9460' - 9474' 8926' - 8940' 9500' - 9512' 8966' - 8978' 9533' - 9555' 8999' - 9021' 9560' - 9576' 9026' - 9042' . f"") ~. j~, on&. Ga~~ Cons. ; ¡Anchorage .. ( ( DS 3-10 PERFORATING SUMMARY OF OPERATIONS 12/23/8.ß.: Began perforating operation. 0 R U perforating unit, pressure tested equipment. 0 RIH to 100' with gun #1. SITP 20 psi. Made up hard line to well 3-1 AL gas line. Opened 3-10 to AL gas to force fluid level down hole. SI 3-10; SITP 1300 psi. RIH with gun, opened well to tank, perforated interval ~ 1 SPF 00 ha in , flowed well for 5 minutes. SI well, POOH, all shots fired. 0 RIH with gun #2, opened well, perforated interval 4' MD 1 1200 pþasing), flowed well for 5 minutes. SI well, POOH, all shots fired. 0 RIH with gun #3, opened well, perforated interval 2,M0-9249' MD (4 SP~ 1200 pþasing), flowed well for 5 minutes. SI well, POOH, all shots fired. 0 RD, returned well to production. Perforation depths referenced to BHCS log, 8/31/79. ARCO ALASKA! INC. I:' U" q l" x: ,,() I'.;).: 3 t.. (~f . .. ¡;; -" I.. '-J. ANCHORAGE, ALASKA DATE: REFEF.:ENCE: 1-3 1-6 1-14 1 -21 1 -')'~) ... .... 3-1 3-10 3-25 5-~5 5-12 9--4 <9--31 11-i~> 1i-15 12-9 1 2--20 13-'~) 13-30 1-23-89 C)¡:;.c:;:(/ ,loJl (' ARea CASED HOLE FINALS F;~UN 1,511 RUN 1, 51 F~UN ;, 5 I f~UN ;, 5 I f\~UN; 5 " HUN 1, 5 I F~UN 1, 5 II ¡:~UN 1, 511 I:;~ U N 1, ~) II i;~UN 1, ~5 II RUN i" ~> H HUN i, 58 FdJN i, 2 II &5 D F~UN 1, 5. F:UN :~, 5 II RUN ;, 5U F\:UN i, 5 II RUN i, 58 PLEASE SIGN AND RETURN THE ATTACHED COpy AS RECEIPT OF DATA.. 1-4-89 1-5-89 1-9-89 1-7-89 1-8-89 , ")-/")9-88 I......:.. ~ , ':>-?Q-8Q 1..- ..... 1 ~ 12-31-88 , -" - C\ ç. 1 .1 C) 1 1-2-89 12-30-88 12-30-88 'j 2--2B-BB 1-1-8(,;> 1 - {,-.89 1-8-89 1-6-89 1 .- i i -89 PRODUCTION PROFILE PRODUCTION PROFILE PITS PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PITS PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEi~ { DETECT I ON LEAK DETECTION PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE PRODUCTION RECEIVED BY_____----------------- I-II~~VE A NICE DAY! S,~LL Y HOFFECI< EF-~ A TO- i S:29 TF~(~NS ~8904J1 APPF\()VED .-.te--- eo CE \VlJ JAN26 1989 0\\ & Gas cons. CommIsSion ~\a- Anchorage DISTRIBUTION Cf~MCO Ci~ì1C(J CAhCO CI~MCO C~~r1CO Ci~1Ì1CD CAML:O CAì1CD C~~t'\CU -, , . , - ,- i._: ¡:1 f'1 L U C~~t1CO C(~ ¡"iC (j C¡:'1r1CCJ C I~~ ì'i C i.J C t~ r-i c Ci Ci~ì'iC(J Cf~ 1'1CO SCH .a. CENTRAL FILES ... PHILLIPS T or .JL CHE\l¡:;~ON PB WELL FILES '11" D & H F\ & D .u. EXTENSION EXF'L(jF;~A T I ON .s. SAF'C 1r or ... EXXON oK. STr~TE OF ~~LASI< f~ or ... MARATHON .... TEXACO T ... MOBIL ". t. ,f' ARCO Alaska, Inc. ( Prudhoe Bay engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 f ~ ~~ 1c4; ~~~ , r , Donald F. Scheve Operations Engineering Manager December 15, 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Comission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 3-10 Permit Number: 79-21 Enclosed is the Application for Sundry Notice detailing work to be performed on the above-referenced well. Very truly yours, JntJ1l,f~ D. F. Scheve DFS/SAD:sd Enclosures cc: Standard Alaska Production Company JoAnn Gruber, A TO 1478 File P1(DS3-10)Wl-3 REûf:\\lBD DEC 161988 Oil II Gas Con$. c~~m\SS\Qd A'as~ \...t 81ctiQtage. I' ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany AR3B-6132-C , ~ ( STATE OF ALASKA ( ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation shutdown - Re-enter suspended well - Alter casing - Repair well - Plugging - Time extension - Stimulate- Change approved program - Pull tubing - Variance - Perforate _x- Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ~ Development _X- ~ feet 3. Address Exploratory - 7. Unit or Property name Stratigraphic - Service - Prudhoe Bay Unit 8. Well number DS 3-10 9. Permitl Number 79-21 10. API number 50-029-20361 11 . Field/Pool Prudhoe Bay Oil Pool. P.O. BOX 100360 Anch, AK 99510 4. Location of well at surface 2251'FSL, 613'FEL, Sec. 11, T11N, R15E, UM At top ot productive Interval 1033'FSL, 1156'FWL, Sec. 3, T10N, R15E, UM AI enecIlve oepm 1488'FSL, 796'FWL, Sec. 3, T10N, R15E, UM AI 100ai oepm 1 ' , WL Se ON 12. Present well condition summary: Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2701' Production 9040' Liner 1030' 9780 9246 9732 9198 RECEiVED DEC 1 6 1988 M Alaska Oil & Gas cons-. ..~~ feet Plugs tfh~cIn~h~~g~óne feet feet Junk (measured) 9639' feet Size Cemented Measured depth True vertical depth 20' 170 sx AS" . 81' 81' 13-3/8" 500 sx Fondu & 2731' 2731' 4000 sx AS II 9-5/8" 800 sx Class G & 9067' 8533' 300 sx AS II 7" 270 sx Class G 8745-9775' 8211-9241' Perforation depth: measured (see attachment) true vertical (see attachment) Tubing (size, grade, and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tail @ 9531 'WLM' Packers and SSSV (type and measured depth) RH 9-5/8" pkr @ 8561', WD Hydril pkr @ 9453', WD pkr @ 9518'WLM, & BAL-O SSSV @ 2156' 13. Attachments: Description summary of proposal _x- Detailed operations program - BOP sketch _x- 14. Estimated date for commencing operation 1 16. If proposal was verbally approved ..-,. Oil...::~-'~,' Gas - Suspended- -;,.,,-- Name of approver Date approved Service ¡X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. JlJ~ Title Operations Engr. Manager FOR COMMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Ij,c Lf- --6 (¡;-~OmmjSSiOner Signed I Approved by order of the Commissioner Form 10-403 Rev 06/15188 15. Status of well classification as: Approval No. çg -- ~h Date J 2 -/ C¡-8..., SUBMIT IN TRIPLICATE (~.,l)r.~r,:"~~-~e"Ylt "'!i7(",""'),/" 1o"""',ort')l"1 01",.,1 ~,'L"- ~ "'-:j, ~- -l ~ V .,.L L' J\lev.!....! - v ,.1 "'-'. 'N liD, l fðL' I' -, -L/:l ¡ ,tfJ .\ ( "-", . ,,' '. -, ( ; . , ". .,. .1 I .J!. do...11 IJ. - ¡ I,;.,.....:.-t,¡¡ ---j - ' if (' (r- REPORT OF SUNDRY WELL OPERATIONS PERFORA TION DEPTIIS Well 3-10 (cont'd) . MD TVD 8654' - 8674' 9188' - 9208' 9216' - 9236' 8682' - 8702' 8722' - 8732' 9256' - 9266' 9272' - 9292' 8738' - 8758' 8820' - 8835' 9354' - 9369' 9425' - 9450' 8891' - 8916' 8926' - 8940' 9460' - 9474' 9500' - 9512' 8966' - 8978' 8999' - 9021' 9533' - 9555' 9560' - 9576' 9026' - 9042' \tt:t1t \ \J t D . eel b \9ßß Dt:. . .on coroffi\SS\u ! ..... 0\\ &. Gas cons. A\as\Ø : ~\ I~c\\otage ~~. ( DS 3-10 PROPOSED ADDITIONAL PERFORATIONS API #50-029-20361 PERMIT #79-21 ARCO Alaska, Inc. proposes to add new perforations in OS 3-10 within the Sadlerochit Sand from the Prudhoe Bay Unit. The proposed perforation intervals are as follows: ~ fQQ1age..J1. .sEE ZQœ ~ 9240-9249 9 4 4 Addperf 9369-9394 25 1/8 3 Addperf 9406-9425 1 9 1 2 Addperf Reference Log: BHCS (8/31/79) Well 3-10 is an MI/SWI WAG injector that is currently injecting seawater. The well- bore fluid present when the perforations will be shot will be seawater. The expected bottom hole pressure is 3800 psi. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure (diagram attached). '.! . ) 4 ,2 3 , (' . I( ,. ~ooo PSI 7" WELLH~ CONNECTOR F'LANGE 2. 5000 PSI WIREllNE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/S" LUBRICATOR 4. 5000 PSI 4 1/S" F'LOW TUBE PACK -OF'F' HIRELINE BOP EQUIPMENT ( ("... ARCO ALaska, Inc~ \::' f' H C) '.1 ,( 0 0 '3 ", 0 " ..1.. '" to,' ... ç;, Anchorage, ALaska DATE: r:":"F"'00"" f"Nf'Eoo , ra.. t::. ' ::, '..: ',:, _I .:, ' 3--10 99510 1 (j."B-"B7 ARC a Cased Hole Final 9 ,_./:> 4.-.8 7 ,,\.. .. FI.opf?tr'ol. Pï'fJeluc:tion l...o9ging F:un 1, ~5n I=",..I--,:'\(',h () f cL=d a I. ..r'I:-'A, 1\.1 s: :Ð:q""'c:;':>4 ~ a.. '~... J/(.(oo,.\.. , t:lppr'Q\fl:'!!d............................................. . """""""oooo......,.........,"""""'" I)'I"\~'T'I:"'I'V:~lIT' "'11>.1 ,. "I.. ...., .[. , , " l.. ,.~ .u. "" .IL 'J/' C E~ n t ,.. (:I I. F i I. I::~ ,f-: Ch f~\\lr on D .:"( M Extension ExpLoration F: ::( x 0 n M a )" a t h (',I n t1nb i I. .0. "r ,II. ...' .ø. '". .II. '\I' Ph i I. lip s P B 1¡J f.~ I, L F i I. e S' ,:~ ,~ D SAPC S t '::\ t I::! 0 f PI l ~, s I< <-.\ Tf~xac:o .H, .". .11. OU' ,IL .". ARCO ALaska, Inc. P.D... Box 100360 Anchorage, ALaska DATE: REFERENCE: 1-1 a 1-28 1 --29 2-8 3-7 3-10 9-7 11-1 14-32 18-9 June 1, ( r 99510 1987 ARca Cased Hole Final HAVE A NICE DAY~ 4-25-87 12-28-86 5-14-87 5-2-87 5-9-87 12-27-86 4-27-87 12-25-86 5-13-87 12-29-86 ... 'r .... "II" FLowroter/Fluid I...D.../GR Pe\- f. Rec 0\- d Collar ~ Perf... Log CoLLar Log (PLug) Collar ~ Perf... Log EPL Collar ~ Perf. Log Pe\- f. Rec or d Collar ~ Perf. Log Tub i ng Punche\- Run 1, 51 Run 1,51 Run 1, 58 Run 1, 5 I Run 1, 51 Run 2,58 f<un 1, 51 Run 1, 51 Run 1, 51 Run 1,58 Ca rl\C 0 Sch Gea \- Gea \- Gea \- Sch Gea\- Sch Gear Sch Please sign and return the of data... Received By_____---------------- A"""!t'" "'j IJ ¡.;;......,\c lJj Cl G"" C U\J "'In... C..... . A """,.' IJmm!3~i"l'" . nc':'r... ""'-d I it., ,1 (H3 ' ",:) OJ R()s a nne Pee k ATD-1529 Ä::~~v:~~:::_-~----------------- D I STf~:r BUT I ON Cen-t\- a L FiLes Ch ev\- on D & M Extension Exploration Exxon Mar'a thon t1ob i L ... '.,. JL ,.. -M. 'r =:: Ph iLL ips PH We L L F i L es R ~ D ,,:;~~:1~1~ ::: Tf?XaCO A F~ C D f,) l êJ S k ë'¡ I I n c .. P..D.. Box 100360 Anchoragel Alaska D (:1 T E : F"I::'F'E-:'I:"I::'t,I(" :-: : " ... oo" .- ~ " ..' --- ':ì...."') .." í ---- 'i -- 1 I:} ~ ::';-"1 E-') ." ) ---- -1 -- 4 ...} ~'")!....L. ...1 CI ~ -;:; .-. í 0 ""- :~ .....( ':) ...1 I.." '-.... b -. (j> ~ Cì....-Z1 , ,.1 ~ 0;...-: ':ì , '-' 10.. ~í3-'17 í ~5--2Ø ---- 1 3-,22 N D V E' 11'1 b E' )"' 1 Ci .-, 'i -7 ".' n j, \O}." (;1 '.1 E' ", ..') ,.. I ~ -, ¿ ( ..- d \.:' () -oo 1 "i.' -. Cì I, e.. ,..' (;1\0" Ci -.. ") ,') -, C) /., \..' ..'" ,,'.. <.1 <:1 B'-' 2 ~; "oo Ü f.:, c;¡ .-. ") '1 "" (;'1 l- e.. ..'" ... \M' .,,' C) -' ':> -1; -, ~~ l- e.. ..- .... -, '-' B -.. í .-. 8 to (:i -' 1J - C) 1, J ¡ (/CI 8_.1., --<:)6 \..' \.} C¡ -- ") 1 _.. C) t, ç........ '-1"'" C{ -- ':),¡ -, q 1. ç- ".. I ç- CJ ('.) -. ") 0 .-. C) j, \01':" \01 "'" ( \ (" ( q <:; I:~ 1 (,) I , -, , -'I I I .( OC) I. I '\01 \01 ARC a Cased Hole Final S pin n f.:! ,.. S 11 r V E-~ Y Sp i nnf~'" Sur v~:~y T E'lfl P.. S U ,- V Eo Y Spinner Survey/Temp.. Survey Sp : nnf:~ï' Sur VE~y Spinner Survey (Multi-rate) Spinner Survey/Temp.. Survey T f.:' II' p.. S U ,.. \I f:~ y (F' U II'I pin) Sp i nn€.!,- PBU/Spinner Survey Sp i nnf:~)" SU'¡"VE'Y Sp i nn~?)- S u '" v~~y Sp i nn(;~)- S u)- V€~IY r~u.n 1 I ¡:~lln 1 I F<lln 1 I Run í r~~u.n 1 I F~lln 1 F~: u n 1 I F: II n 1 r~ u. n 1 Ii,' F~l1n 1 Hun 1 I~un 1 "'c' r;:u n 1 r¡ø ... F l c; P Ed r' () l F l [) p €:' t r' () l F I. () P E:~ 1: r' () I. F L () P (.~\ t '" C) I. F I.C)P~:~1:'ì() l F Lop(~tr'o I. F I. () P €.~ t '" C) I. Flop f:.' t).. D l F l () P Ed )- CJ I. F l C) P €~ 'h- () l F l CJ pet )- () l F l C) P ~? t ,- t') I. F I. C) P (~I t '" C) I. ") " ..'- 'i. ... '1' ..'- r) " .:.. ") II .:.. '1 ø .- '1/1 ..'. '-I . ..., ") " .- ") II .:.. ") U .. ") II .:.. 'n Please sIgn and return the attached copy as receipt of data.. I;: r::. C ç:., i v ç:. cI r~ v ... - n. ." . , -.-.---..--.-..-.-----.-----.-.--..-..-.---- HAVE A NICE Df.ìY! RcLS' a nnt-'! Pe€~ k PI TD-1 529 1. 1:;1 f" ).,1 <"' .II. rc~ /.. -1'"1 i. ,';I~~ 11')""'\-...10...' I ." ¡': r: () l'ï§i ',' - f'\ :I'II.'.~:~':I . -- ,,",..'.:..1 ,,1 J'.: ~ .: 1 ~ ¿. : ¡:'.lasl~a Oil & Gé:~, -';~i:~, l.ür¡liT¡;::,~.c.';~ f.r1 t';"'" "') r) CJ h ~,.."j "":~ DISTRIBUTION .fl. C e 1"1 t ,- a l Fi L f~S '/1' .f\. Ch evr cln 'II' D t rí \.'1 ./I, Ex tE'ns i c-..ln Ex p l 0)- a t ion ",' .IL Exxon 'II' M a ì- a tho n .IL Mobi L 'Ir ::: Phil,l.ips PB WeLL Files R ê~ D ===,.. . Soh i 0 t;;St~teof Al.aska . ~ TË'xaco ( ( AF~CD A Laska 1 Ine" PI, ()" Box i 00360 A. '" C" I" C" \.. '.\ C ':" A. ',\ <~, , ',\ II..I,JI(;I.{.., ,(;/...\U (?S)~>1 0 DATE: 1 (JOb S E': p t <-:: en b E' )" ") i. ,:.. \..' 1 ARCO Cased Hol.e Final. r'I "'I"'E"I"'E"N(" '" , r\ ::, .. ::, "\::. " ::, ' ~ 3....10 --- 4 ..., 1 ~4""9 ---4 ,... C) , -' -......4",,10 ---4""1(-) --.......... <:i ,....( ':) 1 I "., ~:¡""1 ') , ,.., ---...... (:) .....( 'i , ¡ ..:.. -----.. ':¡ .." I., ""1 ----""', , '--r" 1""1 ..1.... 1 I --.......... <;> ..', ':) (.) ~' 10.., r'¡ ") C" -............ ~.. '... , ------ 1 r:.. ...' ..1 1 .... ,.¡ '............... ,:.. 11 ",,1 0 .,~í""1'í ~i ("",2 S t f:! p I:~ è) t E.: In j ¿ P r' C) f i I. E'! / G :~ P r' 0 due t ion p)" 0 of i I. (':: T E.":{I¡P 10 1...09/ I n j" Pr' 0 f i I. E' In j" Pr' () f i I. E.: Tf::mp 10 1.09 Inj 10 Pr'of i I,E' S pin 'Ii f:! r' / I n j" p)" 0 f i I. ~:: T (~~( '¡p 10 I. OÇ) T<-::mplo 1...0<3 Inj" Pr'of i LE! 'r f:: (¡) p" L 0 <,:} Inj" Pr'of i L(,:: In j F' i" C) of i L E' Spinner/TeMP" Survey S'p i nn<-::'¡" I...o<:} SF> inner' /F' ¡" Del u e t i on p)oo () of i I. ~:~ Temp" Log leak Detection E:u.n 1} F~un i 1 F~ un i 1 F;~lJ.n i 1 . I:;~ u nil I:;: un 1 1 F~un ~~} I", "x "\ U il ",' 1 I:;~ un 1 1 I:<un 1} :~~ U'li 1 1 F~un 1} I:~ IJ. 'Ii 1} I:;: un í} r~ u. nil F~u.n 2} I:~~ u n 'í} Ci ,..' 1 q .." E>J" .' c, } \.. q....')'¡ .,..qi" .. 10..' \.. ..., 9 ..', 1 {,) "" Ci i" , "\....1.... (" 1 I'" ~'\' r ..., "> ..., 'j "'¡ , ..' - \.. 9 .... 1 (.).... (:' i, , ...h.} I::' " ..l C' " (' r" coo ,d II ,.. ..I Cameo ( . " I' r' C') ..' dIll... - C' , (".. , d m ... <..1 ("'1\("(" " (:1 lit... ..1 Ca {nc: 0 (oo, .. ( \ (.. C.. ..-(:1 II .. J (' ., ( \ ..' ('¡ , (:1 It l.. .. Cameo Ca{¡"co ( , .. ( \ r" (.. ..' <:I I,.., ..1 Ca (lie: 0 C a hi c: 0 (" " e ' C.. ('¡ ..' <:1 It .. " Camco ("'f'("(" ..-<:1 It... ..I Ca (lie: 0 I:~' II ...' 1::- n _l I::: II ...' I::' n ..)- ~> II I::: II _/ q""1I:,',..,(:\i'l " ..1 (,~ \.. <.i....i1/12""BÓ I:,' II ..1 I::' II _l q ....1 1 /1') .,.. q i" , .' 10.. \.. \.. (.. i 1:" ~" ;.'.... > ...- 1 "", , - 1 \.. 0.... 1 1 .... q i. .' \.. \..' o""-<1'-'C)I.\ " I ....' ..., I::' II ,..; I::' II _i I::,: II .., <,;)....12...,B¿ r7' '... 2 () .... B Ó I::' II -,; <:) ".. 1 4"" () i, ... . \..' \..' r.:' II ..i I::; II <:¡ .." ") (,)' I I') 1 .." (;) 1.'. .! r:,. 1 ...... I.} \..' <:}"'-"I"~/'J.I,4""P,,::, , ,,} - \.. \.. I:~' 1/ ..,' O""1I:::,...(:)i, 1 ..-' '.,} \..' C" II ..> i.. 1:,\ coo 1:,\ ., Q .t' C1 .f: cl -; .l' ~\ {....{.. I' " <.I ,;1.. P I, E'i:) S c~~ ~~ I <,:} n Received By_____--- ;? .C~ ~'aska Oil & Gas Corb, uUH\mlssion Anchorage .T""\¡".'<:' .II,Co'C"O"" '\~ ?'II'< ,,:- '1' "::' ö..> l .. DIST':;~IBUTIDN Ph i I. I, ips PB WE': I. I. F i l es f~ t" D Soh i C) C f.;' n t in a L F', I, (~,! S Ch ~~vr on D &~'j Extension Ex pI. orati on E:.xxCin M <:1 ¡.. <":i tho n Mob ¡I, .11, 'II' .11. "I" .II, 'u' ,II, '11' ,II- '11' ,II, '11' ,II, '11' .11, ,,' S'té)tE:' of Al,èiska T~:-:xac:o .II. 'II' Ar~co A La~;'ka, Inc.. P..O.. Bt:>x 100360 Anchorage, ALaska DATE: ,- E. r' E"" E.. N C"" E- .~ :," :, .,~:. , .:. : -"""""1 ".. 2 B ~1--31 ---3-,,1 0 -... :~ -, 1 0 --.. 3-,,10 '--- 4_.':> C" -...... "'.. -> ---1 B'-'9 s ~~ p t .~~ II} b ~~ r' ~>""26-"B6 7-'~~7-"86 ..,.... 2~> -"B t.. 7,-' 2~> ._, HI.> _7 ,_. ':) -1 ..- "-c) 1::: "'.. ..J ) oJ 7-<31 --B6 B....i6""E}6 (' <j)9~>10 2~> , 1 906 ARCO Cased HoLe Final ( ACBL/VDL/SIGN/GR ACBL/VDL/SIGN/GR GF~ prc ACBL/VDL/SIGN/GR CNL/GR (MuLti=Space) C' F" :r ", /AAr-lk F~un 1, ~51 r'l1n 1, ~)H F~un 1, ~>n r~l1n 1, ~) n ':~un 1, ~>. r'lln 1, ~>n F~l1n 1, ~>. Ih' €-~ .fi S D"'o'-<" , ,';;,:)-> I) \.. r..\ c" c' \,:;, -) ..) I) ,- '-~ c" c" , r....)-> D \" €~ S' s I) '" '=0 C" <" , r.. ,:10 ..) Ih" €-LS' S olJ J /a.r-I PLease sIgn and return the attached copy as receipt of data.. Älaska Oil & G~s (;on,;. i.I\Jillmissl0 . Anchoraue n 'Y":" ^ N S. ,I, () 6 S" C) "1 , \, t" I, ..' Ç) Î ...' Centra I. F i 1.<=-"'5 Ch ev}" (>n D ~, M Ext~:'nsion .Exp Lcn'c"ilt iCH\ Exxon t'1 i:\ r' c':t t h C) n MobiL JI, "" JI. 1.' .\1, 'n' ,H, 'a' .H, 'n' D I STF~ I BUT I ON .ft, T Ph i I. Lip.5' PH We L L F i L e.s' F~ ~, D Sc> ') i () S tat f.~ Q f A L i:L~;' 1< a Texac.c) ,II, ..' .ft, ..' .11. T . -,' ( t-";¡HCO A Laska Inc.. P h D.. Bo x 1 00360 Anchorage, ALaska 99510 D{~ TE : S~~p t emb ~~r' 1 <:) D I.: I \,1 ',-' .( "') I ..:.. I I:"I::-FE::-F"E-N('~E' : \ ,.. .. \ '" -... ARCO Cased HoLe Final ---- ---:3 -,,'j 0 :'5",,'j ø 7"" 'I B,...fJ6 -"} ..- ':) 1 -.. (, t.. I ..,.. (;;0 \.1 "cr'l '\'I)L ""J'N 'C' I-' {u '3,../yl.,/.::'./:r", DiftA Temperature Log F~un 1 I ~3H I~un '1, ~}II f Please sign and return the attach~d copy as receipt of data.. Received By_____----------------- IIA\II'" \. NI("E" 1)1\."1 .. .. 'oJ:. f., I " ':' (.., r , Ii C) s' ann (~~ P (~~ (~,~ 1< " 1. 0 1 C" ") C) (.., -, ->..:.. 7 TF~{~}NS ::::Bl,:,~:>7 4 DISTI:~IBUTI()N ,II. '11' ,II. 'II" C(':~ntï'a I. F i I.r.~s Ch €'~Vï' on D & M Extension Expl.oraticn Exxon Ma}"ath(:>n MobiL ,II. 'II' ,II, .". ,IL 'II' ,II. '11' Phi I, I. i p ,~;' p:ø lJJf:~I.l Fi I.E";:: I:;, * I'I , \,'C ... ,II. 'II' .11, 'II' .11, 'II' ..'. I ' ,~¡. <:) "\ I C) Stat('~1 of r~I,aska T E' X <:1 c: 0 Dr'E'SS I) \- I'::. <- ..... I ,....~.:> \.t;;c~:~.;!;.~~ (J¡i II r11"~' '.l. .~k;:,:;, ;..,ans. f;V7'.I!"¡"~i(',,¡\,"1~..' , ""..."".",;",1'",::: i.irJPh"",." ",.d"";:;'¡dnr. ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska DATE: Sep t e,,\ber ARCO Cased Hole Final REFERENCE: 1-34 3-10 4-13 11 -24 7-15-86 7-21-86 7-11-86 7-14-86 ( t ( \ 99519 11, 1986 ACBL/VDL/SIN/GR ACBL/VDL/SIN/GR Multi=Space CNL/GR ACBL/VDL/SIN/GR Run 1, 51 Run 1, 5 I Run 1, 51 Run 1, 51 D,-ess D,-ess Dress DI-ess - - ----- ~ __~nl~§¥~~~~~~~~~ .. Anchorage CE DAY! ,. Rosanne Peek ATO-1529 , TRANS ~86562 DISTRIBUTION Central Fi Les Chevron' D ~ M Extension Exploration Exxon Marathon Mob i l ~ Ph i II ips PB We II F i L es R ~ D ~ Sohio a:i~~:. '¡.,S. tat e;it;.g,f\Í¥' A I .a sk a~rrt ~t._.....i!:<\'~;..i;",:,""",'D,;;;;;::...~.,,"~t;~¡!.ii.:I""-""""""'",}l",' ... Texaco ... ... ... ... ... ... ... ... ... ... ~ ~ ( STATE OF ALASKA ( ~ ALASKA ulL AND GAS CONSERVATION CL-.:~MISSION ,¡C, WELL COMPLETION OR RECOMPLETION REPORT AND LOG -{~,' '~:, 1 . Status of Well Classification of Service Well 1Î? SERVICE ~X Water Injector 'V¡ OIL 0 GAS 0 SUSPENDED 0 ABANDONED 0 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-21 3. Add ress 8. API Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20361 4. Location of well at surface 9. Unit or Lease Name 2134' FSL, 638' FWL, Sec. 11, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1359' FNL, 1403' FWL, Sec. 11, T10N, R15E, UM 3-10 At Total Depth 11. Field and Pool 1357' FNL, 1403' FWL, Sec. 11, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 64' RKB ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/08/79 09/01/79 09/07/79* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+lVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9780'MD,9246'TVD 9732'MD,9198'TVD YES~ NO 0 2156 feet M D 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/CAL/GR, FRT, DM, GR/CCL/CNL, GR/CCL/CBL/VDL/Signature Log, CBL, Temp. Svy. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASI NG SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED LV' Y4.U# H-40 Surf 81' 24" 170 sx AS II cmt 13-3/8" 72.0# L-80 Surf 2731' 17-1/2" 500 sx Fondu & 4000 sx IS II cmt 9-5/8" 47.0# L-80&S-95 Surf 9067' 12-1/4" 800 sx Class G cmt & 30( sx AS II 7" 29.0# L-80 8745' 9775' 8-1/2" ("270)x Class G 50'1) ? 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) See Attached 5-1/2"/4-1/2" 9531' 8561'&9453'~9518'WLM 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATËRIAL USED All perfs f/9398'- 561' 150 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PER 10D . - Flow Tubing Casing Pressure CALCULATED 01 L-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 24-HOUR RATE. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core data was sent under a separate cover letter dated 10/8/79 by the Geology ~ .... 6' r,- 1 '\ 17 ~...., f\ "p~r ,ment'. ',I, .', \¡) .1 ".c, .: .., . ','" C "', '1(~86 \, j>'" .., ;Alaska OH :,:3100 c. ,. . ABC"l","f"', - ,..;, ,~,~,.., IJ ~ Form 10-407 Rev. 7-1-80 (DAM) WC 1 1099 *NOTE: Well was worked over 7/27/86. CONTINUED ON REVERSE SIDE Submit in duplicate .' ¡j -------- l GEOLOGIC MARKI::H$ 30. l' ( 29. FORMATION TESTS - NAME -- MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase, Top Sadlerochit Base Sadlerochit 9185' 9660' 8651 ' 9126' N/A --,--------'-----""-"--- .----..--.-..-.,---- .-----.-----'---- ------'" 31. LIST OF ATTACHMENTS None - -. - """"""-"----""'---'--'--- - .------,.--------.---- - .--'---'- .-------- 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -~~~i~~u ~IA --' _-.-:r;tle A ssoc ;:e Eng; neer Date gr.~h 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: I ndicate 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 (OF, 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 I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 '" PERFORATION DEPTHS Well 3-10 . All Perf'd w/4 spf WC1/099b:dmr ~. ( WELL COMPLETION OR RECOMPLETION REPORT AND LOG MD TVD .-:-~ 9188' - 9208' 8654' - 8674' 9216' - 9236' 8682' - 8702' 9256' - 9266' 8722' - 8732' 9272' - 9292' 8738' - 8758' 9354' - 9369' 8820' - 8835' 9460' - 9474' 8926' - 8940' 9500' - 9512' 8966' - 8978' 9533' - 9555' 8999' - 9021' 9560' - 9576' r--: \ 9026' - 9042' :')\~" .,.i..",. ,,"'~¡¡Id:;,..,d ( " \, ,("" I ~\ ',; ~' r: ;r\ , :': i::)~~ '!'.'.., 1. Operations performed: Operation shutdown 0 Stimulate 0 Alter Casing 0 Other XX Workover Plugging 0 Perforate 0 Pull tubing 0 c/~ '1ß A6!; ,/ 4L1. ø '2. Feey ~ . ~ STATE OF ALASKA ( ALA~ . OIL AND GAS CONSERVATION CO~I" .>SION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator ARCO Alaska. Inc. 3. Address P.o. Box 100360 Anchorage, 4. Location of well at surface 2134'FSL, 638'FWL, Sec.11, T10N, R15E, UM At top of productive interval 1359' FNL, 1403'FWL, Sec.11, T10N, R15E, UM At effective depth 1357'FNL, 1403'FWL, Sec.11, T10N, R15E, UM At total depth 1357'FNL, 1403'FWL, Sec.11, T10N, R15E, UM 11. Present well condition summary Total depth: measured true vertical AK 99510 5. Datum elevation (DF or KB) RKB 64' 6. Unit or Property name Prudhoe Bay Unit 7. Well number ~-'n 8. Approval number Permit #79-21 9. API number 50- 029-20361 10. Pool Prudhoe Bay Oil Pool Effective depth: 9780'MD 9246 'TVD measured 9732'MD true vertical 9198' TVD feet feet Plugs (measured) None feet feet Junk (measured) 9639' Casing Conductor Surface Length 80' 2701' Size 20" 13-3/8" 7" Cemented 170 sx AS I I 500 sx fondu & 4000 sx AS I I 800 sx Class G & 300 sx AS I I 270 sx Class G Measured depth 81'MD 2731'MD True Vertical depth 81 'TVD 2731 'TVD Production 9040' 9-5/8" 9067'MD 8533'TVD Li ner 1030' 8745'-9775'MD 8211'-9241 'TVD Perforation depth: measured (see attachment) R ""-, e"'", ' ~-.. 'II, '\\" .~ f,',-,.. \1"".'.' . 1 . t, ~ /; ;'. '. ~ \ì.: I:"', ,!.. t ':', .~ :'- l. i." ':' ',' ..' true vertical (see attachment) ,.I'\, II I{~' 1 ",II' ..~,.986..; ¡.." !,....i ~_.\ Tubing (size, grade and measured depth) 5-1/2"/4-1/2", L-80, tbg w/tail @ 9531'WLM Packers and SSSV (type and measured depth) RH 9-5/8" pkr @ 8561', WD Hydril pkr @ 9453', 12. Stimulation or cement squeeze summary Alaska Oil Òl '..' .".,I,~;:;lon \' Anc\'¡v[";:iQ,;;. WD pkr @ 9518'WLM, & BAL-O SSSV @ 2156' I ntervals treated (measured) All perfs from 9398' - 9561' Treatment description including volumes used and final pressure 150 sx Class G N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressu re 13. Prior to well operation Subsequent to operation 14. Attachments (Workover Well Hi story w/Addendum, dated 7/30/86) Daily Report of Well Operations XX Copies of Logs and Surveys Run 0 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ( ~ C/rrvx...;A J , hi A- Form 10-404 RevÚ 2-1-85 DAM SWO/085 Date 8~f.p.-8t 0 Submit in Duplicate Title Associ ate Engi neer PERFORATION DEPTHS Well 3-10 (cont'd) SWO/085a:tw { ,~ REPORT OF SUNDRY WELL OPERATIONS MD TVD 9188' - 9208' 8654' - 8674' 9216' - 9236' 8682' - 8702' 9256' - 9266' 8722' - 8732' 9272' - 9292' 8738' - 8758' 9354' - 9369' 8820' - 8835' 9460' - 9474' 8926' - 8940' 9500' - 9512' 8966' - 8978' 9533' - 9555' 8999' - 9021' 9560' - 9576' 9026' - 9042' "I'" f'" \:,., ;I. 'I: L, ",j \"- (~ ¡¡. '§ Ii") !\,.~ I, \:.., ~ Ú'( ',j \\." L, !\ U"'~ . J\\\ ':(; 1 1. 19BG f'\\ -., '-' " ~ f'o11'\"\n"I\ss\o:;\ () (' '¡C lO;\5.. \,II UliU ,~'\as\{a Oi\ ct ~!"," ' [-I. - J\nd"orage (' ",'" \ . ADD END U M -------- WELL: 3-10 7/29/86 RU Otis, RIH, pull dummy SSSV @ 2150' WLM, POOH. RIH to 8794' WLM, pull XX plug fIX nipple. Secure master vlv. Turn well over to Production. Rr:rr,.:W\fED Ii,.. \." ~1"" 11 \I ,- Ii:, 1986'" ,,(, " 1\,1, Iii '.1 ;, :..; ;.»;)$. Cornmission /1.nchorage ~ßRð- J Drilling Supervisor ;Z ~1/g'~ Da e ., ,~ , .. ~ . <' ARCO Oil and Gas Company <> r Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the IIrst Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only, District County, parish or borough North Slope Borough Alaska IState Alaska Field Well no, I 3-10 W/O Lease or Unit Prudhoe Bay ADL /128328 Auth. or w.o. no, Tille AFE AS0219 Recompletion WWS /11 API 50-029-20361 Operator ARCO W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun Workover Date Prior status if a W.O, Hour 7/13/86 0300 Hrs. Date and depth as of 8:00 a.m. Complete record for each day reported 7/13/86 thru 7/14/86 7" f/8745'-9775' 9732' PBTD, PU 3~" DP Accept rig @ 0300 hrs, 7/13/86. ND tree, NU BOPE & tst to 5000 psi. Pull tbg hgr, spear tbg, shear out of PBR, LD tbg. Chg rams to 3~" & tst to 5000 psi. TIH w/fsh'g tIs & 3~" DP. 7/15/86 7" f/8745'-9775' 9732' PBTD, TIH w/pkr picker TIH w/PBR fsh'g aBBY, OS & grapple too big, POOH. PU 6" OS, TIH, reI PBR, POOH & LD same. PU pkr picker & TIH. 7/16/86 7" f/8745'-9775' 9732' PBTD, Mill pkr TIH w/pkr mill, pmp 60 bbls kill pill; did not hold. Pmp new 100 bbl kill pill & chase w/8.7 ppg brine. Sqz pill into formation, circ well; no fluid loss. Millon pkr @ 8556', fluid level holding. 7/17/86 7" f/8745'-9775' 9732' PBTD, Fsh'g TP assy 8.9 ppg NaCl Millon pkr until free; well started flowing. Pmp kill pill, f/8.7 ppg - 8.9 ppg, POH w/pkr. Left tail pipe assy in hole. raise mud wt 7/18/86 7" f/8745'-9775' 9732' PBTD, CBU 8.9 ppg NaCl Brine RIH w/spear to 8428', spear 4~" tbg, POH, LD pkr & CA. RIH, circ @ 7" TOL @ 8767', tag top of fill @ 9567', wsh & rm, pushing junk dn to 9639'; unable to push further, CBU. 7/19/86 thru 7/21/86 7" f/8745'-9775' 9732' PBTD, CBU 8.9 ppg NaCl Brine POH to 8715', pmp 75 bbls cln Bridgesal pill, FOR. RU DA & rn GR/CCL/CBL/VDL/Signature log f/9598'-8650', RD DA. PU 9-5/8" RTTS, RIH to 2500', tat csg to 1500 psi. RIH to 8700', tat csg to 1500 psi, FOR. RU DA, RIH, set EZSV @ 9400', RD DA. PU stinger, RIH on 3~" DP, est IR, M&P 150 sx Cl "G" & hesitate sqz cmt into perfs. Spot 3.5 bbls on top of EZSV, FOR. RIH w/new BHA to TOL, WOC. RIH, drl EZSR tl t N'EÐ39" CBU. !'3 1 1 1~386 Alas!ca Oil & G:::s :;'::. C(jrnm!zJicm 1\ [",!(':"r,' t'i, ,c', I..! ,..' The above is correct s\J.rJ>.~ Date Title 7/30/86 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. . " ARtO Oil and Gas Company ,(~,.. ~ ~ , Daily Well History-Interim InstructIons: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. I Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" 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 County or Parish Alaska North Slope Borough IState Alaska Iwell no. 3-10 W/O Field Lease or Unit Prudhoe Bay ADL 1128328 Date and depth as of 8:00 a.m. Complete record for each day while drilling or workover in progress 7/22/86 711 @ 9775' 9732' PBTD, Top of fill @ 9639', Prep to sqz 8.9 ppg NaCl Brine TOH. Rn DA CBL f/9620'-8650' WLM. Rn temp surv f/9620'-7500' WLM; sqz unsuccessful. RU & perf W/411 gun, 4 SPF, f/9446'-9448'. Set EZSV on WL @ 9393'. TIH w/stinger, est IR @ 2 BPM, 500 psi. Prep to sqz perfs. 7/24/86 711 @ 9775' 9732' PBTD, Top of fill @ 9639', Drl EZSV 8.9 ppg NaCl Brine Sqz all perfS}W,/150 sx Cl IIG" w/2% KCl, .86% FL28, .2% CD-31, 1 GHS FP8L. TIe w/bit, DO cmt to EZSV, drl on EZSV. f/Q3C¡8'- ?SÚJ I' 711 f/8745'-9775' J 9732' PBTD, Top of fill @ 9639', Rn gage ring 8.9 ppg NaCl Brine CO cmt & retnr to 9631', CBU, POOH. Re-rn CBL/VDL/Signature logs f/9562' WLM to 8753' TOL. Rn gage ring/JB. 7/23/86 7/25/86 711 f/8745'-9775' 9639', Rn JB/gage ring 8.9 ppg NaCl Brine POOH, LD JB/GR. RIH w/7" csg scrprs, tag fill @ 9561', RU & re-perf 9560'-9576',9533'-9555', 9500'-9512' & 9460'-9474'. Re-rn gage ring/JB. POOH. D",! I,,'"" (.. N,'.' f \,1 ['" 1"') "'1"' ".., I'},~ ~ î\;! :\ ( , ' ,~II . """ "".. L., ,~ ;".. It",. 1\ ~ i {,~" 1 "1'10 t} C' t;l~,',1, -I. .¡.:H)iO AJaska OìJ & Gas COilS. Commiz::;iüp Jlunchorag&, , The above is correct \ju ~ Date Title 7/30/86 Drilling Supervisor For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 " ~ (" A tla nticRichfieldCom pahy ~~ ~, ~ r \ Daily Well History - Final Report , Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well Is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an Indefinite or appreciable length of time. On workovers when an official test is not required upon completion. report completion and representative test data In blocks provided. The "Final Report" form may be used for reporting the entire operation if space Is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Prudhoe Bay Auth. or w.o. no. ADL 1128328 Iwell no. 3-10 W/O Field Lease or Unit Title AFE AS0219 Recomp1etion WWS III API 50-029-20361 7/13/86 Total number of wells (active or inactive) on thiS¡ cost center prior to plugging and abandonment of this well Hour 0300 Hrs. I Prior status if a W.O. Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover A.RCo. W,I. 21. 66% Date Date and depth as of 8:00 a.m. Complete record for each day reported 7/26/86 thru 7/27/86 7" f/8745'9775' 9639', RR 8.9 ppg NaC1 Brine + 100 bb1s diesel cap Rn 7" straddle assy w/WD pkr @ 951~, Champ pkr @ 9453', 7" WD Perm Pkr @ 9518',9-5/8" @ 8700', btm of mu1eshoe @ 9531'. POOH, LD Otis setting tl. Set 7" pkr on WL @ 9310' WLM. RIH w/9-5/8" pkr w/4-1/2" tailpipe on 5-1/2" tbg. Lnd tbg w/9-5/8" RH pkr @ 8561', Ba1-0-SSSV @ 2156' & wire1ine guide @ 8849'. POOH, LD DP. RU Otis, pull dummy. Disp1 well w/100 bb1s diesel. Set dummy, tst csg to 2000 psi. ND BOPE, NU & tst tree. RR @ 2300 hrs, 7/27/86. RI tT"" ('" ~"" 'I '\ 11 ~(' ¡,"'" ( ¡:',.!' ¡r '\,t.~".:t! ',':, f~("'.'11' '!""oro '..~\,:':J..;i ,'q"",}"",' "'" ..1. .,.. \.' I",,' Alaska OJ! & C,US CL.',¡ ,< '.., , Ar¡C'¡"""."I4':"" , ',,!'J. ù'~I';;i :; ~ () ¡11 Old TD New TD PB Depth 9639' Released rig Date Kind of rig 2300 Hrs. 7/27/86 Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc,) Single Flowing Official reservoir name(s) Sadlerochit Producing method Potential test data Well no. Date Reservoir Producing Interval 011 or gas Test time Production 011 on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Sign Date Title 7/30/86 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ,l' ARCa Alaska, Inc,( Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ( åt/ ~~ 1°~ ",'i "II1II II'" ), ~ ¡W\ October 29,1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 3-10 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. pull the tubing and repair DS 3-10. We expect to start this work on December 15,1985. If you have any questions, please call me at 263-4944 or Eric Witten at 263-4968. We propose to Sincerely, t.~;U~ Associate Engineer JG/tw GRUI2/L42 Enclosure RECE\\fED eel' 3 1.1'!ßfJ " cororolSSí\Oí! "\ & Gas Cons. A\a.S\<a 0\ Anchorage ARca Alaska, Inc. is a Subsidiary of AlianticRichfielclCompany ,. ( STATE OF ALASKA ( ALASKÀ OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL 0 COMPLETED WELL oXX OTHER 0 2. Name of Operator ARCO Alaska 3. Address 7. Permit No. Inc. 8. API Number 50- P. O. Box 100360 e AK 99510-0360 4. Location of Well Surface: 2134' FSL, 638' FWL, Sec.11, T10N, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-10 5. Elevation in feet (indicate KB, DF, etc.) RKB 64' 6. Lease Designation and Serial No. ADL 28328 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) 0 Altering Casing 0 Abandonment 0 Other 0 0 0 0 (Submit in Triplicate) Perforate 0 Alter Casing 0 Perforations Stimulate 0 Abandon 0 Stimulation Repair Well 1&1 Change Plans 0 Repairs Made Pull Tubing þ! Other 'Ø. 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 perform a workover on the subject well. The procedure will be as follows: 1. MIRU. Kill well. ND tree. NU BOPE & test. Pull tubing & packer. Clean out to top of fish (tubing tail). Recover fish. Install isolation packers at 9516'MD, 9453'MD, and 9310'MD. Install a 9-5/8" x 5-1/2" packer at 8520'MD. Run tubing. ND BOPE ~NU tree. Secure well & release rig. 2. 3. 4. 5. 6. 7. 8. 9. 10. A 13-5/8",5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be test~d weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within permafrost intervals. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start: December 15,1985 '~(Yl' "'" ~ lnG( () ;"oJ a ,,~j ;;;! a;, . 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. '" .""",- ¡b,!'ìr'"I),(jl":::;,',¡'C '\ ",'",. 'U'l;:" Signed The space bel Conditions of Approval, if any: r Title . F. J.1CSSNf Regional Drilling Eng;n~~r Date 1()~28' as: IRIG\JAl SliMED It LONNIE C. SMITH " Approved Copy Rzrned ~". 1/ 1J1J!~- f Date ß-JiLð-5- Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER By Order of the Commission GRU12/SN08 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, '17" Post Otfi 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 ( ~~ ~~ Date: Au gus t 1, 19 85 Reference: ARCO CH Finals 2-13VEpilog 5-12-85 Run 1 5" DA 3-6'/ Temp Log 7-13/14-85 1 5" Camco 3-6/ spl.nner 7-17-85 1 5" Camco '3-7/ Temp 7-13-~5 1 5" Camco 3-10""'" Spinner 7-17-85 1 5" Camco 4-12""""'- Epilog 5-13-85, 1 5" DA 6-10 ", Epilog 5-10-~5 1 5" DA ** 13- 34'" TDT 11-23-84 3 5" Sch ***Th is log has the wrong date on it. 11-23-84 is the correc' date, not 11- 23-85 . t**********~ 13-34/TDT 11-24-84 2 5" Sch d ¡Q~-15 ~ilog 5-11-85 1 5" DA 14-22~emp. 7-15-85' 15" Camco 15-9'; CET 11-~-84 . 15" Sch Please Sl.gn as Received by roJ - " ¡I.. U~L ..'t, U (J'- '.-¡:.~,é. '. , ¿ 1geF~- '.> \J ~~ . 1.1) " ' ,." ¡" ,',' {~CIf}S I.','~ . C ... ~.I ',.. "i .::'i,. Ofhfh,' , ' 'lye "1"1 ssio/1 Pam Lambert ATO 1429C Trans 249 Chevron D & M Expl. Services, , Ext. Exploration Exxon Marathon Mobil Phillips, PB Well Files R & D Sohio State of Alaska Texaco ARca Alaska, Inc, is II Subsidiary 01 AllllnlicRichlieldCompany ,"" ARCO Alaska, Inc. "..- Prudhoe BaJ .Ieering Post Office Bòx 360 Anchorage, Alaska 99510 Telephone 907 263 4248 ( I Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 Permit II 76-60 DS 9-18 Permit If 77-39 DS 3-7 Permit II 76-53 DS 9-17 Permit If 77-38 DS 3-10 Permit If 79-21 DS 9-19 Permit II 77-40 DS 3-18 Permit If 79-103 DS 9-20 Permit If 7 7 -41 DS 4-6 Permit II 76-42 DS 11-2 Permit If 81-128 DS 4-8 Permit If 76-10 DS 16-1 Permit If 80-136 DS 4-11 Permit If 78-6 DS 16-2 Permit If 80-150 DS 4-14 Permit If 78-36 DS 16-3 Permit If 76-83 DS 4-15 Permit If 78-37 DS 16-5 Permit If 81-37 DS 9-8 Permit If 76-70 DS 16-10 Permit If 80-04 DS 9-10 Permit II 76-82 DS 16-11 ,Permit If 80-118 DS 9-12 Permit II 77-7 DS 16-16 Permit If 80-127 DS 9-14 Permit II 77-25 DS 17-6 Permit If 80-132 DS 9-15 Permit If 77-36 DS 17-8 Permit If 81-74 DS 9-16 Permit If 77-37 DS 17-10 Permit If 81-97 Dear Mr. Chatterton: ~~ ~~ Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, ,{),nJfJ jJ ~ D. F. Scheve DFS/JEB/mjb RECEIVED JAN 2 5 1985 Petroleum Company Alaska Oil & Gas Cons. CommIssIon Anchorage Attachments cc: Sohio Alaska ARCO AlASkA, Inc. Is II SubsidiAry of AtlllnllcRlchfleldCompliny {/J~ ~::~ ,.. '" 1~ (e; ~ - I fL " (' STATE OF ALASKA ( ALASKA OILAND GAS CONSERVATION COMMISSION SU'NDRY NOTICES AND REPORTS ON WELLS , 1. DRILLING WELL 0 COMPLETED WELLKJ OTHER 0 2. Name of Operator AReO Alaska, Inc. 7. Permit No. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 2134'N & 638'E of SW cr Sec. 11, T10N, RISE, UM 79-21 8. API Number 50- 029-20361 9. Unit or Lease Name Prudhoe Bay Uni t 10. Well Number 1359'S & 1403'E of NW cr Sec. 11, T10N, RISE, OM DS 3-10 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 64' RKB 1357'S & 1403'E of NW cr Sec. 11, T10N, RISE, lmŒ 6. Lease Designation and Serial No. ADL 28328 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate 0 Alter Casing 0 Perforations Stimulate 0 Abandon 0 Stimulation Repair Well 0 Change Plans 0 Repairs Made Pull Tubing 0 Other 0 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. has converted DS 3-10 to water injection service. The well is part of the Flow Station 2 water flood project. (Submit in Duplicate) 0 Altering Casing 0 Abandonment 0 Other 0 0 0 ~ The well began receiving water on September 23,1984. '--.... RECE~VED lì b~ Ii\ B ':') !"" lq "' h ~I ó"'l, e '\5 (~ ~) ..... to "J Alaska Oil & Gas Cons. Gommission Anchorage 14, I heceby certify that ~Oing is tcue and corteet to the best of my knowledge, s;gned--!) YJ1 'l ~ h......- T;tle Regional The space below for Commission use Conditions of Approval, if any: Engineer Date ~2../fo'Ji.- 1" I ",,-æ\~,,:l,...,,¡,'t.I";"""\"""'~~"':"i ,j '~" ,. " I"~"~ J , :~( Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER By Order of the Commission Date .. .. on.... Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate P..O. /... 1:"'1-- (") ""'!" S I' ~"' 1-1 p, ~... \- 1-" d ... Q " I:{ (-, y , ",' ~'i 11 C h 0 r <:1 q E' " D {'j T E : I"J E' r- E ( , 1-, E' 'u ,'-7~'.'diLJ,:'1 '-'I'-F',"'r'!-'IC"" , '\:~'::.,~,:,r\ ,1:" I) <:' , " ..~ .. I", ) " :~, .. I' '" 1 ... , .. .., ... D.. S:.. n <" ...' .. ..'> .. D '" I '. " '..' I, r" {'", } .. ..':, .. r' ..., I ... " .. ",' .. I' ~" , ... .:~ .. 11.. oS.'.. I) \" , .. ..~ .. D (., .. .:, . 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I, ::~4 í (,;,:' C h (.~, ...... r" C) n I) ~ i./. " ~,~ I HDI.E' Fin(31.:;;: ('F:'~""'~"""'-'- , .:>;..'~Plllllf.:') Í'I::-~'~/~~!'; - ""',- ~..' ." ,:' ,J'~ J I ) ¡ ) ) ',-= ) D iff T f.~ il) P L D ,] D iff T Eo 111 P CFS/Sp ¡ nni:!'r (" r" '" ,..., I' ~ .,,'.:':,,/.::,:i;nn\::')- CN,/hS l/GF~ SF' í nn(~)- Log "', "'! /'.! (" ,'-"'" L 1\.... t,!..'".. l,1' '~, (" ;. I ", l ':~ ... (.. '-, ., r... / I' ¡ .::, l :r I", Sp i nnf::'r L.OÇJ ("'" ,..,,~ '(-'U ..,I\,/r¡~,/ ,\",: Sp i nn€,:'r Log S pin nfl.')- I... (J 9 Inj Pr'of i l€~/S'p ¡ n'n€~'r S p ¡ n n (~)" ,/ T f? in F:' ,/' I n ..i P 'I" D 'f i l ('::' S pin n f:!)" /T E' f¡'¡ p / I n j P r D .r i l E'! I n j F')- (") of i I. p / S pin n t::')- .../ 'r ('::' j¡) P Sp i 'nnf?'r l. 09 I n j P ¡" CI f i I. f.~ /' S pin n (::')- ,,/ T (~:: f¡'¡ p CFS/.:';:P i nnE:'r Diff T(~tnp I...O(j '1.loot!,~ ,~'i'+':r'I"l..';'("1 , I 0;;, ",I" (,I -, I 0;;, .. , )-~,...... I' '" ,¡, c: C) p Y' ¡;¡ S 0::.' t. 1::.' I'.", ,\la::;K2: Oij ~~ i;:;1S C;;iI~~;, l)d~"-lnìlsSIOlI Ie: Ci '~~ n]'~:"T'I;'T\"{!I""Tt"i\1 ,~" ,.... ' .., ,L ", I ./, \.., !... Exploration Services Extension Exploration E' v y ("', "', - '" " ,.. I G (~':' t t y r"í a ¡.. ¿:'¡ t h D 1"1 Mobil hob i I. E ¿: F" Phi l !, I P :::: !::"'-'!rl~'I{"P r:.,'-", I I '", u I ..! ;', .\ "¡; 'f h: t,: :0 SohiD S t ':~ t E' D of p I. ¡¿i s k d It,.. l ! ,'"..' ,", -, , I:;, ¡ , .., " -~ I I F: u. 1"1 F;: IJ. 'Ii '"I F~llÏi ¡:;~ u. '¡"¡ ,:':0 i": u. n F:U'!Ï í~: u. n F:u'¡,,¡ F U. 'Ii F~ U ï'j C' I' '," 1', ,,', ¡ I I:;, I' .., '...', I i I~: un F~u.'¡"'¡ ¡~: u. n PU'¡"I I~: un lu' I , .., "', ',,~ I I F:un ~ 'í í '1 ~ I í í , " J ~ I , " 'i i 'I í 'I í '1 í í i I::' " I c' ,.. I, ç:.' .::' 1::.: D GO GO GO GO GO GCi :::: ~ ~::: 1\ 1:;: II L-:; 1\ => Ð :::: 1\ DP! C (.~ lï¡ C C) D~i D(': C ,¿OJ Ii) c: D C, H -,' I::' 1\ -,:' I::; E '¡ II ..'.. ~:> e Di:', C (:) rn c: D La lï¡C D C,:ìlï¡C: 0 I::' II " '-, B ".. "", II ...:, => H :::: n C a ¡'¡'j C (j C ~'J (¡"¡ c: 0 C ('iI 11) C D C¿"I¡'¡CD C,:';I(¡'¡CO GO 1:;' n "l ":' /I .:.. 58 1::' U ..,:' t:' II 'u:' GO ,/" ARCO Alaska, In( Prudhoe Bay t::nglneerlng Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 (: ~~ ~~ Donald F. Scheve Regional Operations Engineer October 19, 1984 Mr. C. V. Chatterton STATE OF ALASKA Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 RE: Prudhoe Bay Unit DS 3-10 DS 3-18 Permit No. 79-21 Permit No. 79-103 Dear Mr. Chatterton: Enclosed are .. Subsequent" Sundry Notices for the above mentioned wells. 7! ;'JJ)~ D. F. Scheve DFS/DLL/JB/mjb cc: SOHIO Petroleum Company File P1(DS 3-10)Wl-3 File P1(DS 3-18)Wl-3 RECEIVED OCT 1 91984 Älaska Oil & Gas Cons. Commission Anchorage ARca Alaskl. Inc. 1'1 Sub,'dllry of AlllntlcRlchlleldComplny " STATE OF ALASKA , ALAS~, I LAN 0 GAS CONSERV A TION( JI MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 . DRILLING WELL 0 COMPLETED WELL ~ OTHER 0 a t-/.f- G3 ..... ~ ~ tl 2. Name of Operator ARCO Alaska, Inc. 7. Permit No. 79-21 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 2134'N & 638'E of SW cr Sec. 11, T10N, R15E, UM 8. API Number 50- 029-20361 9. Unit or Lease Name Prudhoe Ba ,--( Unit 1359'S & 1403'E of NW cr Sec. 11, T10N, R15E, UM 10. Well Number DS 3-10 1357'S & 1403'E of NW cr Sec. 11, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designëtion and Serial No. 64' RKB ADL 28328 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate 0 Alter Casing 0 Perforations Stimulate 0 Abandon 0 Stimulation Repair Well 0 Change Plans 0 Repairs Made Pull Tubing 0 Other 0 Pulling Tubing (Not!'!: Report mI,Jltiple 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 25.105-1701- Began perforating operation 9-20-84. equipment. RIH with gun #1, (Submit in Duplicate) ex Altering Casing 0 Abandonment 0 Other 0 0 0 0 RU perforating unit, pressure tested RIH with gun #2, RIH with gun #3, RIH with gun #4, RIH with gun #5, RIH with gun #6, shot interval Shut-in well, shot interval Shut-in well, shot interval Shut-in well, shot interval Shut-in well, shot interval Shut-in well, shot interval Shut-in well, 9188-9208' MD (4 POOH, all shots. 9216-9236' MD (4 POOH, all shots. 9272-9292' MD (4 POOH, all shots. 9354-9369' MD (4 POOH, all shots. 9256-9266' MD (4 POOH, all shots. 9560-9576' MD (4 POOH, all shots. spf) , flowed fired. spf) , flowed fired. spf) , flowed fired. spf) , flowed fired. spf) , flowed fired. spf) , flowed fired. well to clean up. well to clean up. well to clean up. well to clean up. well to clean up. well to clean up. Ran SSSV, secured well, RD. RECEIVED Ref: BHCS 8/31/79 OCT 1 91984 14. I herßby c ify that the f egOi,ng isøue and correct to the best of my knowledge. Signed 1 ~ Title Regional Engineer The space below for Commission use ---~-~_.-- Conditions of Approval, if any: Alaska Oil & Gas Cons. Commission Anchorage Approved by Form 10-403 Rev. 7.1-80 - COMMISSIONER By Order of the Commission Date ---.........,.,....----.....-.-....'..'- Suþmit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir( Prudhoe Esa;, _ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 ( Donald F. Scheve Regional Operations Engineer October 19,1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-10 DS 3-18 Permit No. 78-21 Permit No. 79-103 Dear Mr. Chatterton: ~~~ " K. ~ ". 7t' \-.""... ~ U~tl Jk -r Attached are "Well Completion" Reports for work completed on the above-mentioned wells. ï ;;;;~ D. F. Scheve DFS/BB/mjb Attachments cc: Sohio Alaska Petroleum Co. File Pl(DS 3-10)Wl-3 File P1(DS 3-18)Wl-3 RECEIVED OCT 1 91984 1\laska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. III a Subsidiary of AtlantlcRlchlleldCompany ,,"' STATE OF ALASKA (:.. ALAS~ ">- AND GAS CONSERVATION " ," JlISSION . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL 0 GAS 0 SUSPENDED 0 ABANDONED 0 SERVICE~ Water In;ector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-21 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20361 4. Location of well at surface 9. Unit or Lease Name 2134' N & 638' E of Sw Cr Sec 11, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1359' S & 1403' E of NW Cr Sec 11, T10N, R15E, UM 3-10 (22-11-10-15) At Total Depth 11. Field and Pool 1357' S & 1403' E of NW Cr Sec.11, T10N, R15E, UM Prudhoe Bay Field 5, Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/08/79 09/01/79 09/07/79 N/A feet MSL 1 17. Total Depth (MD+TVDI 18.Plug Back Depth (MD+TVDI 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9780'MD,9246'TVD 9732' MD, 9198' TVD YES ex NO 0 2266 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/cNL/CAL/GR, FRT, DM, GR/CCL/CNL 2~. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94:/1: Welded H-40 81' 24" 170 sx Arctic Set II cm 13-3/8" 7241: Butt L-80 2730' 17-1/2" 400 sx Experimental &4 )00 SC Arctic II cmt 9-518" 47# Butt 80 & 95 9065' 12-1/4" 800 sx Class "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI 9533' - 9555' MD *Added on 9-21-84 5-1/2" 8659' 8523' 9500' - 9512' MD w/4 spf 9480' - 9474' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9425' - 9450' MD DEPTH INTERVAL (MOl AMOUNT & KIND OF MATERIAL USED *9188' - 9208' MD *9272' - 9292' MD N/A *9216' - 9236' MD *9354' - 9369' MD *9256' - 9266' MD *9560' - 9576' MD IJ 1= ( r: I \/1= n Producing Interval: 8591-8978' TVD . ... ... - .... 8 Y ......., 27. PRODUCTION TEST ""'r 1 a , Date First Production Method of Operation (Flowing, gas lift, etc.) -"-'. - '" N/A ... , na t:> "".,,~ /"to" .." . _n ... ~~8~~~~'RATI0 Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE} TEST PERIOD. - Flow Tubing Casing Pressure CALCULATED 01 L-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (carr) Press. 24-HOUR RATE. 28. CORE DATA Brief description of lithology, p~rosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core data was sent under a separate cover letter dated 10/8/79 by the Geology Department. Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 29, 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Sadlerochit Base Sadlerochit 9185' 9660' 8651' 9126' N/A 1----- 31. LIST OF ATTACHMENTS .------- -------------.--.. I hereby certify that the foregoing is true and correct to the best of my knowledge s;gned~ Title Regional l-------.------------------ --- u.,,-,------_.--- --------- ..------ 32. Engineer Date /O/11/ry / I 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. Itern,l:,Classificationof 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 thi~Jorm 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 itehl 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separatßly produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, 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 I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate JJnone". Form 1 0-407 " ", ARGO Alaska, Irl Prudhoe b...~ ~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 23,1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 3-4 DS 3-10 DS 3-11 DS 3-12 DS 3-13 DS 3-16 DS 3-17 DS 3-18 Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit NO. d ( ~~ ~~ 76-51 79-21 79-47 79-58 79-71 79-93 79-102 79-103 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, . jJn1A~ D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File P1(DS 3-4,10,11,12, 13,16,17,18)Wl-3 ?- " ARCO Alaska. Inc, Is a Subsidiary of AllanllcRlchlieldCompany RECEIVED MAY241984 Alaska Oil & Gas Cons. Commission .Anchorage " . STATE OF ALASKA ., ALASJ4 I L AN 0 GAS CONSERVATION ( AM ISSION SUNDRY NOTICES AND REPORTS ON WELLS ~ ~ , /1)' ". ;.' t 1 , DRILLING WELL 0 COMPLETED WELL ~ OTHER 0 Prudhoe Ba 10, Well Number ~ ~ ., 2. Name of Operator ARCO Alaska, Inc. 3. Address 7. Permit No. 79-21 8. API Number P.o. Box 100360, Anchorage, Alaska 99510 4. Location of Well 2134'N & 638'E of SW cr Sec. 11, T10N, R15E, UM 50- 029-20361 9. Unit or Lease Name 1359'S & 1403'E of NW cr Sec. 11, T10N, R15E, UM DS 3-10 11. Field and Pool 1357'S & 1403'E of NW cr Sec. 11 T10N R15E UM Prudhoe Bay Field Prudhoe Bay oil Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 64' RKB ADL 28328 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: 12. (Submit in Tripliçate) Perforate ex Alter Casing 0 Perforations Stimulate 0 Abandon 0 Stimulation Repair Well 0 Change Plans 0 Repairs Made Pull Tubing 0 Other 0 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 3-10 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit with the intent to convert it to a sea water injection well. 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. (Submit in Duplicate) 0 Altering Casing 0 Abandonment 0 Other 0 0 0 0 Proposed Perforation Intervals: 9188-9208' MD 9216-9236' MD 9256-9266' MD 9272-9292' MD 9354-9374' MD 9560-9576' MD Ref: BHCS 8/31/79 RECEIVED MAY 241984 Subsequent VVark Reported on Form No!ð-JfB Dated 11-;11-1.3;.'1 Alaska Oil & Gas Cons. Commission Anchorage rtify that the forego'ng is true and correct to the best of my knowledge. Signed The space below .----~~ Conditions of Approval, if any: Title Regional Engineer Date 51;<1 ) ~f 8RI G tMAL SlllEa BY' LON~IE C. SMITH Approved Copy - ~lt~?~. ~_-fL Approved by Form 10-403 Rev. 7-1-80 _u_- COMMISSIONER -------- By Order of the Commission Date §ß.i!li~- --- Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARGO Alaska, Inc. Post Office Bov 360 Anchorage{'a 99510 Telephone \.... "2.77 5637 April 2, 1984 Reference: (' ARCO Pressure Data 3-10/3-18-84 3-15;/'/3-18-84 ,~ 3-18/ 3-18-84 4-5.,/" 3-17-84 4-16¡/" 3-9-84 9-1i'//, 3-18-84 9-6 ,/ 3-18-84 9-10/ 3-19-84 11-2/ 3-17-84 13-27/" 3-4-84 13-28"""" 3-5-84 ......3-5-84 D.S. 13-29""'" 3-12-84 D.S. 14-23"""- 3-10-84 D.S. 14-24.~ 3-10-84 D.S. 14-25"""" 3-11-84 D.S. D.S. D.S. D.S. . D.S. D.S. D.S. D.S. D.S. D.S. D.S. Static Survey Static Survey Static Survey Static Survey PBU , Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey PBU Data Sheet Static Survey Static Survey Static Survey Static Survey Cameo Cameo Otis Cameo Cameo Otis Cameo Cameo Otis DA DA DA Otis Otis Otis ¿Sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. if: 112 Chevron D & M Dallas HAVE A-HAPPY EASTER! ~~ ~~ ~. , 'II! ~JYE ) ~/ ~~~ DISTRIB UTION Mobil Mobil E & P Alaska Oil & Gas Cons. Commission , Anchorage Phillips Prudhoe Bay Well Files Drilling Ext. Exploration Exxon Getty Marathon '. ~ C, C' :, ',c., R & D Carolyn Smith Sohio ':¡;i?¡t;:ate, of, Ala$ka ',~ " ,;' t,' "",',:,:C '-,','0 ,," , ' -, - , ( (' Bill Sheffield, Governor ALASKA DIL AND GAS CONSERVATION COMMISSION March 29, 1984 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 9950H.3192 TELEPHONE(907) 279:-1433 ADM I N I S T RAT I V E A P PRO V A L NO. 192. 1 Re: The application of ARCO Alaska, Inc. to substitute static bottomhole pressure surveys for transient pressure surveys in Prudhoe Bay Unit wells .DS 3-10, DS 3-15, DS 3-18, DS 4-1, DS 4-5, DS 4-11, DS 9-1, DS 9-6, DS 9-10, DS 16-1 and DS 16-9. Mr. D. F. Scheve Regional Operations ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska Dear Mr. Scheve: Engineer 99510 Application for exceptions 23, 1984. Exception to CO DS 9-6 and exception to CO wells DS 3-10, DS 3-15, DS 9-10, DS 16-1 and DS 16-9. to Rule 6 of CO 165 was received March 165 Rule 6(c) for PBU wells DS 4-5 and 165 Rule 6(d) was requested for PBU 3-18, DS 4-1, DS 4-11, DS 9-1, DS ARCO Alaska, Inc. 's application requests substitution of static bottomhole pressure surveys for the transient surveys required in Rule 6(c) ~nd (d) of CO 165. These static pressure measurements were taken during the scheduled FS2 shutdown (March 12-19) after a shut-in of approximately seven days. Pursuant to CO 188 and 192 it has been determined that static bottomhole pressure surveys serve the intent and purpose of Rule 6 of CO 165 and may be substituted for the transient survey. The Alaska Oil and Gas Conservation Commission hereby authorizes substitution of static bottomhole pressure surveys for transient surveys in PBU wells DS 3-10, DS 3-15, DS 3-18, DS 4-1, DS 4-5, DS 4-11, DS 9-1, DS 9-6, DS 9-10, DS 16-1 and DS 16-9 pursuant to Rule 2 of CO 192. 2:2rer Lonnie C. Smith Commissioner BY ORDER OF THE COMHISSION lc ARGO Alaska, I(C'c' Prudhoe. . .:ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 t ,( ~~ ~~ Donald F. Scheve Regional Operations Engineer March 15, 1984 C. V. Chatterton STATE OF ALASKA Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: Prudhoe Bay Unit DS 3-10 DS 3-15 DS 3-18 DS 4-1 DS 4-5 DS 4-11 DS 9-1 DS 9-6 DS 9-10 DS 16-1 DS 16-9 Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. Permit No. 79-21 79-92 79-103 70-42 71-25 78-6 75-76 76-48 76-82 80-136 81-19 rYtw.~1 ~!fð Þr ;;,1 .' ", ..,,; r' I;" ,¡"\f~ :' ,':1.' " ,,::!\ Id,J,"¡,\¡ ,;.¡';;:(:ì.-,.I: '. 1','.; Enclosed are Sundry Notices requesting permission to substitute static bottomho1e pressure surveys in place of transient pressure test prescribed in Conservation Order 165, Rule 6, on key wells 4-5 and 9-6, and section wells 3-10, 3-15, 3-18, 4-1, 4-11, 9-1, 9-10, 16-1 and 16-9. The static pressure measurements on these eleven wells are part of a package being planned to obtain a baseline reservoir pressure in the FS2 waterflood area prior to the start of water injection. Each well will be shut-in for approximately seven days prior to its survey. We believe that these static pressure surveys will provide a better interpretation of reservoir pressure in the FS2 area than transient pressure surveys and will satisfy the intent of Conservation Order 165, Rules 6(c) and 6(d). If you have any questions concerning this request, please contact Dan Cavin at 263-4268. Very truly yours, f)n1J~ D. F. Scheve DFS/DLL/STATE/lmh cc: SOHIO Petroleum Company File P1(DS)Wl-3 ARca Alaska, Inc. Is a Subsidiary of AtlanllcRlchlleldCompany . STATE OF ALASKA l ALAS~. ) LAN D GAS CONSERVATION ( N1 MISSION SUNDRY NOTICES AND REPORTS ON WELLS ~ O€- 'I}.(~ 63 .,....., v1t 1. DRILLING WELL 0 COMPLETED WE LL KI OTHER 0 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 7. Permit No. 79-21 8. API Number 50- 029-20361 r\ H 4. Location of Well 2134'N & 638'E of SW cr Sec. 11, T10N, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 1359'S & 1403'E of NW cr Sec. 11, T10N, R15E, UM DS 3-10 11. Field and Pool 1357'S & 1403'E of NW cr Sec. 11, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc,) 6. Lease Designation and Serial No; 64' RKB ADL 28328 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORTOF: Prudhoe Bay Field Prudhoe Bay oil Pool 12. (Submit in Triplicate) Perforate 0 Alter Casing 0 Perforations Stimulate 0 Abandon 0 Stimulation Repair Well 0 Change Plans 0 Repairs Made Pull Tubing 0 Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Desoribe PrQposed '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. requests permission to run a static bottomhole pressure survey on section well 3-10 in lieu of a pressure transient test for 1984. Conservation Order 165, Rule 6 (d) requires an annual transient survey on one well in each governmental section producing. (Submit in Duplicate) 0 Altering Casing 0 Abandonment 0 Other 0 0 0 0 A static pressure survey will be run while the well is shut-in during the flow station shutdown (March 12-19) to fulfill the State's requirements. The static pressure survey should provide accurate reservoir pressure data. RE(E~VED \\_~A.R 2 ?: 1984 '1\'1 ka Oil & Gas Cons. Commission "as Anchorage - 14. I he,"p;"£ 10"901n9 Is true ano corr.ect to the best of my knO~ledge. Signed '/ ~ Title RegJ.onal The space below for Commission use ---------------- Conditions of Approval, if any: Engineer Date :S/22/ rf , / - -- Approved Copy Returned ,. ' .L:J4.;f;ëfof -. COMMISSIONER the Commission Date j --~ ¿._~--'~Y--_.._- 1~1\"'"n'l"'~"'.~1 r"Iii'~"I"~]\ L ,;', " L'i ,¡¡i ;';:.. ,:() ! i'i' ::!ÎI iL ill BY l~m~n[ ~~" ~MUHJ Approved by Form 10-403 Rev. 7-1-80 -- - Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARca Alaska, Inÿ., ' Post OffiC\ ' 360 Anchorage. t"\laska 99510 Telephone 907 277 5637 ( \ ~~. ~~ December 8,1982 RE: ARCO Cased Hole Finals 0.5.3-10 10-29-82 CH CNL/GR Run 4 5" D/A 0.5. 4-8 11-12-82 Spinner 5" SCH 0 .5. 4- 13 10-30-82 CH CNL/GR Run 5 5" D/A 0.5. 13-3 10-22-82 CH CNL/GR Run 2 5" D/A n. 5 . 14- 7. 10-27-82 CH CNL/GR Run 2 5" D/A 0.5 . 13-4 10-23-82 CH CNL/GR Run 2 5" D/A Please sign and return the attached copy as receipt of data. . Becky Benedi ct AFA-403 Trans. #645 DISTRIBUTION NORTH G'EOlOGY R & D DRILLING P'HIlLIPS SOHIO MARATHON CHEVRON 'EXXON MOBIL GETTY D & M '~ : , 1':'.. ,.,' ',' ."'> " ,'.',l~,£\7,,~/l': ". " !t ,'I) to., ~-- ¡~'Cl ~K "'... )' , '4 , IU;:'~¡:"1 O. , ' "', ' , <" ~. "I " '" '. , \0 G ' ù( as c'-, I.'! (.I{)n (~ -¡./}"7/}O"'" L,a/[¡, . rag(J fJ¡IS'~~(Dn' ARca Alaska, Inc. is a Subsidiary of AtianticRichfietdCompany ARca Alaska, Inc.. Post OffiC( )( 360 Anchorage. Jska 99510 Telephone 907 277 5637 November 8,1982 (' \ RE: ARCO Magnetic Tapes with Listings . \" 0.5. 5-14 /0.5. 4-1 /' 0.5. 9-15 .- 0.5. 13-5 t..--. D~S. 3-10 v 0.5. 13-3 ..-- 0 . 5. 4- 13 ./ 0.5. 1-21 '-- 0.5. 13-4 10-30-82 10-30-82 10-31-82 11-1-82 10-29-82 10-22-82 10-31-82 10-15-82 10-23-82 Cased Hole CNL Tape #ACC 66015 Cased Hole CNL Tape #ACC 66013 SCH SCH Cased Hole CNL Tape #ACC 66014 Cased Hole CNL Tape #ACC 66016 SCH 5CH CNL (6 passes) Tape #ECC 1507 ' CNL/Mu1tispace (2 passes) Tape #ECC 1503 D/A D/A CNL Tape #ECC 1508 D/A D/A Open Hole Tape #ECC 1489 CNL & CNL Repeat. Tape#ECC 1504 D/A Please sign and return the attached copy as receipt of data. Becky Benedict AFA-403 , Trans. #608 NORTH GEOLOGY R & 0 DRILLING PHILLIPS SOHIO MARATHON CHEVRON f,) r",,': If' f: I I ",t,," : ,,"" I'} 1\ P , I" 'I. , "'" ..'~ ,," , !' ,", !, ¡ .. !,- DISTRIBUTION 1\1 0 V I' C) ! (, i r:! ~; " ) d)"", Al'1<,r.,¡ ()IJ & " ~l,)I\,: (¡¡it: ("irl~' (\ ", " ,'.:CIJ/'J;i'-"¡"'11' Anchnrag~} ""hl-¡) EXXON MOBIL GETTY 0 & M :' STATE OF ALASKA' DALLAS L ~/-4'~:;- /, 0/ q , I ~ /' , 6r~/Z-J~;LL £ Yj7orah~ . .. . " "",, " ~~ ~~ Run 3 Run 6 Run 1 Run 3 ARCO Oil and Gas Company North Alas,[," District Post Off;(' )X 360 Anchorage. Mlaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 31, 1981 Reference: ARCa Magnetic Tapes & Listings D.S.9-18 3/6/81 3/10/81 D.S.16-1 D.S.13-12 .,.."".,...."n":'s':3':'10") "',-_..._---,-_.._..~~_""-""~""- 3/9/81 3/20/81 D.S.14-7 3/20/81 (' Tape #DDNLL 8800-9320 Tape #CN/MS Tape #CNL/MS 11800-12990 Tape IICN/MS - Tape lisp 9796-10836 8950-9650 10560-11560 Dresser Atlas Dresser Dresser Dresser Dresser /' I~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #153 ... DISTRIBUTION NORTH GEOLOGY R & D DRILLING ENG. MANAGER D & M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHGN CHEVRON ARCO Oil and G..¡s Company IS a Division ot AlianticRichlieldCompany """""-'..-..",......----."..-..-"" .. ----"--....,,,,-- , ~~ cot\"JA I~l:,C 0 N\ N\ - -ì C9.~~~~~ - -~\--'R" ' r. c- .. ., ì:',J' - "1)\ 1 Er-I',- , --:'-\--'2 E\'~:~'d:;':- _1,\" ') "-': , I oJ' -" r" I'" I ¿1, "', '.." -; ,--..' , r-::n\ \ \ '.,:J..,,- -?;,. --I "'Î (~:'.C.I~'A-~ .-" ,.:; - '" ' ,- -\ ?, G[OL ,." , '-, '\1 c1' ,^,¡ TI':.C '......t-,ì I, , .- -;-:-1' \ C)T (:J TEC ~" 'I -~ ...,,~.. : ,,--....- C' \, ' .. CON~E_R_~.___-- F\ \, F: ( t(l:rr: " C¿/""," ~'~~. i~ V E tJ '¿, r....~",.;' !iG(, ~:~'!:...t""'-1-~~~;'-'/' . . \ ..:. Co> 'rll '-l.-~/r \,) :.J U '~'~"-I.. 0, "', I ,." I; ~I I ,.r !1 (' .. , . \" \ ' , ..' , ,',~ ", ~":;13. C~::'JJm!S I . ." '" :; ,~,,' ,.., '. 3,0'" ,,' ... . ¡ ""'7 " '~ ! "" ARCO Oil and Gas Company North AI~'" District Post Offic~ ...,¡ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Feb 6, 1981 Reference: ARCO CASED HOLE FINALS Q.S.3~~ 2/10/80 Spectralog """..D . S . 3-10 2/10/80 CNL/Gamma Ray D. S. 3-13 V'" 1/11/81 Collar Log D.S.6-1 ~/' 1/14/81 DDNLL "/",,, 1/14/81 D.S.6-9 1...",..",..," Spinner Log I.-/;f). S . 6-9 1/16/81 DDNLL " /'" "," 1/16/81 D.S.6-13 v' Spinner Log D.S.6-14V' 1/4/81 Spinner Log " D. S. 6-15 0;'/'" 1/10/81 Spinner D. S. 7--12 / 1/11/81 DDNLL L,"'~D.S.9-18 1/19/81 DDNLL D.S.13-3 V-/ 1/15/81 DDNLL /' D.S.14-7 V' 1/12/81 DDNLL \..........]1. S .16-16 1/-2/81 Collar Log/Gyro Corr. t/ D.S.16-16 1/21/81 CNL/Gamma Ray ACB/VDL /'" D.S:16-16 t 1/13/81 ~ase sign and return the ~~~~ched copy as receipt of data. DISTRIBUTION Mary Kellis North Engineering NORTH GEOLOGY R & D DRILLING ENG. MANAGER D & M GEOLOGY' STATE OF ALASKA Transmittal 1153 ARCO Oil and Gas Company is a Oivision of Allan lie Richfield Company ----- .~---- --~ ( Run 2 5" Run 2 5" Passll2 511 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" ~~ ~". \ œr}}..f .d' ',r":' "\ ~ I .. I'\; ..-,. 'I "', ""7"'v. -. ...-¡ ., .. : ":, \ . '~, .". \ ~: ;>.~: \" I ,,~ 0..0 ! .- \ ,~,,:. ':', .,..' ,..,- c' . L\-. \ " ,)L_.. .. \ )'~-'.,v _.- \ ": "~;'.o , ,,7 ~ ,- \ c.." t. T yr.,.... ,:," '. I '--.-. \ dS.T!\~2".\~<;... __0 I .CONFER: ..... ...".____d- FILF: 5" 2" & 5" (on same log) 5" \ EXXON MOBIL ;1. ~,'~R"".E1VED~. 0 GETTY M ~~ PHILLIPS' B 1 0 1981 ' SOH I 0 "Iaska au & Gas Cons. Commission MA RAT H 0 NAftChOrage CHEVRON .: """.-"""_"'.__0'.,.."...,., "......__0.0... ................... ARCU Oil and Gas Company North Alaskr1 District ",r Post Of j~ x 360 Anchorage, Hlaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer ( ~ICÓiJj~ÿ!l~ ~ i). =\, ;o:~~;tj ~~ I I. .J r. I '. I~,' \ ,- I " .-.i\I(::: ,... ._~ ,; ~-~~;,.~~n{}J~,' . ..-" y:....~~ \' ';,,:-- --I r- ;,\".':&~:,.~'.'~\ ¡ I-r--r"'l : , .,-:,.' ._- ~~T ".T FC ! \ Sf/.. T Tí:.C - ,---- 1'- .,.'-' ..-.--- h:~'I\!FEi<; 1 0 5 6 0 - llj 4. 0....-...---13" e sse r I FI f; 8596-9570 " January 14, 1981 Reference: ARCO MAGNETIC TAPES , , D.S.4-11 ,,' D.S.2-1A 12/22/80 12/22/80 Tape IICN/MS Tape IICN ~lO' 12/19/80 Tape IICN 9000-9620 " D.S. 2-14 12/19/80 Tape IICN/MS 8700-9800 " ~ease sign and return the attached copy as receipt of data, l1ôI'j F. Kclli.s North Engineering transmittal 11976 . '> \. DISTRIBUTION NORTH GEOLOGY R & D DRILLING ENG. MANAGER D & M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHGN CHEVRON ",~7 P2'" ,I,' c: ç V' E '"" / ' /' ~,-z. '.f u " c..,., '~~v ," - ...-- ~-" /1.--, ,~','v\'"",,~¿.,./ '/'Ã"tl I;" , ~"""L. ,) 11\1 J 9 il:~ f,\ 1 '. ',' ^ ",:,,'(YI'.", " f \ .\ - :\( ..,' i ;' l J:!:' ,,' " 'I' (' .', ,I" " '¡)fI lT/r3~ìr ¡\ii~!lUIWJU ' On ARCO Oil and Gas Company is a Division 01 AtlanlicRichlieldCompany , '.... , ""_.- .."" ........, ARCO Oil and Gas Company North Alai"'" District Post Otfi, )x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 jerry A. Rochon District Operations Engineer (' côFK- . rnp.I~^ I '..."", ,J\ - ",- \ COM~'k"/(' . '..', Rt; t' roo G " \ 1 tì-,1(} ,,0- ,.~.__\, 2 t~'!~ J~é \ '1 ",~,: ; ... "~--- '. f" 4 :NG ,--- -~ 1 GEO,L ~ -l'2GEO~" ;, . -'I 3 G~ÖL -- " I ST^T TE~,_- . \ STÞ-T T§~- - -',-- - CON FER: FILF: November 13,1980 Reference: ARCO Cased Hole Finals D.S.7-5 9/4/80 Spinner 5" D.S. 3-6 8/17/80 Lifetime log Run 1 5" \ _jf~'-S~~. 9/26/80 NeutTon log Run 3 5" D.S. 7-12 10/24/80 Collar log 5" ~ase sign and return the ~tached coN as receipt of d~a. Mary Kellis HordL Engin~~rJ.ng Tr::¡,nsmi ttal #804 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. " MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON /J '", "2: R E ~ EJ-H 0 , , /"L ,/ /L.",(;[;\ttlé- ï &"'1 " ~".t¿ l.' /' ,/ - , ('/0(:, ¡,I, ("Lt~~ NOV 1 8 1980 Alaska Oil & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Di~ision 01 AtlanlicRichlieldCompany ARGO Oil and G(7 ~ompany AI~si\& Û ' ('" \ .\ilc~~~r,:c:e, /d~lsh:a 3~;5'!O I COMM- -""-r- COMM.-- <I rCOJ\I\II",~ ' -¡-R"Ë-S ; ;".i ~~7 -rl ;:::~,.!l:-:- -1'-2 LNG, --\---3 ~-!'."- ',,: ,\ " --I -4"---""~ t: "."J ,,-' ,.--t)1 \ 1 vi:, ~--- \ -r), r.. <;' ,,"',i' -"" .!- " ¿:"v,' -\- - ') "è ': I~)\ ' ....' ....., ,.... - \ 51l"1 T::: - T T.-,- 1 ~"'!, i'::\.., -r_:~,~,: "--- - ,-,- CONFER: FYlF: f!;;J ~, ø~ ~.;,.r" "..-:' , ":, :.." ,', .; ::)05: ~)¡¡:c'? t3DX :.\30 '7',:::-,:~hC'r~(~ ..107 277 35:37 May 20,1980 Reference: ARCa Cased Hole Logs .........--~ ~ 4/11-12/80 Spinner Run 1 5" D.S.3- 4/11/80 Spinner Run 1 5" D.S. 3-17 4/30/80 CNL Run 1 5" h' 14-8 4/10/80 ACBL/VDL Run 1 5" .~',;..,' , I;": t Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #333 ~ North R & D Drilling Eng. Manager D & M Geology State of Alaska DISTRIBUTION Geology Exxon Mobil Getty Phillips Sohio Marathon Chevron ~,Æ',~ ,~' ~f,~"'/ , 1,;/1 " :,I ^ 4/"')" "ill, ""',,' "-'-','~' f,~" "'0:9.,/;"'A', ,l' . ," ~"'" 1),'" '1""," ".,' ~ -.; 1/ ,~.", ," ":;// '~ l J.(f , " '(" ,Ie" '>I'" '., 1., ,,',,'),;7,,"/;,., "',' , ~:",'h'~,,1 ~, - , /f .',j¡ '~r:,' .- J/'lf/' (,~i,' l..". ..0', ¡" IC/,'," , "~>:" , '4'11' I~:r.. l¡f'(j'J/11. . . 'iJ¡llt%I1' ,1\,;1 CO CII and G,¡s Comp,¡ny IS i1 ùivi$,on at ¡.\tlanlicR¡chti~IJC'Jmpàny Pc:;t Of{¡G~C , 350 ¡""--~"-I"'-'" ,..,.t.... C"ì:-) ~' "1"...., ....\ '--~¡~~". ,,' .)I\'" .J;;;~ OJ To!eph:);.ü 907 ?-n 5(;37 ( :J)c~ /"~,' ~'<'" ..' ,'.í "', ',' ""', , ..;~. ~ -:" """,',': ':' ,.-.-" "'- ,,- ,..' '\, COMM """""""~"','" ", (i7,'~~,,',-:'::": "" /. ,'~ .. \ COM~_~'~<:, ¡:i':" --\"COMM .~" -'--T RES EI\JG- -I' 1 ENG ..-- . -r-2ENG ","-'- \'3 EN:::;..- --r4 ENG .-,--,- I""l GEOL- 1"-2 GEO~,- -T '3 GEOL ----\ST ;\T T~C - I 5T ~~..T~~,- -,--"-- , -.-' ..'-- -----"-1 -CONFER: FILF: "¡';"II",..,,\¡,,11I,\::ld'....',)!¡¡IJdIIY h '.) ì ¡¡! :-\ I i!\) ~ (. d! ~) J U í.1i... C; I ìI ~¡ U I ,} b! G n Nodi-: Jl.LJSka District , December 7, 1979 Reference: Enclosed is a re~trànsmittal of the Gyroscopic Survey fay D.S. 3~lO dated 9/11/79 by SDC~ Please replace the- original with this one. Vnease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Fmgineering : //1 { :::_" '--~'/,-;"/7 ¿~ L----" ~\~'""E'" "". ~" "Ir"'- /1,/¡ \" I ' '.' lJ , .. '.. ~.... //'1. 1 D( G 1 ':? '9~9' "'h,~ () I: ~~'-- ' Alaska Oil & G:IS .w ' , AnChorag;' \JUI' IÍII~~iOI1 , TRAi\fS~,U TT AL # 510 DISTRIBUfrON North Geology Exxon Drilling Mobil Eng. Manager Getty R & D Sohio Geology Marathon State of Alaska ~1illips D & 1\'1 Chevron '--~ '.- J')3 NUr-.lBER: ;-a~LL NAME: f/JCATION: rr'r-VEY' Dì'.>TE. *' -...; .r~, ,1' . Pr'I £"1'-='1 FI C 01) I I I I '-Jr< ~O:;,)ITJR-OT S v~.... J i'. 1 ! . J J -;. ~ \J ..... t ~ 1 -, \. ,_I' 700 ~'lESr.l.1 41ST SI'HCET Gynoo~ODIC Dll~~rmIO~l"T Cunv~y L', ..J V L . ~!..) ....... J. 1". -.I .:J 1. , !J FOR ****************** * ARCa OIL & GAS ~ **************x**y . 3776 DRILLSITE 3-10 PRU DB OE BAY ., -- /, 9-11-79 .-", ~UFVEY ENGINEER: PHIL GPAFFT GYRO REFERENCE BEARING: NOD-ODE ~ETHOD OF CALCULATION: RADIUS OF CURVATURE ***DEPTH MEASURED IN FEET*** CO¡.H>lENT S : ~ :Þ~ ::J ~'., g[;:. c; - .... .' ID ,- '!Os 'if:¡ vô ~ ~ 3 :ñ- ':"1 ,...,. v ::J rrHANK YOU ,)!.. i5) <n £ !;? ********************************* *THIS SURVEY IS CORRECT TO THE * *ßEST OF MY KNOWLEDGE AND IS * *SUPPORTED BY ACTUAL FIELD DATA.* * ,---'----"-., "', , . . * , ,. i",.\ '. , * \,..- ';' .. -.; ¡ J. "~"';_" * ~- .,r. l""'~ - .-. I . .. .,40.00, . ":. - \,. ¡ * ********************** * * COt.1Pi\NY REPRESENTATIVE - * ********************************* -, """-! --c' t-1 r::~ ---~ /C) r~"""'~- , ;; ii , ~ f.-'" é-=--'~ Þ f' .';) "",.J r-r-, - ;~ C"Š? CJ -- -- -~' -- - --,_. -, -- '--- -~--------- --------. _h__. --- --'---'-'--- . ---.- /' // ,. _I ~. , .' ~ / -' .'. J'- r. ' "=""-"'l Ç- Or . r, ~ 1 ~. r Dr-. '." T .OJ'ir' --:. Iv:-.. !"':C! -.j:,< ;-<-r'- r;!1 t ("'- J- ,! I_;,J ,J ~ 'J .J ¡:...~ - t-. ~( r) (J"' é Ct.' i) I C C: , 1[,) \ f ç Y " 1,-' ,-' \.} r . v ~j" -, \I '- ;~t..f)IUS OF CU;,VATURC Í"~ËTHOD OF CO>V:PUTATIOr"~s (.'r.)Yr~UTI~~. Ç'v~D ~nc' R.'V F- . ~ LI~r)~Fv &~ A~~~r.jATF.~ -,,'. I,....-J'" ",~-' .J J . I., "'-,-- I ..........,,"..... r, -,"'" 17 SEP 79 \.:ELl DS 3-10 K B E LEV 3!.¡. FT J r... ç.\ )\.j r. ( -.l 7 -, L ) ....., ,J . ~ V ,J ~.J RECORD OF SURVEY ALL CALCULATIONS PERfORMED BY IBM ELECTRONtC COMPUTER TRUE ¡:EAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D ivi 0 100 200 300 4r\A \,/ >..,' 500 600 700 800 9 r-. "') \)V 1000 1100 1200 1300 1400 1500 lóOO 1700 1800 1900 2000 2100 ,,~200 ;' 300 2/~ GO ~;' - Ú 0 () 0 0 0 0 0 0 0 0 0 '" v 0 0 0 0 0 0 0 0 0 0 0 30 0 0 [) 0 r, v 0 0.00 0 () v 100.00 200.00 3(10' .(",{'¡ -' ...1 v 4 n r1 Or-.. OJ V . \..) 500.00 6 P\ r- .-" f'I f..j.'?í~ v~, '-'.' 0 0 0 0 0 ^ v 700.00 800.00 900.00 1000.00 0 0 0 0 0 0 0 0 1100.00 1200.00 1300.00 1400.00 1500.00 l"~O .-..... oU . Ul..J 1 7 '" " " - vu.tJ\} l"'hÍ!O nn ...- '- ....J v I) V 1900.00 1999.99 2r¡q9 9'9 ~ v" ., 2199..99 1'. V 229ge99 23:)9.99 0 SUB SEA -34,..00 66.00 166.00 266.00 366..00 466.00 566.00 666000 766.00 866.00 966..00 1066.00 1166.00 1266.00 1366.00 1466.00 lS66~OO 1666.00 1 766 0 Cia 1866~OO 1965.99 2065.99 2165.99 2265.99 23(;,5(;99 DRIFT DIREC DEG. N Q@OOE N O.OOE 1, I 0 .- ;'1 {'; i="..' ,i \j 'J- ,.,; O. {ì{\ç:- t.. - ... '<.1,- N O.OOE N " r.",'- , ". ."V"'" , v_v '- N a.aCE N OèCOE N a.ODE N 0.00£ Pt, C... ,.., .Or:: ,~ I. ,,} < . ~ J< I 0 f) .-- r- i~ . \.. Or: N O.OOE N O.OOE N O.OOE N a.OOE N 0.00£ N a.OGE fJ Or>"~' . - 'Jt. " " \.1 "- N a.OOE N69.00E to I C' 0 .-} ,~- 1\ , .' ... t:. \1 0 C~'E. ¡ ~ '0 - U N O.OOE '" () ;", n :::- ¡ '\ ~~.. v \} \b TOTAL COORDINATES 0.00 S 0.00 5 -0.00 S 0.00 5 0 r-í ,,"\ S. .. \;;.¡ c' 0.00 S 0.00 S 0.00 S 0.00.$ 0.00 S 0.00 S 0.00 5 0.00 S 0.00 S 0.00 S 0.00 S 0.00 S 0,,00 S 0.00 S 0..00 S 0.33 N 0.67 N ro. "7 ,. v~ C !.~ 05167 N 0.67 N \.. OGOO \,¿ 0.00 h 0.00 v! f'1. "0 r, l> v . ..f ,... C ("-0- \' c. J.. ".1' - "¡ .4'" .0"1 ì"~ V. v h . (J (-.." ,. . ',J It ,./.; W Û . G 0 ~'Í.. .0" 'n{)-' - ,- . l.!...... v~ 0.00 \1 0 . 0- ,f) \ ,¡ .v .... 0 . 00 \¡j 0.00 Vi 0 . 00 'f; 0 . 0 0 ~>J 0 . 0 0 ~'J 0 . 00 v~ 0 .00 I,'; o.oc \'i 0 . 00 v: 0.23 E 0 . tt 6 E \."\ l~ ('. E ; e ..... 0 çlr6 f 0 1'- t:: ¡ ~ y \,.j ... C LOS U RES DISTANCE A~GlE D pi¡ S 0,,00 $ 0 0 0.00 S 0 0 0..00 so 0 0.00 S 0 0 C ""'0 c: A r~ .v J V V "', 00 SA r. iv.- u~: 0 'if' S On .Uv V ,. "" 0 - 0 (' v.v' ~ ) O~OO S 0 0 0.00 5 0 0 0$00 5 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0.00 S 0 0 0 . l} 1 N 34 30 Ofì~2 N 34 30 0",82 N 34 30 0- r- 2 . I '~t- J.' f' e b - ¡\ :; ~ ::5..J 0.82 N :31; 3(; 0 I'; ¥ < 0 \': 0 ~,¡ 0 \\' 0 \.¡ 0 Vi 0 If! 0 ',-I , ú 0 '(.,I 0 'f! 0 ir; 0 h 0 \'¡ 0 y.j 0 \~ 0 1¡i 0 \\1 0 \.1 ~I 0 <J 0 \¡j 0 E 0 E a [ - r- u ..~ 0 L DOG LEG SEVEr; I TY DEG/1OOFT 0.000 0 ,"¡r,t) .\..1\"';\..1 O.JO-) Or, '" -~. to 'J '.J U o.~)OO 0 . ~; 0 ~) ().~)OO o.coo 0.000 a.GOO 0.000 0.000 0.000 0.000 0.000 D.UOO 0 ') r r} . \.1 ,) "- O.CjOO 0.')00 0.000 0.500 0&500 Oø~)O() 0 . c) 00 0.::;00 ~, SEC TIC' . DI-T~.'- - :::, J-\ ¡\; \ o"'oc o"o~ a.DC oooe O.CJC 0 r.~- . \.} '.: 050:. C It 0' (:~()(; 0 ,.."-,, .VU O. r',;-' \..- '.- O. DC 0 . O~\ O. O. C-c- Or-. . \) '- O.OC 0 . 0": a.co 0.00 O"ITJ 0 --, 6 t: C' 0.0; 0..2.(; (! . E: C ¡\~;CO >~DS' 3-10 GYROSCOPIC SURVEY r"'--("'-'I"'-'" -'"'F '""lJ~-'\!""Y ",-1-- \-"/l", t: '--,,->(, -,' .,....._,"~/"'" ~ '-~I-+ 17 SEP 7) ALL (^LCULATIO~S PERFOR~ED BY IBM ELECTRONIC (O~PU1ER " TRUE P¡"t:" D~~IrT \/,-r-.TIC"t :J-\ ..:.") . ,¡ . r t: ¡, 1\ , '~'~-<---J ... -'r'"L'- - Oc'p- -fH L; t:.. P I r! th'l'.,J;: ,4 i D "'-^(' 1 0 ~ ~}....i...! 2600 0 it 5 2700 0 0 -2800 0 0 ,..." r. ,-, r) 1 0 ¿';,lV, 3000 0 30 3100 1 0 3200 1 15 3300 1 0 3/..00 0 0 .. - T\ r. 1 1 r- .5 :'Hj t; - :; ...-., :; C: () 0 1) -" "'. ~f . .. 3700 3 15 380:) 7 0 390J 8 0 ,æ 'u' '-. ., ,..- 0 4?1 vv Ö 4100 '10 30 4200 1330 #. ." ~', ",< 1 t 1 ç, ~ -' v V ,) ."If <4"'00 20 0 4500 23 0 1,,6('0 28 15 4700 32 0 L p, ('I (, _3 1 .., ..-} tu-.Jv ~ ' J"-' d. q 'ì ;", "';\ A ~ . \, '.J ... ~ it; n Of) "), 7 ~ f", ~J) "" -'-' ~lCr. ?,~' 15 _i~. r '.! -' ~5 :;:;, ~) ,-. :', "¡ ~~ 0 .' .. -,} ..,J ." L ,. ? 3 Ü n ";:' c. . Q'.'7 :'.1 ,-. 2499..99 2599.98 2699.97 2799.97 2899.97 2999.96 ?'(¡û9...cc:.. ....",J ....1/ 3199.93 3299.91 3 '") c '"' r' 1 :;¡j':l.'" 3499.90 3t:;9C1 PQ ".J ,0'-1" 3699.84 ? 7(' Q 4 ¿'- .... ;1..0 , 389éJ.5ó 0 3997.59 4096.28 4194.08 4290.72 4385.75 4478.78 4568.91 l~655.39 4740 . it 2 [. ~\ 2 ") . r.) Ú r~ C. ~ - 'i-901.61 t...9P,':O..."',S:. . -' ..... -' 50~)9(;21 0 5 1 :3 7 " '-t 7 sue Sr::' t" .... ' , 2465.99 2565.98 £:665.97 27{;5.97 2' .~ .. 5 {} 7 bQ ." 2965.96 3065.9:) 3165.93 3265e91 ~ -;, 0.. :>r (' 1 .,.;,.1 1;>:;1 3465.90 3565.89 ~6f-.F...P.L ...,. V-'W~- 3765,42 3 SóL~. 56 3963.,59 4062.28 ¿f160.08 lt256v12 4351.75 444l..78 ¿,C','~4 Ql . J... .... ~, 6 '-, 1 .' 0 ~ ',¿ . .,j -' '7""" 102 .., vO.'-, 478[;.54 4867~61 4946055 £'- r¡ ') c: - 1 -' '" L ~) ~ ¿ 5103i:t+7 (J~{IFT DIHEC DEG. S86.00E Nû3.00E N O.OOE "'I 0 0;-",'-:: " .' ",,' ... S ,°, ('0 r. (-. r- :> "", . U j~' V ",...L S "'- 4 r- r, r- j 'oJvt: S' ,...., ,- r- _9.vvL:. c- "'... f"t ..., f:" ";':>LIiVV,- S19.00E N OeOOE C, '11.-, 0 0 G iN ""- .. "! ^" -, -- f~- ,'" V-V\;-:' N23.00l\' N' ¿Po (-.... ;"\ ""1' , , J A L~ ¡ ¡ y . ',- ~ - ". .. N 2.00Þ¡ " '1 " r ,." ,'( 0 . v 0 ~ N2-3. DOE N26.00E N28.00E N27.00E N27.00E N33.00E N23.00E "-'1 nrr I ~ " 4& l..' v c N28.00E """0 ,,('- I'~'" e V Ù t. N3Ô.COE ..., 7 "" ( ... "!.<; ' '~ f~.,; Ov.J>-. N37e:OO[' TOTAL COORDl~ATES 1 ""r, "', .¡;'v N 1.24 N 1.69 N 1 L r- ~, . "'..) -;} l'i 1.91 N 0 Kh ~,¡ e",./ p¡ 011'315 2,,09 5 -. n.~ r- ~~\JO .:; :¡¡;76 S 3.52 S 3028 S 0 ':"") .- 1.~(. ~ 7.78 N "..... 51 .' LV. ~ Pi '"' 4 .;¡ --, r I ~ . . oJ ";) ." 49.77 N 6e.69 N 91.56 N 119.15 N 1 c; 1 ¡:¡ 0 "t -,"'" tt 1 P {) '"I 2 ~! v,aL - :1 233.47 N 280~32 N 329.90 N 383044 N 4341191 N 4840.53 N 534.25 N 1.03 E 2.55 E 2.95 E 2.95 E ...., 5 f' r ;). "J C 4.35 E 4.93 E 5.76 E 6 fi 0 E, f;. ;,< 7.19 E 6 l"\ E~ .. +~, 5963 E ç: 1", 6 ,", ;"I 0 '.., 1-. 1.79 E 0.68 \,: 0 ",P E .,,'" 4.84 E 13.46 E 25.11 E 39.47 E 56.11 E 77.71 E lvl f2li, E 125.11 E 153.16 E 1B2.84 E 216.26 [ 252Ci99 E 290 Ill..? E C LOS U RES DISTANCE ANGLE D rt¡ S 1.53 N 40 34 ~4 E >, ¡- 4 .. 1', 4 0 ,..... r- L. J f.~)' ..¡..j c 3.40 N 60 9 13 E 3640 N 60 9 13 E 4.06 N 6155 15 E 4.43 N 78 54 30 [ 4094 S &6 21 12 t 6.13 S 70 '3 52 t 7.64 S 59 36 ¿j E 8.12 S 62 22 44 E 7.31 S 611151 [ 6.52 S 59 4333 E ~.l~O S ~4 ~ ~p ~ ~ J V ~ ~v ~ 7.98 N 12 59 57 E 20.55 N 1 ~4 24 W I' 4 l..... r . 0 Z- r. " ", L- ~ ,..:.tv \ ' ô:; ~/ L 50.01 N 5 33 14 E 69.99 N 11 5 11 E 94.94 N 15 20 15 E 125.52 N 18 19 48 E 161.84 N 20 17 10 E 204.56 N 22 19 43 E 254.48 N 23 26 37 E 306.97 N 24 3 9 E 363.72 N 24 54 15 E 4 ~, b. ):¡ (\ '\ I 2 r- ¿- 0 " ,""" r. ¿,.vv h :J ~,jð ¡.. 4 f' ... 7 1 t 2 L, ") Y ~,~ t- , ,) ?. - I'i -- v r. b ¿ ~') l.. ~46.60 N 27 34 12 [ rC" Ie t' r,' --1 ~.- {- ,) ¡b~ ...1 f\ 2¿ j ~/ c DOG LEG SeVeRITY DEe/100FT 1.000 0.250 0.750 0.000 1.001 0.500 0..500 0..250 OG¿50 1.000 1 ¿- t".'J (¡ '"J t-. 1.25~) 3.2~1 3$75tJ 1.U:>9 1.667 2.531 3.004 2.754 3.752 3.000 5.419 4e655 2.2£,1 6 ~ 09 - .:.> :;.> 0..894 2 . it 1 9 0 ~ it 5l~ leoOOO Sr-CT 1 ~" L d:'; r. I {: T f, ',; (- F v -.) ,"1 '. ..- 1. ~.l ¿'", . 1 .. , - ,---, ...1-' " 2. 7 ~ 2.72 '..., 1 r .J. ,) 2~49 1 I) (¡ 5 0 . J {} ('" '-, t -'.J.7L) -0.63 -Oo7/!. -0.80 1 . c-, r, "."..... 7.8(; 113.61 31.14 47.67 óH.4:) ,~ 9't.Oi 125.07 161.63 204.54 2 :; (~ 0 4 B 30(,.9£+ 363.:>5 424e45 4E:it'~91 ~ Ii- Î-t 0 ç ß 60:) . l~ ;~ ,:" '"; (' i)' Lt) <:)' ~1-'1 n.' " - - '0 - 'V r 'Y' ",,' c ,", n 11'- c.-" ", \1 ,= Y ,', S",'i),..]> I¡U ,'" ).Ii"~ r' ~ ,,-,~,_'-.', .... ." -, -,'rr-¡i"" "-"r C!>-~"I"'Y' L~,\_...¡,-"v v' .J,,:,VL 1 ~I ('" r p ~l c ..... h ' .I III C'Lr~l'L"T~"'<"" ....f.".,....¡,~.",.."r- E"" I r-", ""t-C-F""""C C""r~"T-"-' ,,) ",. ,>;;,,:~), L.) ,<'f" j--c',~~,' ~.r h" "r .' ¡'-. I '¡ ~'f l';',,;..JU "j'" . - ",,"-"" ,,"""'.~ '." ~¿..>,.....J", ,J s,.. -"" ',""'¡....l> , '", L,,' Tour: " f- '~~!' S r-.Qlr-r V....r"'r..r^L ,r t. A, . u: ,r t.;->. 1 ....... P> ' DePTH þ,NGLf DEPTH D £: L r;' A '.:¡ ["j J" _'7 5'- r, () ~ (') -' v v -,:J t:." 1" 1 .." Q 1 r. ~ C \..' C ~ :.) :J 5-700 if a () 5QOO 4115 saoo 45 6000 42 0 ,.. 1 ") ,. 3 r. 4 r {) . l- ,)'i ? L 2 C, ('\ '2 {.. o, u - ~l -' ',,' S. ? :-', ~D ~~ -, 0 ,,)2-.1' - J 6ltOO 30 0 6500 29 0 6600 29 0 ~7'-"'--' .,r.. 15 v U I.j L..::; 6800 28 0 6900 27 0 7 () r. ,'"' .',... " "\ v V '- b ;> \., 7100 24 15 7200 23 0 7300 2130 7400 20 0 7500 17 30 7 Ú 0 0 1!{ 0 7700 12 0 7800 11 15 7900 11 15 ~' .... ,. {- 1 (ò "(' .~; . i. J' ,J -'\" . :,1 .....1 v ,~ ' -' " fi, 1 (; (} '-) }'~?OC B !d t', 0 5215.19 r;;29~ 9~' J ¿. L 5371.,03 0 0 Slyl.6 . (;O 5524450 5 5 9 7 . I:, 7 ... " 7.. r'\ :JO UoJv 5 7l" 5 ,. 61 t:. ~ 2 4' . t:.. 'J, ..- ~ ' J <' !:. C, -, ~..... ~, J7 lLJ It ~ :) ~99" lq J £..'. ~ , "'" 7 " 2 "'. . OV ';ìe ¿ 6166.68 6254.46 6342.65 6431.35 tr:""'O' L,P- v~¿ . "':;> 6611.0D 6702.61 6795.16 68H8.68 6983.36 7079,,59 7117t;O2 7274.97 7373.0~) 7 L-( 7 1 " 2. :1 .... ¡~; 7569"Hl 766nt.71 fì ..... SUB SEA 5181.19 5258.90 5337.03 ~lt14.60 5490.50 5563.47 :J636 e 00 5711.61 DRIFT r\Ic¡:-,C lJ " '-. Dr-r "\k t'J . N31eOOE N32.00E N34.0CE N35.00E ~: '). ~, r.. ~' ,.. I'iJ'TeVUt:.. N33~OOE ""?7 ,,~t'.. ì\J 0 Vvc. N35.aO[ ì":-. -{ q n .. ç', ? 1,\; '} 4. " (} n r: ~ .v,,-'-' ,¡L -""~ ~P7/.q1 '\;23, .no;-; .,I .... -,' , ¥ , v.... !",o !';' ~ . 1 Q t-J 1 r) .. r. v'~ r: ø -; ,1 ,-, ./ . . ,......' ... 60L~5.22 N S.OGL 6132.6f. 6220.46 6308,,65 6397$35 6486.65 6577.00 66""" "1 . vC ~ (1 6761.1ó 68 5 L} . 68 6949.36 70'+5.59 71'~ ¡")', , ' l~.J . \n::: 72£¡0097 7339.05 7437~2~) 7 :::,"\ :~.. ~. ;:, 1 ... -' ./ .. .., 7(-,').4 e 7J .. ""' f, i 8" Or. r" '" '&' \..'L: r.1 B r. n :;:: ,11 ,.",vi... . 1 - ,..... -- 'J ¿ fi Í,JUt N1Z.OOE NIl.OOE ;\ f 1 '" h ,- I, ,S.uvt:. NIO.OOE N 9.00E N 9.00E ~, 5 "'\ Or- Ii 'V 1[. N. 2 ~('\i= . - «I U ....'.., N 2.00C N 4t'ODE r..¡ 9-f)!¡r:. I', ... ~ .... ,-.. N 5.00r N 0000::-: r~ 1 7 ~ () 0 :- TOTAL COORDINATES ~ 586.40 N 64(;606 N 692 "it-O N 744.41 N 70 Ö!' .. í"1 t'.. ~,! Jf . .., v I" 855.06 N 911.42 N 964.36 N ~ "17 10. ".1 .v . ,', 1069.64 N 1119.63 N 11~r--J" .. oee¿.Q r" 12 1 6 . 2 7 r',~ 1263~71 N 1310.12 N 1355.29 N 1399.39 N 14/t 1 . 14 N 1480.25 N 1517.59 N 1 t: .. <"} . c.. C'.' ,,~ :.J'..,J t: ~ ..., " j ... 158£¡-048 N 1611.57 N 16?h Oh. ~i .J...... " "" ¡-., 165lto17 N 1673.55 ì\ lí.C')-'-¡ " ....) -- L 0 ¿ (\ 1709~13 N 1"17 -~ 7 ¡.;. r,' , -' 0; ¿ " 325.62 E 'Jçj:t ~l r' ..;:;)..,.::J C 392.50 E 428.2(... E 465.12 E 502.84 E ~b¿'-A'"l"l c -.. ...... L. r:: ~,~ _'-7 r' J b ¡j c t:. 61f1,QS t- VII.. - ~- .~ ,~ r" r- O,j.1jJ.).;) t:. 648 fi 3f¡. E 6~6.04 [ 6ó2.79 E 669. '+6 E 677.6/4 [ 687.24 E £.or _2 r- ù/o.l t: 705.85 E 11't.52 E 720.77 E 726.31 E 730 .., '" r: , .¿:t Co .'131 pO F I . ..." .... 732.67 E 7"'":ì 7" F j .;J iI .:) ~" 735.94 E 7 "'¡ r¡ '? '^ ~ -} (} . (;_.J '- -, ~,,"' r\ 7 ¡:' ;) () {' 'j :.... 7[¡.1,,15 E CLCìSURE S DISTANCE ANGLE D (/¡ {.' ~ 670.14 N 29 2 36 [ 133.62 N 29 1514 E 7~~ 02 1\1 2.° ?~. Çl F <j -' . ... - \! ,J' ;J <-.:;> - 858e80 N 29 54 39 E 923.11 N 30 14 2 f 991.95 N 30 21 32 L lO&ü.~7 N 30 45 12 E 1125.74 N 31 3 26 E 1167.01 N 30 5538 [ . .~ I', ~ ~', .. ~., . 3 j>o 1 t' [' '>j""J¡..;".-t"" )' .l. '"- "'T oJ . - u ¡ i -' .... ..) , . 1293.80 N 30 4 25 E 133ge86 N 29 19 0 E 1~~~.,~ ,~ I~ 28. ~~ 1~ t~ - ~ '-' r ..... t' ~ \. -" ... .-J '. 1430.08 N 27 54 45 E 1415.00 ~ 27 20 58 L 1519.56 N 26 53 19 [ 1563.02 N 26 27 3 E 1604.72 N 26 S 42 E 1643.68 N 25 460 E 1680.06 N 25 24 18 £ 1114.08 N 25 4 14 E 1744.66 N 24 44 36 E 1 7 t, (J "', R 1\1 2 I 2 t';. -:.t Or-' ;.);.1.';11, I.. .¡. ....~. ~ 1790.79 N 24 9 1 E 1809.60' N 23 5513 E 1828921 N 23 44 Ih E 1 r', l t .> 9 :\, -, 3 ~ 4 7 [- {} +o.<~ ¡..; L.,; : lab? ~~ ~ ~~ ~~ ~'.J C '-' --.Lj I, ~~~ c.¿ ;.I-' ~ 1.-'7' _c." "~'~.:.l 1" r:-7 r- b U.~3 N ¿~ ~ ~ L DOC; LEG SEVê.F< 1 TY DEG/IOUFT 3.775 0.629 1 :: Of') .... . v (", 1.7ge 1.323 3.78.3 :3 . 't 91" 2t':~94 5.:::,39 '... (. \ 1 '-- - e ,.I .J 40423 111105 0.000 O.7~)O 0.916 1 ,.. 0 O. . Li . 0.538 2.3/t9 1 . if 6 5 ¡.SOt.) 1.500 2.526 3.504 2 r ',r .OLd O.75l~ 0.975 0.76? 1 t.~ Or:: ......' '..J loO~:; seCT lor.; D I c. T ,'~ 1\; C ç.' '-' .: - ~. 667 ó 'lJ) 7-'q.47- t'. , '" ' 1op 0 ..- .... . .' . 8 5 2 . 6 :;, 916~6í 9újl)9C lO51...2~ 1115.0:; 1 1 _7 ,- n" J. ::> (¡ 'i (.¡ 1') '~'1 :;: ,', ('~.)L CO:;:: 12E::L~.3a 1 -¿ ':""" 1? j -' ¿ 11 :- 1 ~. _7 .-, c 1 :; Cs) l/i2b.1C) 1471~(J5 1:>16..35 1 5{) ( .. to} :3 lbO2c60~ 1641.9' 167b.7-, 1713.12 1743.99 1_,." (;1 b'lc:;~ 1 7 iJ (\ . !) :-' "toJ -~, l¡'v'ÎO.[.~ .... " r -' 1 u ,- '; 1-¡ \:' I. t' C t-. ldt,6o24 1 ,~ t, -.. ... 0 ~) t,1 ',' L. "', '" 1 p ~ r, ,~';, ..../L:t!-'-, :\F< n L~S' 7;-'} 0 rY-~-;('Jr-rr)f) I f- Cllf)\U,"V V ,,'-,"..1'\.,;';( '-..' ...:J¡,V,,--t ( R r.,' ,. "t D :-, {', rj~ r', 1 ¡r~, V .~ Y ....~t_\~!.,:j 'I.' ,;J.....,-.o.., 1 7 c' (,' 1=', -, q , .,J '-" 0 "'LI ('LCltL"Tlr"'r t"r-c.,'-,"')""" 'y ¡' -, ., Etr~r"rrn~'I~ (r""J-'-u r\ '-, h ' ; ¡-.. , \..í ;'~.:;J r' L Po 1- (,) !"'\~, L) [j ð ;vi " '1:. ..... ~.~ v ;-,~ C ' .)JdJ C t !: J\ Tr" I ¡,- ./ ,0' ", ~ '- ~"~r A <:. On I f~T vt~p T 1 Ct:' L "- "",$., ." -'" ,\ -.C-" f) _, '1 A.,' r- I' r r' ~- P' T L' t..-,..-:r "~I ".u...c jL n 8300 B40G -, t.. "', r. bJ,V\.i 8600 °, 7 n -!,-, '-' 1,.." J 8800 H9JG 9(h')O Ql"'p . v ,j 0 ., r. ,', './(;, V...l 9300 9/+ 'J 0 9500 96(:0 '" 7 r. ,-\ '-j V \..1 {) 7 '-, ;'\ '7 Öv D 6 30 ~ 0 5 0 l~ 30 4. :3 230 ? ?() <" ",,' ,." 1 45 1 ?A -¡ './ 0 - Ü 0 30 0 0 r} 0' IJ 0 0 ~4 0 7767.90 7 ,-, r 7' 4 ""'I doe 'J 70(7 r¡") ",:.'1 .'.., t:.. 8066.67 8166 . it 0 8""6 :;1 ¿e) fJ~, 8366èlO 6466 $ O~) 8565e93 ú t. 6 5 G (\ Vv' fvY 0 0 "'7"t;,~;~ 0 "'-" ..... . '.' ("I (I r-. r 6 "'" ,-" H,' ,'" ,~'.. ',-,.< ,-..J ", '" '",,-, 8965.88 On{~5 c L5 .. .- ." ol".:,~ Q,D .I \,.. or' «I '.; '" 92lt-5.88 SOTTOri HOLE CLOSURE !' SUB c::. r' t ...,.....-\ 7 7 7',.! 0 r, ..J..J.jV 7 P, ~ ,.. i, f-- 053.40.) 7933.02 K<ì3? '<7 ". í., .~)t D P. 1 ?,? " Ie¡. C'-¡ ~.' .;' c' , r," ') v, c-. ") 1 Cr-:::C:." ß332"lO 84,32 fi 00 g:::.;l~q'2 ~..-- .,~ r:631.F,i.; ~ -... - '- .. Ü731~ßg }.i8~1 f('. ..~' -' . ",. <'" '-, 0') 1 (' ,e) t: ,".) 41...., (:; C C "", ] ., f'} i ,..., . Y',~, " -". v....' Q ~ ..., 1 r, Q .i J. ';" - C ',":> 9211.88 DRIFT [)Ip,:.-,( " ' ,1.-- DÇr.,.... ---" ... N14.00E t~13. DOE a.II£. (',i'lC " 0."'-""'<- N16.00C t..' 1 c... f).V' r": .-."",~ - , J~. n ")r~ N&.öç...,..v..... N48.0UE t~4 C » OuE N27.00E N18s0CE N O.OOL: N O.OOE. N SoOOE N a.ooc N OoDGE !',; 0'. n n P- I.. v-..- 1'O'T^L cr-J~Drl.)I~^TÇC 1"\ ' - \.,. '... I:':" ,",-,,1 1735.91 N 1745.65 N 1754.0B N 1762~O4 N 1769.11 N 17 7 ¡ -, ,~, ., , ,+ - ',.¡ í '>i 1778.'+7 N 1781.60 N 1-18' 6"" to, , ~ ~ ' ';i I'of 1787..30 N 17 e d . 59 ;\ 17 ;..", r{ 0 ~. C', f-,~ , '-' U , ... ~ ,,- 17Ü9~O3 (oJ 't 7'~ h 4f.. ", J. tJ ':J e '0 1-'; 1789,,46 N 1789.46 N 1°4/ "'\£: Fi?E- A- q 2~ i\). ~ ;J (- I I f~ " ~ .9 19 E 74b,..52 E 7L}!:, . 86 E 749.04 E 7 r. 1- 01 '-. r' :> '",(".. t:. -'53o5~; E 755.98 E 7~t) .92 E 761.95 E 763.99 E 765.08 E 765~2H E 765.28 E 7 ~. ï, ":i to"') t: v '" ~ -' '" 0.,., 7 .... ".." ," 6. ""', ' r"", P, '_.....~ \- 7~Ç, ..._-~ F b...; e ~"'J ¿, .~ 765.32 E CLOC'U"(' (;. , v I'\. , '-' r', I S 1, " ~,' j- ~:: A ~ " r: L ;:: v r\;'¡-""", ' 1'1...." 'eo D M 1888.63 N 23 12 51 E 1898011 N 23 9 47 E 1907.32N 23 7 25 E 1915ò54 N 23 5 3S £ 19~~ o~ N 2~ 4 17 t~ ¿ ...Le.rL.\.... - l' Ç> ') (\ r 1 \! 2"¡ lJ. 2 ¿" F '/£'-.'JfI-J I. ,~). .... 1 C; 3 ".;: (. 0', ~,,; ':J 'l, 6 ~~" 't' .. .:J . 'J ~j I .. ~ :) ...:> t:. 19 '~ '" ., 0 1-..j 2-' 0 1 r' (', J .. ' I "(. :J ;¡ ";j r 1941.3lt N 2310 29 L 1944.17 N 2310 26 E 1945t44 N 23 9 ~2 E lO~~Ab£ ~ 23 0 ~2 C _-:7r.......',-. " J1 oi.- ~" 1945.£4 N 23 9 36 E 1 r. I' ~,~ f.! ') - c' In E '7 "t {) .. ¿:) ", L j ;r '/- 1946.25 N 23 9 19 l 1946Q25 N 23 9 19 [ 5 DOG l. £:/.J r r V c í~ I T Y ':'>... t... ,,\ DEG/IOUFT 1.500 1.50J ü.261 00500 00500 14000 n f"., q 1 ve.-",-- o. ::H+9 0.750 O.2~¡O l' ;.".pp , . -' 'J """ 0 .~ r- '-1 " 'J tj \.r 0$500 O.~)()O O.ÜOO 0 .." ~ . lJ 1.1 U SfCTIO,'i ["',I'~l"\~J(¡" ,,1 -,,) ¡..,., '- 1,,-, '. '~ ,'" >-í ;-. [" ... ~'. /, '- 'J 'J .. ... ,.' 1 0 C" c 7'~ t-' ., V ~ 1..-. '17 ' "i '-' .. 1 (¡ 1 c... t,; L: , ~:;... 19 'j~. (1 1 , (... t:, C .... .L. 1,-,') (I , n 1 '7 '- :7 EI ....' ... 1 r'. ',.;:¿ r. " -:/ .) -" . (; ..:;: 1937,.70 1 9 '-;.1 co :' ¿~ 1 ~){-'r L; . 1 7 l"I.'.,~ [.1. '.I T;.J" "f~' 1 (' I. ,. l} ,,' .'r ::;; ~ ,';' 194? j¡f ~> 1"..., f /' " ¡ 'j ,..¡. c. ~ '- -- 1,' ,I:. ') r ;) it 0 . (- ..J 19(+6.2:, ~, þ,Î<C (ì ,CC()c N þ}:; E £: ('- " , ,< ) -, ~-.., -J .' - ..... " .,-; Gì;f::,r'C('(ìPIC ~ur')\Jçv - -,....J v '-"" . '-" ¡" v L. , INTERPOLATED TRUE VERTIC^L DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS lOP SÞ,D BASE SAD ~../ ~ A r tu R- [...- fj , .... ~J ¡ ,- f.,.. DCPTH 9165 9660 ToU' '"- (', t. V t:' >:{ T I C I~ 1 l.-,'. -, » DEPTH 8650.90 9125.88 TOTAL 1786f!93 N 1789.46 N . COORDINATES 761f.95 E 765,,32 E .. ~._- - , C L C SUR E DISTANCE AhGL[ 1943.78 ,1946.25 D ~~ PI C ....' N 23 10 29 E ,.,~ 2-1 Q 1 r¡ ~ ; 'i -' ,; '7 ~ 1 7 S L P ~( '-) SU~3 SLt\ r-; .: 1 ( "', 0 l) I..: \j .. '".í 9091e83 ,-.. ~ . "'-' Ar"'c~'-' 'r-..r- ':!. 10 J4 ! '....J. LJ ::;¡ -.J - . GyDr)~scn~IC CtUD\:~V I ¡ \, ..., ...' r ...} I', V ,~ t il/EASURED nEJ)TH Ai',JD OTHEH Dþ, Tf\ FOf-{ EVERY EVEN lCO FEET OF SUb SEA DEPTH" tf:EASUR E D DEPTH 13lf 23/(- 334 434 5---" #1 t 634 7'2 /, ~ -y 83/ý 03" ;; ~ 1034 1134 1234 133/+ lit 3 4 1534 'j 163l}' 1734 1834 1934 2034 2134 223/+ 2334 2434 2534 2~.r;.b - \,., j . 2734 283t't 2934- 3034 313[1; 3 ;! 3 If J33l¡. 3l~ 3 !-,;- 3 5 3 /;- r'Oj t~, :, V t-~ VERTICAL SUB MD-TVD n~PTu r-r:A' DIcF~Qr:-rc¡cç ""~L. r¡ v'- ~ r """'<'-"0' L- 134e 23ft. 334. 434. 534. 6 3lt. 734. B34. 934. 1-""-4 ;Jj Iâ 1134. 1234. 1334. 143(+. 1534. 1634. 1734- 1834. 1934. 203ft. 2134. 2234. 2334. 2434. 2534. 2634. 2734. 28344 293f,. 3034& 313[1'" 3 231~ it 33)t~è 3 4 ?J+ eo :3 ~) 3!~ if 100 200 300 400 500 600 700 800 900 1000 1100 120G 1":-" ,;¡i.)v It} 00 ' 1500 lEf'.(; "..J ,/ 1700 IPoO v\J 1900 2000 2100 2200 2300 2L;00 2500 2600 2700 2800 29CO 3 t¡n i""\ v,-_...j 31GO 3200 3300 3 iy 0('1 ? (::¡i~jri .J -" v''.' 0 0 c 0 0 0 n '\.i" () v 0 0 0 0 0 0 0 0 0 0 0 ' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C VERTICAL C C'd.? p ç; c T I () rd ~. . -. .. ". 1- ~ ... . ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 û 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C () n \J 0 1 7 S [y 7 9 T OJ f\L C C'-; n r;; [) I ¡~, I f'\ l' E, ", ~ - "," r, .. 'J 0000 S O.OD S 0.00 5 0.00 S 0.00 S 0.00 S 0.00 S 0.00 S 0.00 S 0' r""" (, , .VIJ .... 0.00 S 0.00 S 0.00 S 0.00 S 0.00 S V.-~ 0' {"¡, c, . v .... 0.00 S 0.00 S 0.04 N 0.47 N 0.67 N 0.67 N 0.67 N 0.77 N 1.15 N 1 "'7 ". . .5 l'i 1.69 N 1 7r> ~I . ç, 1\ lCi4f! N 0 . 5 5 r~ 0...89 S '" 71 ~ c", #, J I.'rG 19 5 3065 S 3.S3 S 0.00 \~ 0 """0- . ,~ ~ V '1; 0 . 0 0 ~: 0 . 0 0 ~~ 0 nr¡ i.1 .v..- .1 0.00 h 0.00 ~,¡ 0 On .. ~ It V W 0.00 ~j 0.00 ~'1 .-" / û ~ 00 \.t,J 0 . 0 0 \~ 0 " " '. . tv} V Ii'! 0 . 0 0 ',; 0 "'¡"I !,j fI .... '.I .. 0.00 f} 0.00 vi 0 '" r¡ () I.' .. '..-.... ~. 0.01 E 0 h~ F . -"-.... -- 0.46 E 0.46 r:: O./~,6 E ,'" ",', [ V e q ';1' 1.60 (: 2.(19 E 2.95 E --~ O) (} '"\ C L. .. ,. ';i I- 3.91 E /.J. ' c:. '..; C .8;.1,... L ?$15 [ Ór;ll F (,t;':i) f 7 --, f, ;:~ . c: ,.,. ,-, r: , . ,.., r- :; ." ~.: L ¡ ¡; F-r ,-. ¡--d'; '... CJ r', :.~ ";¡.', ..... In '-'......¿ .., r: Y c) I'; (~C n T) 1 r- c tJ' D \/ ç Y \J I"V~,-vt \...~. ""'" ~CASU~E) DEPTH AND OTH¿R DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH~ ~/ r: f) r...' J ':) ~: r. , '- ,., ,-, ,- '. '- V Tf'H.ìE V~"~-I-tL ,..,'r, ¡" ¡.., I I. "'"} I,."; -> . , '-.. - ,-....' ~¡D-~TVD VERTICAL CORRECTION TOTÞ,L COOf{DINATES ~', r-' D T LJ V'-' ¡ I DEPTH S-I\ "'I.........r'-'E""""'~- ~ '... .. ........ <. ,~' -,',-' ... ~I ...-,,1-.,,""'1-. :3634 <:S6'":£4 3600 0 0 - ..J, õí 3734 37340 "J.7nn 0 0 -" -'" ~ ~P3~' 3834. 3800 0 0 - \.; ..J ,-. 9 ,.. '" 3934. 3900 "" 2 :) .::' () ¿ 4n?7 4034. 4000 2 0 ,- J 4138' 4134. 4100 4 2 4241 423{-f~ L~200 7 3 431:, 5 L~ 334 f! 4300 11 4 it it 52 li434. 4400 17 6 if 56 1 45348 it 500 26 9 4675 463 It. 4600 LtO 1'+ 47:::':') 4734. 4700 58 18 .!' ,,> '~91 4- 4834. 4800 gO 22 50~1 4934. 4900, 1 ^t 26 vo 51[:8 5C3f}o t'jíi'10 134 ,28 ~ ".' v ' 52~-J 5 t; 1 ~ I'" r'lnr¡ 161 27 - - 'T J \..' L. 5424 5234. 5200 Ion 29 " ." 5:,53 :;, 3 3lf-., 5300 219 29 5631 5434. 5400 2"" 27 _TO 5613 ~ 5 -" 4 5500 278 32 :J -' . 5951 5634. 5600 317 ~C .,. ;t 60B5 5734. 5700 351 34 6212 5834. 5800 378 27 (:,...,'" Þ) 5934. Ç,90f} 3G8 20 ~ ::; ~ <-., ;J <-/ ':r' 644e 6034. 6000 It14 16 6J)t:'.: 613ft. é" r. 0 it 29 15 . ..J J ') .l. \.... I. I"- ,e,7"7 6"~4 6?on l¡ {. '2 14- v.~ , f-.?$ -- ,j V rJ 6790 6334e £. 'H'¡O 456 13 ~ -' oJ 6903 6/+ 34. ,6it GO 4(;9 13 7015 6:)34c. 6500 ItSl 12 712:: 6' .., t. f. ( "r. 491 1.0 - ..-l, 0 .' -,- ò ... '-,.)\-;\J 7 ;: 7) L} 6 7 ?:- I; \< 6700 500 0 -' 7 --:-'1.. 'j , 8/-.' } (,or¡ [\ 50E r- 0- k b ' :..ì~; ¡¡ '..-' '..' ',' '>' (¡¡.Le 6 ~) :5 l~ co fJ90C 514 r r;) -¡ :;; j :; ., r, ", I 7000 ~~l('¡ 5 U.:).~~ -' ..." 2.95 S 1.60 N 11.94 N 25.52 N 39.68 N S6.46 N 71.61 N I"'.... ")7 to ~):J . ~ ,'" 1 ? ~.~, 4' f... r ' .... ",". "" 'i 174-.04 N 221\\:)8 N ..... 7 f, 7 ~," ~ ..:.. L ¡>,J -; 'À-¡ LC' r-: _J .,:1 d li-O4.B6 f~ l.J. {.., 0 7h t,; . vu. . I" 531.74 N 599.33 N 667.91 N 734042 N 805.21 N 83Lt.54 N 9 5(, . ill N 1023.95 N 1085.75 N 1143.12 N 1198.32 N 12t;.'-' .-JC }, -' L.. , ~,' /\1 1305.52 N l'2t-., ,.,-. /,1 ..;.J~.cnJ ," 1405.87 N J¿.r:)l.~') \1 . r... -.' ~ ¡. l'~93c21 .\¡ ) ¡;:. ., ~ - ,- ;,' - _\ ..) t. . (~ ;--) ; '. 1 ç .' .'. ,.." " , t') ..' .... ..t,...1 ,",,' ,.,. ',j .. .... " . 1 :>': 9:--:; ::; 1 -,' . -"- ~ - " If SE::P 7') 5.65 E 4 lr. ,... e ç. C 0.53 E 0 . 6 7 (j 1 . 4l. E -(.76 E 17...no r: ... "" - 1.., 31.27 E 47.18 E 6ee3S E 95e83 E 1-'2 ('9 ç ¿ ,.. " .... 157.;~2 [ 195.83 f 241cl~, E .-..~, .... .~ "- t- C. r L ç 0 .. .) ...; r.:. 3 3 :3 . It:3 E 376.27 E 4 ? 1 '} q ,- c... .c..u L 46c' Q'~ ':: :I.,:~ L "")2 73 :"' ~'-. L 575.18 E 613.72 E 639.70 E 6524J28 E 660.27 E 667.92 E 676.68 E - "7 ..') c- D Ö .;.J t- L ~. q 7 '", "'1 C' (..J , f¡ ./ L 708039 E 716Ðï7 [ 7 ') ':'s 1" (: ,-. -- (' - -) . -, 7 -; -, !- ,: j:' ,,- U ò ...;,J ~- -, "1 ? / - J . e -Ji L '-. t, r í ,} f' - (j~j :3 ---- J 0 ( )' '; " p- C 0 {'- I (' yo, - >- \1' .- , ,,;.:~ ';-' -- "_-,'J:< ;, 1- , , -- .... . -, . '" - . ~ ',- : . (-;\ S U c_~ C ~-¡ D L~~ ~ T H r ;\1 DOT H f r~ D !à, T r. F 0 ~-{ f- V F f< Y [ V :=. f-,~ 1 00 F í:.:l T (; F S U 3 5 E Þ. D [ P iH . 17 ," -) ~- ~J: ¡ I 'j r ,r tI..- l t ,-, ~. :... vi co ~ --. > ,,-': t- ~, J - '--' '>-' F -- .. , PllF " . 0" Vr~L.'T- I rl',l- CUt) \Ah_T'Vr--., ~¡'\ '-.. -'- :> :)- ,Jl} L. DEPTH SEA DIFFERENCE DEPTH 7656 7134~ 7100 J.'?2 .' G.- 77::"0 7234.. 7 ') 0 f'. 524 JU c- .J 'J 7860 73 3l¡. 7300 526 7 \/6 2 7434. 7ltOO 528 B054 7534. 7500 530 8165 7634. 71,(';0 5::>1 ""-~ 826ó 773t..¡'i¡¡ 7700 532 8366 7834. 7p.no 532- ...... ~, 8/;.67 7n^ I 7900 533 :1 .)<-i- eo 8567 -) J)l 8000 533 bt -}6 8668 813"1' . f 1 1"\ r) 534 j \.Iv ~76P. B234~ 8200 ~) 3lt ...' "'- 886t~ 8334. 8300 534 8968 Sit 3/,. Plon 53'+ ..' t ; I.' 9063 B534. 8500 53't 9168 f,634. 8600 :;34 9"'):; G 87 3/+.. R 70t~¡ 53'+ L '-->~) "- - \./ 9 ~) (. P 8 ß 3ft ~ 8r~Of'i :> -, I. - ,-,.J 'v '_J .~-j- 9468 8934. 8900 534 9568 9034. 9000 53l~ 9668 9134. 9100 :¡ 34 '9768 9234. 9200 534 ;/ V rot> T 1 (' Þ, L ....K ~... C U- -, ;-? P F C- T i (ì t--.: , ., , -' . v, . 3 2 2 2 2 1 1 0 1 0 1 0 (I ,.. v () 0 0 0 0 0 0 0 T GT /,L (r-- r-, '-. r- I' - It T r c UVi<L) J\I-'. L J 162 If e 56 N 16't5,bS N 1665.82N 1 ¡:;, Q ':' 2 (:) ~J v ~, ... c -, , , 1703.34 N 171~' c. 2'- f>.' - t;'.:1 J; 1732.02 N 1742.61 ('-.¡ 17r:l,"r-' >,- :.J_v.,v H 1759~51 N 1766.92 j\; 1773.12 ;\~ 1777.45 l'-l - 1 7 p. .v-' , C':, F /\" . '-' . -.... ~ 1733. 77 f\~ 1 .,- ,.. h ... 4 Q t-..; \J Y '" .". " 1-7 1<," .~, . ö b . l.¡. ~ 1\ 1788...59 N 17--'- 7~ \, , Ö ð. '-) ¡', 1 7 B 9 (; 4 2 Î'~ 1789./;,6 N 1 7 8 9 . It 6 N 7",,' r::tl r;: -' ¿ . oJ ,- L.- 7 'J -:.~ ? 1 E" -'-'5",,- 734.85 [ 737ij:;3 [ 7 3 {} ,.., r. ..- ò.D';;' C .-... 739&91 E 7431;52 [ 746..15 E 7lt8.21 E -, ¡;: ro , t. r' E f;,¡U.'JV ' 1[;,2- Q") r:- ./ .. ,,' t.. L. 755~13 E 7£j7.89 E '761..03 E 163.50 E 7&4879 E 7 /---" ~ <) E .....:>O_L 765 III 2 [~ [ .765.29 E 765.32 E 765.32 E 765.32 E ---- ARca -r: ~ . :- OS '-10 ,úVRQsÇÔP1C- 'VRvty I NTERPOlA'tED VALUES FOR EV£N 1000 FEETO'f4i.AiUf(ff):'УPT-H-,- TRUE VERTICAL DEPTH . ÅC! C!: 11 c:.iH- n ~-_Þ'. - ,L 1""< _\.<h" - ~.J DEPTH 1000 2000 3000 4000 5000 60QO 7000 aODO 90-00 -1-^ '~o -u\.: - . 1999. 2999. 3997. 1+ 9 0.1. 5670. 6520. 7471. 8466. SU8 SEA 966. 1965. 2965. 39-63. 4867. 56'6. 64&6. 7437. 8432. TOTAL COORDiNATES A Aj'\ - v.Vv b- 0-33 N Q.S5 N 34.39 N .". ø -"} 4-4 ... - J} -0 ~ .- - ;1 911.42 N 1399.39N 1692.21 N 1781.60 N 0.00 W 0.23 E 4.35 £: G.2S E 182.84 £ 54Z.31E 696.22 E 738.23E 161.95 E 11 SEP-79 ..". ~ ..-. ...-......, ..' ). ~ A ~ " or ,. ( '~ TVD ;; TMD ;; ,'!, 4000 92461 97801 ..1 Ì" 7200 1 " I reoo +- ,6400 / ' , I ' 16000 / / 5600 .,.. ~ ,/ .:::> / CI) I 0 / ....,¡ , (.) ;' ~20C) ", , ' /","4800 ,/ , "...,. ,......... (" ARCO OIL a GAS DRILL SITE 3-10 GYROSCOPIC SURVEY RADIUS' OF CURVATURE SCALE! 111= 5001 SEPT. 18 t 1979 ~- ~ ~ ,-., - .' .. ... " ,...,. ........ ... ALL ARE DE PT HS TVD. SHOWN . ., --,,- ,',- ( 0, 400- 800 -:- '1200- 1600- ;) ~ 2000 - 2400":" 2800 - 32,00 - 3600 ..,.. " 4000 + I 1'\ 4400 - - - :1" I \\ 4800 .- -~ " \ - 0200 ~ "- , 5600 '~ \" 6000 ~ \ , \ \ 6400 ~ , , \, 6800""'1- 7200 - 7600 - 8000 - 6400- 8600 - 9200 - ( ARCO OIL a GAS DRILL SITE 3-10 GYROSCOPIC SURVftY RADIUS, OF CURVATURE SCALE: 111:10001 ' SEPT. 18, 1979 I ~ c ALL DEPTHS SHOWN ARE TV D. TVD:: 92461 TMD = ,9780' . Nodh 1.las:<~ Dis!¡::;! Po~;t 01:j" '0:': 36') I\nchcr~,~ ,\I:E~:;:¡ £~510 Tc!.::pk:n.c 9D7?7ï C,G3r ( I':'~ fJ)' : ' r' T ' ", '. ~': ,.': "\' '~., , /,' ,,', ,. . /'<,.., "~ ',c.." : ~,.._' ...., '~'-~.."" ('ji,"',': "- ", If ¡ " :;:;) ,;;::1 1¡,.I,:,I;\;,',:";",,':ìr"i)',,ICI,I;:i)i','i>i',:r" l\ovembcr 7~ 1979 Reference: Enclosed are ~ Iagnetic Tapes for the following ARCa Hells: ~,'"',, ,,27/79 Tap,c #57005 Schlurnberger ' .S~ 3-1~8/31/79 Tape #57011 .' ._,-' ~;-Sign and return the attached copy as receipt of data" K., J., Sahlstrom North EnuineerinO' b ö . TRL\:\JST\II'ffAL # 464 , '."--:-7 DISTRIBUTIO:\ North Geology Exxon Drilling ~Iobil Eng. Manager Getty R & D Sabia Geology Marathon State of Alaska Phillips D & ~1 Chevron " t..._"."";,,;,, /~;~'".,. - I ",-" ",""I ,,-r " -,'" :;-:';.:::::"", ¡, I,';", . '-::,. '" /.', , ,,- (+~;-::;:.,.. /'t ..~:.~ ' >--;:'"J , " ¡;::--"Lt? '- "', ! , ¡ ! \,,' 4r",:' , , :, , ' 1\ ' (I'" '¡'Ii") ", "II/ II'" . . CJ: V.I i,/I' f, ,,., ' ,; Ii' I:} (, ': :;ì1~:-:;~'~!":;:1:¡-,::;,:(>.-:1t)t:r:i ""t""'~'1D \' f,'" bU,\!. ¡'¡ïl,;( ',;:'.Ïl f'f.)C.t:C:filg ..-ìVI~;jOn N .:nth Þ I~: ~¡..., i ;;~,r, :c t p()S~ 0 Uic! ,., (¡GO ( '" )" I COM /)"JI'~,:: ',--. I .. ,--" , " ,.~, ',,'" ':""',:"," I COM' ..' "', ,""',:" J .",:, ' , , '~:,- '--"" ,---_....*..,'00""'-" '..,.'".. '___"',I,_._C_OJ\l\J\A lc\~.,( "':~:"'~~~,~-., rjT-',',:".-:-;;:Y" --' ReS fi'.-IC, ¡ -", ',>: ;t--" 1,'¡n\¡Ir.'J)' ',} --,--.- -'" 'j-.." '-.¡ I '" "-NC' ' L. cl" I --r3'::',,:'-: j -1'-4 [:.1(;----1 1 GEOL ¡ ---- --- , J3g~:j I ST A~vffc--- -r-ST,A. T TEC- . ,-'-- CONFER: FILF: /\nc:,or(:~jÇ, Ajd'3X<1 995\ 0 Te!:'¡J~'1':Jn~ ~.i;J'ï :~ï'7 !.:.G:;! October 26,1979 Reference: Enclosed are Magnetic Tapes for the fo11mving AF£O wells: ,~ , WGI # 3 . C~eas, e sign and return the attached of data.. 11/12/79 ? 10/6/79 10/6/79 Tape it 681 Tape it 672 Tape #,673 Dresser Atlas f I fI " " copy as receipt K., J.. Sahlstrom North Engineering . TRAI'-JSÌ\UTTAL N 439 ])1>;1((1' j;¡ iTIC)\ .\o¡-th C,-:010(,I\" ,> , ¡ )r.illi ng ],:nC) \¡'.)!) ',l(¡ ',"" . .;-,' ,l >\, \ ,:. \ ' I 1 ~ [; 1 ) Cr,n'1 (\(1\' " ~ - . - c", SUt['c of /\laska n e¡ ~r l\xor 1 ;,.[c) 1) i .! C;c t: tv ~:;Oll.i,o i\[~1 ra thon Phillips Chevron ~J&~ - ; .'~'~' - ¡ iiffi~ a... AJiiSk::J 0:/ ;'~J t....e, !. & GI)S (í) AnChor.a'ln~S' (,OfJ1rn. 5'\IIJ /SSIOfl '\. ' " ARCO Oil and ~as Company '\¡Otl!~/\t' '11',l'I.: r";o~,: Oi' l)O,' :::';:' !.\I',::!òc,aqn. i\la;;l( , J'ìl', Tell'pilOnc: 90"1 xn r:;GJ7 '. I..~' J (, October 26, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 J ' SUbject:~ermit No. 79-22 DS 3-10, Permit No. 79-21 Dear Sir: Enclosed please find a Completion Report for the above-mentioned wells reporting production information. Very truly yours, ?ÍJ. -I ~ P. A. VanDusen, District Drilling Engineer PAV:jh Enclosures. ARCO (JIJ ;",d G,,~ CUI~'P:"'\' '" ,) i'",", ',(>f /..tI,'I':h:i'.ldlficld:;rJl'I:' ""ì I;"'" ", - '. , ~: ÍJ L. ,:' ï¡,' ,~' ;" , \, i,./ r . I" , " '. , t ;; /n , :' ,I AJ:::~:'. ' V," /'1 "~I , ,I.,} [.:1',)(1:': " I ..,; I,C: '; 1(,11 RErEIVE'.O '. ~.. ,m' ~,' ,«"..,' , ',," f,;[.V ~'1 1979 Alaska Oil & G,s [;in:'" l>Uldl,¡¡~j;:rJII Ant~t1uraU$ . . Form P-7 SUBMIT IN DC '-"" ,E* STATE OF ALASKA (See other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE (' WELL COMPLETION OR RECOMPLETION REPORT AND LOG* 50-029-20361 6. LEASE DESIGNATION AND SERIAL NO. 1a. TYPE OF WELL: b. TYPE OF COMPLETION: NEW 0 WORK 0 WELL OVER 2. NAME OF OPERATOR OIL IV! WELL ð,.J GAS 0 WELL DRyD Other ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME DEEP-O EN PLUG.D BACK DIFF. 0 RESER. Other Perfora ted 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. ARCO Oil and Gas Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchoraqe, AK 99501 OS 3-10 (22-11-10-15) 10. FIELD AND POOL, OR WILDCAT 4. LOCATION OF WELL (Report location clearly and In accordance with any State requirements). At surface 21341N & 6381E of SW cr See 11, Tl0N, R15E, UM At top prod. interval reported below Prudhoe Bay Field-Prudhoe Oi' 11. SEC., T., R., M., (BOTTOM HOLE Poo' OBJECTIVE) 135~:o~al~Pt~403IE of NW cr See 11, Tl0N, R15E, UM 13571S & 14031E of NW cr See 11, Tl0N, R15E, UM See 11, Tl0N, R15E, UM 12. PERMIT NO. 13. DATE SPUDDED 14. DATE T.D. REACHED 15. DATE COMP, SUSP, OR ABAND. 79-21 16. ELEVATIONS (DF, RKB, RT, GR, ETC)* 17. ELEV. CASINGHEAD 8/8/79 9/1/79 9/7/79 18. TOTAL DEPTH, MD & TVD 19. PLUG BACK MD & TVD 20. IF MULTIPLE COMPL., QEPTI-I HOW MANY* 9780'MD 92461TVD 9/321MO 91981TVO Sinqle 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* 64' RKB 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS All Top Sadlerochit Base Sadlerochit 91851MO 9660lMO 86511TVO 91261TVO 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN L/1OIL/SP/BHCS/GR, FOC/CNL/CAL/GR, FRT, OM, GR/CCL(CNL 25. CASING RECORD (Report all strings set In well) CASING SIZE 20" 13-3 8" 9-5 8" WEIGHT, LB/FT. 94# Welded 72# Butt 47# Butt GRADE H-40 L-80 80&95 DEPTH SET (MD) 811 27301 9065' AMOUNT PULLED cmt 26. SIZE 7" TOP (MD) 87451 LINER RECORD BOTTOM (MD) 27. SACKS CEMENT* SCREEN (MD) SIZE TUBING RECORD DEPTH SET (MD) PACKER SET (MD) II 28. PERFORATIONS OPEN TO PRODUCTION ~95331-95551 /1~ ~9500 1 -9512 I ~ /\ ;;'94801-94741 , , 94251-9450 I (I nterval, size and number) 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED w/4 shot per foot '," 01' '/ ' I,.,' \ -'-. '" "'I . ,,\... ~' J.I . . " .~:; 10/11/79 FLOW TUBING PRESS. 903 PRODUCTION PRODUCTION METHOD (Flowing, gas 11ft, pumplng-slze and type of pump) 231<::1, Oil.. !~ WE.llST ATUS (Producing or Flowing !\'"'~h,~t-lnrH' p'r'ôêiütW{ HOURS TESTED CHOKE SIZE PROD'N FOR Oll-BBL. GAS-MCF. WATER-BBL. GAS-Oil RATIO TEST PER 10D )Þ 6. 1 57 11 828 298 785 WATER-BBL. Oil GRAVITY.API (CORR.) CASING PRESSURE CALCULATED Oil-BBL. 24-HOUR RATE ~ 47 312 1192 2 TEST WITNESSED BY 31, DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ( Reinjected 32. LIST OF ATTACHMENTS 33. , h,,'by ",tlfY Ih,l tho fO"'Olo~ïr oI."h'" ,"",motloo " ,0mP"" ODd ""'" :' d""~'O'" "om :" "':"b" "'Ofd". SIGNED ~/J.. l(~~ TITLE Olstrl ct Or,11, nq Engl neer DATE ~ *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: Th is form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: IISacks Cementll: Attached supplemental records for this well should show the details of any multiple 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. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH None Top Sadlerochit 9185' 86511 Base Sadlerochi 9660' 9126' -.-' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Core data was sent under a separate cover letter dated 10/8/79 by Geology Department. r;c.ì t:, !li.1"ì:,\1 Di:)~r¡ct Post Oiij~,() ;\)x J(¡O t\nCfl(\r'J' i"j':~(~" ,:""~~::'1n ",J, c",...J.....,'} 'f,': !::' phon é: (;,"'./' ':.TI ~'<):3¡ October 30,1979 Reference: ( Open Hole Logs for the following AHCO Muc.l1og 9/9/79 8/31/79 8/8/79~9/9/79 , Pooled Arrmv Plot/Cluster Listing 'I !! II fI tI Please sign and return the attached copy as receipt of data., K~. J., Sahlstrom NO1~th Engineering TMNSHITTAl.J # 444 \'u j' t'h (>"""[1):"" . , , ~ I.', - \ \:,j '] )ì',jJ 'JÍ:1¡l \' ¡:¡ì\' ~,!:¡n'l('C'r ' ';:.' ., , " ", .:,," )~ é; )) CcoÎo~ \' \,' , St;ìtc of j\lasb¡ J) k; 1\! ])T S'I'¡~T J\l fl'¡ (),\J ! >~,\on ~bJ.' i1 (.;ct t v ',I Soh'j,t..) ~.bTat¡1olì Phil'! ip:.:; OJ ;,~\, 1'0 n /"7 " (:~~ ' . ,,;,:=;¡, -- ¡,/q.('k~ ,4~:J.i,lf ,f ,119 d,".' ' , . '-., Ok '"'01..-1; ", t,,'~ Ocr 3 1 19¡~' "'"' 4Jaska f\1¡ 1) I., . ~,¡, u ~ ~, ..,1 d ~ AnCfJuraue I".."..." I ,~< ",j: '\ ':}., " " ;", ;~", ~"': ',,".', t~1 ,"' "" "..: 7':'...:.::::, , ,:.,' , , '::¡ , ~ , '",J ' rost oniG',~ ¿,,~~^ 3~;O ¡\nc¡~o ';::~i 'i,~ ::.,-¡ 99:.;'1 U Tf:1-;p;".)r,,\ ,/ '),:'1 ~;')Ti October 30, 197q Reference: ('Î k . (l" "I,' r .::'\.. , , ...<"t v'.¡, , Enclosed aTe PTCSSUTe SuTveys for the wells: ~~~-~~" 9/3~/79 iJ"-U . S 3 - ID-.::). ~:<i!WJ\:\;"';""J~'I~ Dresser Atlas " , r ~' , ( .. ,)' .' 7>... .,,- c," \. ,"'"" ,.; .:,..y<. "'", "", " J "'~'1 ",','," ",,'" , ',', , /'-:r/ "\,~" :,7 ~' --T-ê'Òij\~~Ä"-~.l' \ COi\:'JJ\ ~ I ' -~. ,.' \ co I, ~':' ' r" -.i~:,\,:~,-- ; --"'-'\-I')ç:,-" ',;..;:~ t, '-', ' ',._-:'\.}, [\'--1Gy-- \~=-]'-,~ ~;>,p3D,.-- \ \ '3:; ':, =' ----'\ "~r",;,\~ ,-- I ' " - ,- '1-----' '1 r::~L I r :; -. ?:::l- :_+q--~ "~I-Ó' )4,' \ '-' :,.. '.¡ ..../.., '--"I '~, I~,' ce,! / , " J - ,J '" ,- , ("'r r, 'r' "C::C : \ ," ", I '" ,- ; (1 \ r," ^ ì- T'::C : 1') ::- I IJ, ," : \ t" '\1 F ¡:: R . , ',- .." ..' ..,- - \ ,'" '.., ...-.1 followin IT ~AAGO' ---"--- C> ¿....-P'íease sign and rctl.l111 the attached copy as receipt of data. , I K. J. Sahlstrom North Engineering TP.Ju\JS1\HTTAL If 446 !'\nrth (\~ul O~'\' , " ]) r i ] 'I i j I;) , , rr() '.I,p);}\' ",)' . ..:,' 1, \'.. ,:' ~" , J:~ (' ,'\ , '- ¡ " CC'ol U~IY ,,' , Stntc of :\J:¡~k~l l' ('; \1 j)"l (-;'j 'j.1 ! 1)1 "" I ('ì' , " , , , . II , J.\ I >-: :\ C1 :1 ¡\[O1 ):i.l ( " (\ 'I "l" \ ' .." " '¡ S()11 io H,l.l'a tho:} PÌ1i,11i.1)~ Chevron ,""-') " ; .. , .. \'. /', ,'J ~, I ',' "'¿' ") _O)' " (' ,,' f ......"""',' ,-, ,'.,-,,' /' " "" ~ ::......:,~( /,.1 ,..' ,:'~!!"""'-c.lr,/<,~,:,:-,1'/1, , ' ~,.,,¿2 ¿. t-- ¿; to" " ,~'-'- {./"'(j;;il ( Ii, .' , ,,' : " C,,' ~ ~ ,,' " ": /, \~1 ~ ¡' I'" '. " 1"1"\,,,..:,..., I,.;li r" q , , ,,' ',iI "," I;c :' ", ,,'-., ,': ¡',:,:I"" ',' I ¡' . ..1,;.:'- ,j : J Post Offic0 30x ~~GO Gtl""\""~' 1.1 '-' '~' T ,,~¡2p' ~, 1\1 ¿;:;:\ ,1 ~)S:j'1O . SCJï 2"17 ~jG:¡ i' October 23, 1979 Reference: ~,..)\. ....~,. """",-""-.,,,........-- ,",'\~, ' " ' (Y~' </ 1 . .-~' f ",,) ~'\ 'il . ...;~ . . /, V' r- r)! ,I A - "', ~.,':. ' .. ""'. --- \ \.' ~I . 1 --'--- I, '.. . <- ~~.~~ 't,~~ ~ J' , ". ~/ ; 1 ~~.~\., .. I ..., "." I /. ~ ;\.,.. '~Ll\... --. I ; J..¡ 1 r :~,)I. -. ¡r:- .... v, /11--- I (.' .; , 1'. 'q-q' .. ,,' '- Y;;-Z:- t-- ! :j G;:C1 L i ST'YijTEC. ::',"'" ,<:;--, :\---, -f ~:Î_',',.', ' . ',-' 1/ -- f , - COí\!rFR: . rll.F: ----~---- Enclosed are Cased Hole Logs for the fo110\ving ARCO Ke11s~ ~ ! . .S. 3-10 D.. - J.." D.S. 14-8 Äease sign of data. 9/30/79 9/29/79 5/31/79 6/11/79 Differential Temperature Spectra1og- Fluid Density CNL - Run 1 5" RÜn 1 5" Run 1 5" Run 1 5" and return the attached copy as receipt K. J. Sahlstrom North Engineering TRA1~Sr.n.TTAL # 429 ¡nSTRJ h~jl' [0\ j~:OI'Uì C;coJo~¡\- ,'" }.::\.\ 0 JJ Dr'.l ] 'I jt1g i'!oh.i 1 l~ng. )\1él11;lgcr Cet:ty fZ é; D Soh 'Í.o Ceo'! O~),y ~!a1-(!.t]10n St;1tC of Alas )'.;:¡ pj} iJ.l-¡ ps 1) (ì ~1 Chcvr.on ,. /7 . (-re. ',' '. f....: ./" "at: /7' {" ./ Lé/ý' ,. v./ -....-' .'~'tr,é?~~_~ t?/ : . . ~~''- North ;\1.:1::;:<3 Distr¡~;t Post Off~c". ox 350 AI''''''''''''''''( '..,..',,-. 'g'v"" 0 ' 'J I . v , , ' k.1 :'" " ...;.:J t TC!2pi"lone 907 277 56Tï ( ,-61 ~.~ L¿,/~~¿¡ -"":".; I COM . ~<~(j =~\~~-~~ ',. I Rr:S ti~G ---I 1 ~:NG 1-----, - -, , '. t ,,' I, 2 ENG, 'A'?' 1_--- --. p-'--, ,--- -\- ~ ;~~--- tá 1 GEOL---- , - I - 2 GEØflL-- I 3 GEOL . I ST 1-\ T TEC ~:F::=C- . FILF: 1 I..... '... ...~ \~ I I l.j :...) i J J. 'J i I October 23, 1979 Reference: Enclosed are Open Hole Logs for the following ARCa wells: (~~D'~Š'"~~~~~~1i) 8/31/79 CPL' Run 1 5" . ' - v ~1r 3 9/20/79 CNL Run 1 2 & 5° (same log) ~Please sign and return ,the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL # 428 /J /' ~) r~:: it'''' F:i~ ~,:' ¡i""~\, ~þV~k9Øt:.):ta (' ,r",'~' q ['.tt~ /O~ \.. ~ (_.'~. !.0! 0 (} ~~,:y £ ~:;' DISTlrrBlJTTO:\ tJ:~\;<:~ O~i (,e! I 11 n t ~:;~;iu¡j North Ccolog;: Dr.il.ling Lng. i'-!:ln.:lgcl' R c¡ D Gcolocr\r \., ',.. State of Ala:;ka D c¡ ~l f:~\:.\or I :0rob:i_l Cett)' Sahio ~.Tara t1ìon Phillips Chevron .AI ", ( ( DRILL SITE 3-10 Sec. ll-T10N-R15E, UM ARC a Oil & Gas Co. CORE SUMMARY Core Recovered No. Drilled Ft. 0/ Lithology /:1 1 9130-9189 61 100% Shale, mudstone 2 9191-9249 58 100% Sandstone 3 9249-9308 59 100% Sandstone, shale 4 9308-9362 53 100% Shale, siltstone, sandstone, conglomerate 5 9362-9397 32 91% Pebbly sandstone 6 9397-9455 52.5 90% Sandstone - 7 94-55-9513 55 95% Sandstone, siltstone, conglomerate 8 9513-9573 58 97% Sandstone, siltstone 9 9573-9631 57 98% Sandstone 10 9531-9690 59 100% Sandstone, siltstone, shale i ::.. ,,,¡ . ../,;'J ;,~ ",....:..",P ~~,'.:..f """'''''-<,'~,'''' """""."." '-';'(' ,",'V", : ./r~'i;';'; ""'. '~, '.. -.. ..' '. , ¡ ~~ C/-' ~_:.'..~ :'\ t { ¡J ¡ ~ ~ i c: Fi i (: :'; ~: ¿: : \.1-:; c ~ì1 p :: i1 y Nor t;') ;:\ ~ìl ~,~rìc::::; Pm j \,ci n~j Dj Ij; s¡ on tJ a r th ¡.\ Lêl,;: ~(,1 D i s ~ï'i c I Post OUí( ax 350 Ancho::lJé:, j\!:lS~\Q 995'10 ( T2!.~p:~O~~~ ~lOì' 2/7 ::;G:::ï' Reference: in, þ. i .' ¡ JJ 1 '''':'):, ') ') ¡-: ..;.~ '--,,----1 ; I:: :~o' '>¿íj - - v ,-] '" l~ I-'-.~ ~.~- I ST.,~ T n:c?:::J. ~J~~!i1 FllF, --j October 23, 1979 Enclosed are Core Reports for the following ARCO well: A ,J~$'.s 'D.S. 3-10 9/28/79 Corre at ion Coregr ph ~rlft (J , II 9/17/79 are Analysis' (jø(t, "D.~. 3-10 Core Summary rom ann P-7 '~ease sign and return the attached copy as of data. - /J¿:)t'~ 01::... receipt K. J. Sahlstrom North Engineering °. TRAt\JSfiIITTAL It 425 V"' . ~~~..~ \ I """ l-" '~,,',",,,,,,',',',:',,""'.,~-, " --..ð /":J~' ,: ',' "..~ "" ~~ {"../'(J, .--~ D T s'nn n UTI 0\ \\.)¡,th Ceo] ogy Exxon j)ri l1ing ;\!ob:i.J Lng. r.!arlag c,r Cc t t)' R & D Sohio c.;cology ~.Iar{ thon State of 1\1,:.:151\<-1 D (1 M Phillips Chevron ARCO ~i,1 ,a,nd -;,~r,::-"r~~Ompany ,',I,i"Ld 1., r'f);! Off:cÒ ,,;,"( 3GC: ,::'.nchor~lqc. AI;':;J'.Z1 09510 1C'¡epholl" DO? ?"77 56:17 October 17,1979 ( ,~ ~~ Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 , "",""~"'~'''''~:f~~~~~~~ Subject: OS 3-9, Permit No. 79-22" \OS 3-10, \')Permit No. 79-21 OS 12-3, Permit No. 79-41 ~1~,.,#.é;;.t;'""Permit No. 79-43 WGI #3, Permit No. 79-49 De a r Sir: Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, l!lI7I~ P. A. VanDusen District Drilling Engineer PAV:jh Attachments IF . . ~ ,\ flRCO Oil Mid Gas Company Is 11 DivisIon I)f Alléll'.ticRich~ip'dC:ompM1Y ¡ ,. ~~ l i 'j r} 1/ I , , ~ .:,' ~ , , ' , , '~::¡ l SUBMIT IN ol_, ,--' 'E* (See other In- structions on reverse side) / - .. ( Form P-1 STATE OF ALASKA Oil AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE 50-029-20361 6. LEASE DESIGNATION AND SERIAL NO. OIL r7ì GAS D WELL II\....J WELL DRY D Other WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 79-21 16. ELEr~JNS (OF, RKB, RT, GR, ETC)* 17. ELEV. CASINGHEAD 8 8 79 9 1 79 9/7/79 '6 } RKB 18. TOTAL DEPTH, MD & TVD 19. PLUG BACK M,D & TVD 20. ~ MUL¡~L; COMPL., . 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS 9780'MD9246TVD ~~3~IMD 9198TVD O~rngle ALL 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOMnNAME (MD & TVD)* Top Sadlerochit 9185 IMD 0651 ITVD Base Sadlerochit 9660 IMD 9126 ITVD la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW fV1 WORK 0 DEEP-D PLUG D DIFF. D WELL Lill OVER EN BACK RESER. Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.o. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requlrements)* At surface 21341 N & 6381 E of SWCR At top prod, interval reported below Sec Sec Sec 11 , T 11 , T 11 , T 10 N,R 15 10 N,R 15 10 N,R 15 Al ~?a~d~Pt~ & 14031 E of NWCR 13571S & 14031 E of NWCR 13. DATE SPUDDED 15. DATE COMP, SUSP, OR ABAND. 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHCS/GR, FDC/CNL/CAL/GR, FRT, DM, GR/CCL/CNL 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit E,UM t:UM ~UM 9. WEL!-N°. DS(3 - lQ 22-11-10-15) 10þFIEL AND P~OL, O~ VVlr'ÇAT r U 0 e a.Y 1 e a ru oe 11 00 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec-1l,T~N,R.lLE,UM 12. PERMIT NO. 23. WAS DIRECTIONAL SURVEY MADE Yes HOLE SIZE AMOUNT PULLED 25. CASING RECORD (Report all strings set In well) DEPTH SET (MD) CASING SIZE 26. SIZE SCREEN (MD) II 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) Arcticset IIcn 27. TUBING RECORD PACKER SET (MD) 9533-9555 9500-9512 9480-9474 I 9425-9450 w/4 shots per foot N A 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 30. DATE FIRST PRODUCTION N/A PRODUCTION PRODUCTION METHOD (Flowing, gas 11ft, pumplng-slze and type of pump) DATE OF TEST. CHOKE SIZE PROD'N FOR TEST PERIOD ) HOURS TESTED OIL-BBL. FLOW TUBING PRESS. CASING PRESSURE CALCULATED OIL-BBL. 24-HOUR RATE . 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) GAS-MCF. Reinjected 32. LIST OF ATTACHMENTS GAS-OI L RATIO 10/17/79 DATE *(See instructions and Spaces for Additional Data on Reverse Side) I ¡ It. B' () ¡).j¿tLlþ t 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: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple 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. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME ri~Nf. MEAS. DEPTH TRUE VERT. DEPTI Top Sadlerochit 9185 8651 Base Sadlerochit 9660 9126 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Core data was sent by our geology department under a separate cover letter on 10/8/79. ../ H ~. . I - "r::'-',~ ( ( Drilling History OS 3-10 (22-11-10-15) API 50-029-20361, AOL 28328, Permit No. 79-21 Spudded well @ 0300 hrs 8/8/79. Drld 17-1/211 hole to 27501. Ran 13-3/811 72# L- 80 csg w/shoe set @ 27301 & FC @ 26481. Cmtd w/50 sx red dye cmt, followed by 400 sx experimental cmt, followed by 50 sx red dye, followed by 4000 sx Arcticset II cmt. First 500 sx including red dye cmt was part of sur cmt experimental tst. Installed & tstd pkoff, did 20 sx top job. NU & tstd BOP. Drld shoe & 101 new hole to 27601. Tstd form to 500 psi or 12.5 ppg equiv mud. Drld 12- 1/4" hole to 90801. Ran & cmtd 9-5/811 47# L-80 & S-95 csg w/800 sx Class G cmt, shoe @ 90651. Installed & tstd pkoff. Dwnsqz 9-5/811 x 13-3/811 ann thru FO w/300 sx Arcticset cmt. Arctic Packed 9-5/8" x 13-3/811 ann thru FO w/240 bbls Arctic Pack. Drld show & cmt to 90901. Tstd form to equiv of 12.5 ppg mud. Orld to 91301. Cored from 91301-96891. Ran DIL/BHCS/GR log from 97771-90671. Pulled GR to 27301. Ran FDC/CNL/GR/CAL log from 97771-90671. Ran RFT w/2 press stops & dipmeter. RU & ran 711 csg w/shoe. set @ 97751. Cmtd w/200 sx Class G cmt. Displ cmt & bump plug w/2000 psi press. Installed 5" ra~tstd. Cleaned out to 87471. Tstd csg to 800 psi. Cleaned out to 97321~ Set pkr @ 86721. Performed WSO tst. Chgd over to CaC12. Installed & tstd 5-1/211 rams. Ran 5- 1/211 tbg. Displ tbg csg ann w/433 bbls diesel. Set pkr. Tstd tbg to 3000 psi. Ran 2-3/811 tbg. Chgd tbg over to diesel. ND BOP's. Installed OCT tree. Tstd to 5000 psi. Press up tbg to 3500 psi, 200 psi on csg for long term tbg tst. Released rig @ 1730 hrs 9/7/79. Began perf operations 9/28/79. Ran Spec log. Perfd intervals 95331-95551,95001-9512',94801-94741,94251-94501 ,w/4 shots per ft. Flowed well. All depths referenced to CCl dated 9/11/79. Ran Amerada press bomb w/grad stops @ 92991,93991, & 94991. Ran & tstd SSSV, closed SSSV & bled dwn f/1250 psi to 750 psi for 30 min. Installed & tstd tree cap to 5000 ' psi. Released well to Prod Dept @ 0130 hrs 10/1/79. ~"'t "'"1'11 ¡.) \', ,r ,,. r J¡' " J;'. (' ( ,I II I rT7 Eastman " ~ ~ Whipstock II A ÆTROLAN£ COMPANY I REPORT of I SUB-SURFACE DIRECTIONAL L SURVEY 1\ ::,\~ I ¡ J ' ,- I I I I ARCO OII&:':I&',GAS COMPANY D.S. 3-10 WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUMBER TYPE OF SURVEY A879 S0434 Magnetic Multishot SURVEY BY Tom Jones OFF!CE ALASKA II I I ¡ I I Q.ß.IT 8-31-79 ! ¡ ; , ¡ ll'O"fIII' O"'l~~ FJ2. (' ( !1fI Eastman ~ ~ Whipstock a A PETROIANE COMRWY P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 7VVX 910-881-5066/Cable: EASTCO September 4, 1979 ARCO Oil & Gas P.O. Box 360 Anchorage, Alaska 99501 Well Number: D.S. 3-10 Location: Prudhoe Bay, Alaska Type of Survey: Magnetic Multishot Date: 8-31-79 Method of Computation: Radius of Curvature Surveyor: Tom Jones Job Number: A879 80434 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Magnetic Multishot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, ~ q(Øu.- . Bob Kiser 14 District Operations Surveyor co: file enc. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide G'.. r~". :'~ .-' "'.... CD ::::: .re., ~ ,2.: w-: ::-. :L ;-'::i :,.:....: " ~ ¡- ~t ..''':'''' ,"'~ ".:" "':'" '¿ ;::. ~+ '..') ''''''; ':! )- 7::: : ,,'-:- -.....: ".J... <I ;L ::E """, ..,... ~ ,....;. '. '.z... 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N 6 E N 6 E N '/ E N /' E N :/ E r\ "'Z 1 '..J . 9..:i. 9 :::~; .¡ ã.j} ~:i) + i) ,4"4 + N ßE N B E N n E N 'IE N :1.~5 E 93+ 93. 94. ¡~:I ::5 + '/,~+ ,{:, ¡:{ C 0 Ü~:) :'~; LIE!...!... J 0 P¡:<UDHCI[ Üfi'Y '! NUi:~TH ~:>L.OPE" Al...t~SK,~ CONF'U T {¡ T I 01",1 'fIt'}[ Dt;TE 0 '» : ():3 ¡ .q ,,:;- 0 ~:.; -.. bE F' .u/ ~/ ¡::' ::¡GE NO y ~r Tf<UE i"íEf~ßUf~ED DHIFT DRIFT C[)UI:~SE VEf<lICAI... \.jEf<TIC{.¡L I:;: I::: C T (.¡ N G U L ~:¡ I:~ C LOa u ¡:~ 1::: DEP1'Ii ANGLE DIRECTION LENGTH DEPTH SECTION COO R DIN ArE S DISTANCE DIRECTION FEET D M D FEET FEET FEET FEEf FEET D M ß61".7. B7l0. Dn03f BB':¡:? .. B9(':¡O. ')OBO + 9:1.1b+ \/ ~:': 0 \.1 . ~? :.3 () ~'5 f \.;:- :~ \) ..~.} t (? .i.} ~] i.ì + (?::':¡B3. 9(,:.'76. .;;i)'O} ÿ PF<O...JEC'fEII ':'}/Ü(). DOGL.EG f.)E\.lEI:~ I T'{ DG./1OOFT :::¡ 0 N 19 E \lt~ 8093 :1. 9 19()2 ~;B :f. ?47 29 N /59 ßO I::: 1. 9 () ~~j :.3.4 N ";' "1 ...,.'1. E 0 t:. (:) . .. . . . t .~:. ..., "~\) . -4 30 N 21 E (?~3 H 1 8~:j B? :J.9:1.0 2B :I. 7~;j4 ~5:~ N ..... ~ ,OJ 44 E 1 913 Ü~:~ N 2:3 :;~';Ÿ' E () ~:.;-.l . . . . /O~, of .. . ~:S 4:.i N ''') -š E 93 82?B 63 1 9:1.6 97 1 "" J. .", 73 N 764 94 E :I. 919 72 N 23 I::, 0 H~:.~ ~.....J ~ . . ~ \,)V . . . ,'¡.: 7 + :.3 1 c:' N 2~5 E 94 8372 4~) 1922 ?0 1. 7é~.; 97 N 767 2B E 1 92~j ,45 N ~.:~~ :~~ :;~ 'j.i E () ('~ .,} . . . . . + ''') 4~), N 24 E 9::~ B4t)~) :33 1.92"/ 1::'1:." 1 7'70 40 N '7(.)(,» :.30 E 1930 :"5:~ N ::,;~ ~3 29 E 0 4., . . . ...J.J . . . . .''- ~,:.~ ~ 1::' N ~::4 E 90 B~j~j~j 22 1931 B6 1774 "'1 c:- N '/i1 Ü5 E 1. ~i ::s i\ Ò.4 N "'"1 ..:~ :? ':ïl E 0 00 4 .,j .. of . . .:').J . . ,,:'. ..:> . 1 30 i"l :~~2 E 36 B~:j91. 20 19:33 20 I ..., ...'c- ~jB N 7i'1. !57 E :I. "':¡3~,; 9'7 N :::!:~ ~.:.: 9 E :3 4B . . / 1..'1 of + . ~ :I. 30 N ;'~:L E 93 + 8ti84 . 1 l 193~.) . t:,3 1. 777 . B4 N /í'2 . 47 E 1. 93B . 4l N 23 ~?9 E () . () :~:s :I. 30 N 16 E 94 B77B. :I. 3 1. 9:3H 09 1700 :1. '''} N ;?7:~ /') ¡;;. E:: :1.940 Ü¿> N :::2 ~:~ ::,~9 E 0 :I. ..:l . . of l .. .;.. ,.J + + 1 30 N :I. "1 E 9:~ Be?:I. . to 1940 ~51 17 f.1 k.~ ~5:~ N -'} ..., "'/ Bb E -:1. 943 ::.~ ~~:. N 23 20 E () 08 "oJ . . . l 1.:':\ . . .. :I. 30 N :I. ") E r:J ~5 B9¿4 + O? :1.942 92 1. i'BA ~;.1. N '774 3H E 1 ':'¡'4~5 ,.: t;:" N .").001 .,.:~ ":J E 0 03 ,,:.. + . . . ;¡ \.J ..J .,\.:.. --I ,:.. ¡ . 1 1 ~5 N :I. :I. E 94 90~H~. 04 lS'45. 1.1::' 1. 7~:f7 . :t. 2 N '774 ß3 E 1947 <:56 N ~?3 ::.:: (~:. I::, () 2/ . ., . .¡ + :I. 0 N '7 E 93. 91~.:j 1 .. 02 :1.946.94 17B8 ~92 N 77. ~.:j + 12 E 1. 949 . 6:~ N "J":¡ ::.~6 E 0 , 28 "":. '..1 :I. 0 N 4 E 31 9:1.B2 02 1.\,'47 4\5 17~~9 ..::}6 N 77~5 1 l E :1. 9~50 :1. .1} N 23 ~.~ ~5 E () :I. ..., .. .. .. . .. ,; .. / :I. o. ~ N 4 E 92~:.¡~5 + ():I. O'e 194B .,6B '73. 1790+73 N ";? 'ï' ~5 ÿ :~~~ é:. I:: :I. 9~5:1. .. :.:~:4 N 23 ::?~:) F N 23 DEGG 2~::.¡ NINS [ . 19~;:j:l.,,::54 FEET F J N~~¡I... C/...{)SUt=<[ .... ü I f<ECT ION; DISTf4NCE: ~-~~~~~#t;; I ARe!-' l' I ' ' ' I ,~tæ::c:ro::=~~._' ---- --y ,._-'-~-=~-----f1lJf'?-l=ÞJH~-1(Rb-.t'~Ð-.j-9'~1::-l-Qfi ==r-'PRtJÐ~E--BAYï-NðR-frrStðPE;--ÃlASKR=r===--===:~==- 5CRl:~!1- -IN.~=-29!!rFær-----' i -~acRimc==þ=~:=i==--~~=k--=~~~~~"1H~r-- . ~ ~~~-=T-~~~~~=~==F~=- ===r--:--r-~ ==1----~_t---:- 1-- ~'-~-1-~--l:--- --+----r- ¡ : : . ~.~ ¡ -~\'-----r ' r-~- \ t;--:-r=:: ' r- -o--~- ~~-~--= I f--~ +- f- -~--+ t---- -~ . - J . --::t=:---=---+--; t:::- ~--r-:1&-'--~~- -- -;--. ~f~~ --;;;- ~~; ---~--:~--~~-r -~+-~¡,,----;--~ ~ . ' t I i'1I.I,- n I ..YI'. , ' I L 'l'f "I fljp Mrlo_~'LUU' I VL ¡ I I' I :¿ ~1:¡~1a: E-RS-l+-+;1s.: ~-~.~ ," I :JL l~;:¡J.,. 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' I --~'-r----r---_-:--'~ I ---.-1- --r --t-' .-- ._, --1--_":: ----, ..- T ---:=.=:t::=::i 4- -~c==!--_._~--->---'-' . ~-- ~...." t ïI - T "" ,- I ~ .---- I " I ! I I I I I I I I Il/L- U I' ., 11 'l~'oo( II-' ''11\ I.JJOT ,I, 1 .... I: ..--WI I ....... ."'. ......, ..~~..;..-. ~ -~~ __, - '... ........ \UnT ur: I II ......"A --. ........,..... ' ,I I HI' 1- .... . I -,- I r"-lr' I 'T I I I I I I III I I I , I ; I I , . . I ' nnIT , . ...... 'M ! ;,.11 un . - I c;ca i T -T I I I I , I I . c;g\õl, I T "'!,IIf1IT. , I I I ~ i r I ' , 41 If II I L...:-- I , ; = I ~ 44 IÞOi I ' - I '- I I ~ I -. I I ...1 IfUl ..... ' I '10, I :0\ ::r: I :.... .;¡,;¡ []U, , I I I I ! ~ .' .... . .-.- :I: I I , I " ......"':.. I , , " I '- !"Ii /'"" I '\J I I I I " ., I ,",' ; I I III II ,.. ''- I , , I 10 I I / , I, ,- I : I --- I I I \ ..;;., I .- I I 1. I i . 1 II, ,.I, i I 1 ; , ..... ..... I L I 1 ~. 't-. '41 ...,.......... ~ "^'. ïi-, ., . ''}, I", I .-- .!-, r---~ ----+, I I I ~ :Joa NU[.1BER: , 0 ¡H r: -'-1~AME: i '\..-I ¡LOCATION: J "'> .... SCIENTIFIC DRILLING CONTROLS 700 WEST 41ST STRBET GYROSCOPIC DIRECTIONAL SURVEY FOR ****************** * ARCa OIL & GAS ~ *****************þ 3776 DRILLSITE 3-10 PRU DIIOE BAY ~~URVEY DATE: 9-11-79 ; !SURVEY ENGINEER: PHIL GRAFFT 1 ¡GYRO REFERENCE BEARING: NOQ-OOE ~METHOD OF CALCULATION: RADIUS OF CURVATURE ~ i i***DEPTH MEASURED IN FEET*** ¡COHMEN1IS: ; ø ~ ;, \~r ì -j .1 '.. THANK YOU ,J .. I , (' í J I J' f J ' /, () \f 6, ~;L Vi;!' r y' ,rJ '., (, ********************************* *THIS SURVEY IS CORRECT TO THE * *ßEST OF MY KNOWLEDGE AND IS * *SUPPORTED BY, ACTUAL FIELD DATA.* * ..- --~- "''''j * * \ .'>,j ¡~,. ..~, . \' l ~ * '...' , . \ * ****************~***** * * COMPANY REP~ESENTATIVE * ********************************* v .-..., -."", ~ CO~PLETioN REPORT ÞRCG 0 I L Fy GAS GYROSCOPIC SURVEY RADIUS OF CU~VATURE CovPUTSD FOR SDC BY 17 SEP 79 '..-JELL DS ~-lo- k B ELEV :14 FT JOB NO (3776) METHOD OF COMPUTATIONS F M LINDSEY & ASSOCIATES RECORD OF SURVEY, ' ALL CALCuLATIONS PERFORMED BY IBM ELECTRONIC COMPUTER V TRL-JE ~/ f ,L\ S i Dr~IFT VERTICA.L C: E P T H f~ f\! G L- E:~ ¡)c:pT~1 \.Jl.:....( '1: f'\ f",1: ¡,j r-" () 0 O.GO V 100 0 0 100.00 200 ." 0 200.:JO 'J 300 r"\ ('. 300.0C ',.1 '/ 4DC ~, , , ¿,. CO. 0;) i: v 5 C)O 0 0 500.00 600 " 0 6CO.OO ~j 70CJ C 0 700.00 .SrJCl 0 r. 200.00 v .~CjO 0 0 980.00 - '0(: \) (' lcce.GO ~DC 0 0 llca.GO 1200 '" 0 1200.00 ~.J 130C: ^ 'Î 1300.00 \J lL~OO 0 0 1400.00 1500 " 0 15üO.OO v lilt. .;" ,... - 0 C 1600.00 lDUlJ 17CC 0 r"\ 170D.OO v l8ce u 0 IBOO.CCi 1 r; 0 (J () 0 1900.00 2000 0 30 1999.99 2100 0 0 2099.99 2200 " 2199.99 , v 2300 ('\ 0 2299.99 :.) 2 L~ :J () 0 n 2399.99 t~ SlJ8 SEA -34.00 66.00 166.00 266.00 366.00 466.00 566.00 666.00 766.00 866.00 966.00 1066.00 1166.00 1266.00 1366.00 1466.00 1566.00 1666.00 1766.00 1866.00 1965.99 2065.99 2165.99 2265.99 2365.99 /{\ DRIFT DIREC DEG. N a.oaE N o.aOE N a.OOE N O.OOE j\j G.OOE N DiOOE (\1' O.OOE N O.OOE N Q.COE N ù.OOE N o.OOE N a.oaE N a.aOE N o.OOE N a.OOE N ü.OOE N O.OOE N O.OûE N Q.ODE ¡',~ a.OOE N69.00E N a.OOE N a.OOE N a.QOE 1\1 a.OOE DOG LEG rOïAL COORDINATES C LOS U RES SEVERITY D 1ST A ì'~ C E ANGLE DEG/IOOFT D ¡vi S 0.00 S 0.00 w 0.00 S 0 0 0 W 0.080 o.QO S 0.00 W 0.00 S 0 0 0 vI 0.000 O-RO S 0.00 W 0.00 S 0 0 0 Iwlj 0.000 o.þo S 0.00 W 0.00 S 0 0 0 \,'.j o.aoo ¡ ~ ¡i~!}~) ;~'~~:!l~~~,,:':, 0.00 S 0 0 o~..¡ O.GOO 0.00 S 0 0 0 \Ai 0.000 0.00 S 0 0 0 yJ a.OQO û.oo s 0 0 0 \,/ O.COO 0 . 00 S' '0 ~,cOÚ' Vi c-,,'." 0.00 5 0 0 0 \~ O.Or)Q 0.00 S 0 . 0 0 ~-J 0.00 S 0 0 0 ~~ 0.000 0.00 S 0.00 '.1\: 0.00 S 0 0 0 v~ 0.000 0.00 S 0.00 W 0.00 S 0 0 0 ~Ij 0.000 0.00 S 0.00 \.'J 0.00 S 0 0 O~..¡ Q.OOO 0.00 S 0 . 0 0 I¡J 0.00 S 0 0 0 IIJ 0.000 0.00 S 0.00 \\1 0.00 S 0 0 0 W 0.000 0.00 S 0 . 0 0 \¡: 0.00 S 0 0 0 W O.GOO 0.00 S 0.00 ~i/ 0.00 S 0 0 0 I,~ 0.000 0.00 S 0 . 0 C \-J 0.00 S 0 Û 0 'li o.ooe 0.00 S 0 .00 VI 0.00 S 0 0 0 ',"; O.JOO 0.00 S 0 . 0 0 \t~ 0.00 S 0 0 0 'vI a.GOO 0.33 N 0.2:3 E 0.41 N 34 30 0 E 0.500 0.67 N 0 .L~6 E 0.82 N 34 30 0 E 0.500 0,67 N 0.46 E 0.82 N 34 30 0 E 0.000 0.67 N 0.46 E 0.82 N 34 30 0 E 0.000 0.67 N 0.46 E 0.82 N 3l~ 30 G E 0.000 ,,.-,, SECTIí.. JISïANCE 0.00 0.00 0.00 0.00 0.00 0.00 o.OJ 0.00 0.00 0.00 0.00 0 . (',,.....,,,, 0.0 0-00 0.00 0.00 0.00 , o. CO c.co 0.00 0.40 0.80 0.80 0.80 o.ao ,6, R C (' DS 3-10 GYROSCOPIC SURVEY 17 SEP 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY 13M ELECTRONIC COMPUTER TRUE \~ E AS. D ¡~ 1FT V E R T I GAL DEP TH I\;'-~GLE D \~ DEPTH ~DO 1 0 2499.99 2600 0 45 2599.98 270S 0 Q 2699.97 2300 0 0 2799.97 2900 1 0 2899.97 3000 0 30 2999.96 3100 1 0 3099.95 3200 1 15 3199.93 3300 1 0 3299.91 3400 G 0 3399.91 3500 1 15 3499.90 3600 0 0 3599.89 3700 3 15 3699.84 3800 7 Q 3799.42 3900 8 0 3893e56 ,,' '00 8 0 3997.59 ~)O 10 30 4096.28 4200 13 30 4194.08 430C 16 13 4290.72 4úOG 20 8 4385.75 4500 23 0 4478.78 ~600 28 lS 4568.91 4700 32 ~ 4655.39 4800 31 30 4740.42 4900 38 0 4822.54 5000 37 30 4901.61 5100 38 15 4980.55 5200 38 0 5059.21 5300 39 0 5137,47 sue SEA 2465.99 2565.98 2665.97 2765.97 2865.97 2965.96 3065.95 3165.93 3265.91 3365.91 3465.90 3565.89 3665.84 3765.42 3864.56 3963,59 4062.28 4160.08 Lt 2 5 6 . 7 2 4351.75 44.4l.., 78 4534$91 If 62 1 . 39 4706.42 4788.54 4867,61 l~ 946 . 5 5 5025.21 5103-47 D~IFT DIREC DEG. S8ó.OOE N83.00!:î N a.OOE N a.oaE S38.00E S34.QOE S19.00E S31.00E S19.00E N O.QüE S34.QOW N a.OOE N23.00W N2 O. OO~'J N 2. 0 C)\~J N1O.ooE N23.00E N26.0QE N28.00E N27.0QE N27.00E N33.QOE 1\123.0oE N31tOOE N2a.OQE f\130.00E N36.00E N37.00E N37.QOE TQTAL COORDINATES 1.20 ¡\J 1.24 N 1.69 N 1.69 N 1.91 N 0.85 N 0.R1 S 2.P9 S 3.~6 S '" .76 ~"$ '"';> -- £:: . - --~ ~~~~>;~~~:;!;-:;~:..->~~ 3 . ...:21 ,,$,~ ';, ':, ~ : ~~¡~:io~¿j 7 . 7 8 rT' C 20.54 N 34.39 N 49.77 N 68.69 N 91.56 N 119.15 N 151.80 N 189.22 N 233.47 N 280.32 N 329.90 N 38~.44 N 434.91 N 484,53 N 534.2:; N 1.03 E 2.55 E 2.95 E 2.95 E 3.58 E 4.35 E 4.93 E 5.76 E 6.59 E ~jì¿~ tl)jU~'~;H~;- V5"{b 2 WË'~';; (;?¡~,;Q 9;,. '~F;'¡;, /c~ 'l.'79'E "" 0.68 W 0.28 E 4.84 E 13.46 E 25.11 E 39,47 E 56.11 E 77.71 E 101,24 E 125.11 E 153.16 E 182.84 E 216.26 E 252.99 E 290.45 E C LOS U RES DISTANCE ANGLE D ti¡ 1.58 N 40 34 54 E 2.84 N 64 0 43 E 3.40 N 60 9 13 E 3.40 N 60 9 13 E 4.06 N 61 55 1~ E 4.43 N 78 54 30 E 4.94 S 86 21 12 E 6.13 S 70 3 52 E 7.64 S 59 36 23 E 8.12 S 62 22 44 E 7.31 S 61 11 51 E 6.52 S 59 43 33 E 5.09 S 84 3 48 E 7.98 N 12 59 57 E 20.S5 N 1 54 24 W 34.40 N 0 28 30 E 50.01 N 5 33 14 E 69.99 N 11 5 11 E 94.94 N 15 20 15 E 125.52 N 18 19 48 E 161.84 N 20 17 10 E 204.56 N 22 19 43 E 254,48 N 23 26 37 E 306.97 N 24 3 9 E 363.72 N 24 54 15 E 424.80 N 25 29 38 E 485.71 N 26 26 23 E 546.60 N 27 34 12 E 608.10 N 28 31 52 E s DOG LEG SEVERITY DEG/lOOFT 1.000 0.250 0.750 0.000 1.001 0.500 0.500 0.250 0.250 1.000 1.252 1.250 3.251 3.750 1.059 1.667 2.537 3.û04 2.754 3.752 3.000 5.419 4.685 2.241 6.599 0.894 2.419 0.L+54 1.000 S f:. C T I 0 f\ DlSTAi\;CE ,,~ l.S?' ' 2.1", 2.72 2.72 3.16 2.49 1.65 Q.34 -0.96 -0.63 -0.72 -0.80 1.5Q 7.86 18.61 31.74 4 7 . 6 7~,\ 68.4~ 94.06 125.07 161.63 2.J4.54 254.48 306.94 363.55 424.45 454.91 544.95 605.42 RCO DS 3-10 E !~ S. D~ ¡ F T ¡ [~P T ~~ A r\~ G L E -.. "I ~~)c: 39 5;)~)C) 39 ;;60C, 3!) 15 570~) 40 5i30G 41 15 5SCO 45 0 6000 42 0 6100 39 45 6200 36 .L.. ~ (' '1 ')? '-' -' u v' -'-" 6 Lt C; 0 . 3 Ci 650C) 29 0 6600 29 0 6700 23 IS 6800 28 0 '~OO 27 0 ~Q 26 30 7100 24 15 7200 23 0 7300 21 30 7L~08 20 0 7500 17 3(: 760:) 14 J 770(: 12 0 7800 11 15 79001115 SC¡ûD 10 30 SlOG 9 ~?,20;) r) GYROSCOPIC SURVEY 17 SEP79 RECORD OF SURVEY ALL C ALe U L Þ. T ION S PER FOR ¡.J¡ E D BY I B i.1 E LEe ï R 0 ¡'\j 1 ceo 1'1 PUT E ¡~ TRUE DOG LEG S EVE f.¿ I T Y DEG/100FT VERTICÞ,L DRIFT DIREC bEG. TOTAL COORDINATES C L 0 SU RES DISTAr~CE ANGLE D ,VI s SU8 DEPTH £EA :\.~ 0 5215.19 5181.19 N31.00E 586.40 N 325.ó2 E 670.74 N 29 2 36 E 3.775 5292.90 5258.90 N32.00E 640.06 N 358.51 E 733.62 N 29 15 14 E 0.629 5371.03 5337.03 N34.QOE ó92.4:J N 392.50 E 795.92 N 29 32 51 E 1.072 5448.60 5414.60 N3S.00E 744 .41 N 428.24 E 858.80 N 29 54 39 E 1.798 5524.50 5490.50 N34.00E 798,06 N .465.12 E 923.71 N 30 14 2 E 1.323 5597.47 5563-47 N33.00E 855.06 N 502.84 E 991.95 N 30 27 32 E 3.783 S6ïO.CìO 5636.00 N37.0CJE 911eff2 t\Ì 542.31 E 1060.57 N 30 45 12 E 3.494 5 7 Lt 5 . 6 1 5711.61 N3S.00E 964.~6 N 580.77 E 1125.74 N 31 3 28 E 2. 39l~ 5824.53 5790~53 N24.0üE 1017.~O N 610.95 E 1187.01 N 30 S8 38 E 5.339 59C6.93 5872.93 N23.0üE 1069 . 64~N'-"-":i6:3 :3"".5 J"Er :",~ 1243 . 18 N 30 :3 8 15 E 3.015 5992.19 5958.19 N10.00E 1119.6.:ð;3~r:~>'\\\þ4B~~4J-k:;::~: 1293.80 N 30 4 25 E 4.423 6079.22 6045.22 N S.eOE 11'6 8 . 26\ r~';~~;: / ,6 ;)'6 to 4 '~; ËJ, 1 3 :3 9 . 8 6 j\J 29 1 9 0 E 1.105 6166.68 6132.68 N 8.00E 1216.27':)'!"<~~,/;'6ó2,4OZ;9;'~':CjjHJ~:l385.14 N 28 35 15 E 0.000 6254.46 6220.46 N 8,OOE 1 2 6 ;3 . 71 ' ;\ro;, 6 6 ~' ~'4 6' . Ë :''', c', 14 :3 0 . 0 8 N 2 7 5 4. 4 5 E 0.750 6342.65 6308.65 NIZ.OOE 1310.12 N 677.64 E 1475.00.N 27 20 58 E 0.916 6431D35 6397.35 N12.00E 1355.29 N 687.24 E 1519.58 N 26 53 19 E 1.000 ()520.65 6486.65 Nl1.QOE 1399.39 N 696.22 E 1563.02 N 26 27 :3 E 0.528 6611.0C 6577.00 N1S.OOE 1441.14 N 705.85 E 1604.72 N 26 5 42 E 2.349 6702.61 ó668.61 NIO.OOE 1480.2S N 714.52 E 1643.68 N 25 46 0 E 1.465 6795.16 6761.16 N 9.00E 1517.59 N 720.77 E 1680.06 N 25 24 18 E 1.506 638B.68 6e51~.6B N 9.006 1552.59 N 726.31 E 1714.08 N 25 4 14 E 1.500 S98?;.36 6949.36: N 5.QOE 1584.48 N 730.23 E 1744.66 N 24 44 36 E 2.526 7C79.59 7045.59 ¡\J 2.QOE 1611.57 N 731.89 E 1769.98 N 24 25 30 E 3.,04 7177.02 7143.02 N 2.QOE 1634.05 N 732.67 E 1790.79 N 24 9 1 E 2.000 7274.97 7240.97 N 4.00E 1654.17 N 733.73 E 1809.60 N 23 55 13 E 0.75/+ 7373.05 7339.05 N 9.00E 1673.55 N 135,94 E 1828.21 N 23 44 14 E 0.975 7471.25 7437.25 N 5.00E 1692-27 N 738.23 E 1846.29 N 23 34 7 E 0.762 7569.81 '7535.81 N O.OOE 1709.18 N 738.97 E 1862.09 N 23 22 53 E 1.505 7668.71 7634.71 N17.00E 1723.75 N 741.15 E 1876.33 N 23 15 57 E 1.053 0 ü 0 0 Q 0 i' J Sf:CT IO¡~ Û 1ST A ¡' j C E ~- 667.20 729.47 790.97 852.83 916.67 983.90 1051,25 1115.05 1175.96 1232.59 1284.38 1332.12 1378.91 1425.16 1471.05 1516.35~, 1560.4~ ' 1602.60 1641.97 1678.77 1713.12 1743.99 1769.54 1790.52 1809.43 1828.12 1846.24 1262.08 1¿76.33 r f > ~ ¥ i ! ¡ ¡. ! l ~ ì' t ì r t ~. t .. ~r i-: i- t t /\ f~ c: 0 DS 3-10 GYROSCOPIC SURVEY :17 SEP 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY IBM ELECTRONIC COMPUTER TRUE ;' ~ à. S 6 ~) r-z 1FT V E r-~ TIC A L DEPTH ANGLE DEPTH "'" þ '....i '\-..--0 0 6 30 P}¡400 r:. "\ .,/ "" 3500 c::. ,j .... '.,J 0"- r. (ì 4 30 ',:'00,",,' 8700 4 0 8800 2 0 290() 2 30 9000 2 30 9100 1 45 9200 1 30 9300 0 0 9400 0 !Î v 9500 0 30 9600 0 0 9700 0 0 r .. >30 0 0 ~~ :I¡ 7767.90 7867.40 7 9 6 7 . 0 2' 8066.67 8166,40 8266.21 836EìIt 10 8466.00 8~65.93 8665.89 8 7 6 5'. 8 8 8.865.88 8965.88 9065.88 9 16 ;; '. 8 8 9245.88 BOTTOM HOLE CLOSURE SU8 SEA 7733.90 7833.40 7933.02 8032.67 8132.40 8232.21 8332.10 8432.00 8531.93 8631.,89 8731.88 8831.88 8931.88 9031.88 9131.88 9211.88 DRIFT DIREC DEG. N14.00E N13.JOE N16.00E N16..00E N19.00E N2S..0QE N48.00E N40.00E N27.00E N18.00E ,N O.OOE N O.OOE N S.OOE N O.OOE N o.OOE N O.OOE TOTAL COORDINATES C LOS U RES DISTANCE ANGLE D tV: 1735,91 N 744.52 E 1888.83 N 23 12 51 E 1745.65 N 746.86 Ë 1898.71 N 23 9 47 E 1754.08 N 749.04 E 1907.32 N 23 7 25 E 1762.04 N 751.32 E 1915.34 N 23 5 35 E 1769.11 N 753655 E 1922.92 N 23 4 17 E 1774.70 N 755.98 E 1929.01 N 2~ 4 22 E 1778.U7 N 758.92 E 1933.63 N 23 6 33 E 1781.þQ N 761.95 E 1937.70 N 23 9 19 E 1784.~9 N 763.99 E 1941.34 N 2~ 10 29 E 1787 . 3~.,rN.."'".",,7 65~.p8o;'.E,., ,;,' 1944.1 7 N 2:3 10 26 E 1788. 5+9~~~.B';~\:';} 6,'\~ 28 t:;"'"19 4 5 . 44 N 23 9 52 E 1788. 5'~9~ N':; jJ j765.28<E';':~ 1945.44 N 23 9 52 E '\ :.~'C ~-_: 1789.03<N':'"~"i765.30,,:,E..; 1945.84 N 23 936 E 1 7 8 9 . 4 6"/N'-'~' - 7 6~":3 i 'É' "0-: 1 9 4 6 . 2 5 N 2 3 9 1 9 E 1789,46 N 765.32 E 1946.25 N 23 9 19 E 1789,46 N 765.32 E 1946.25 N 23 9 19 E 1946.25 FEET AT N 23 9 19 E s DOG LEG SEVERITY DEG/IOOFT 1.500 1.500 0.261 0.500 0.500 1.000 0.501 0.349 0..750 0.250 1.500 0.000 0.300 0.500 0.000 0..000 SECTION D 1ST A,'~CE ..-...., l888.8~ 1898.71 1907.32 1915.54 1922.91 1929.01 1933.62 1937.70 1941.34 1944.17 1945.44 1945.44 1945.84 1946.25 1946.25 1946. ?Å\ Þ.RCO DS 3-10 GYROSCOPIC SURVEY 17SEP 79 INTERPOLATED TRUE VERTICAL DEPTHS. COORDINATES AND CLOSURES FOR GIVEN DEPTHS CODE ¡'J Þ. :".-¡ E TOP S¡.\D BASE SA,D '~ ~. ¡\:iE.4SURED DEPTH 9185 9650 TRUE VERTICAL DEPTH 8650.90 9125.88 /\ g I ¡; J ., \() (,7 /(¡ I /' I {lb u / C LOS U R E DISTANCE ANGLE D f\1 S SUB SlA TOTAL COORDINATES 1786.93 N 1789.46 N 1-11 ~/j,?, '~¡;~,- j:) :¿ 764.95 E 765.32 E 1943.78 N 23 10 29 E 8616.90f f1-J~1 1 9 46 . 2 5 N 2 3 9 1 9 E 9 09 1 . 8 ö Æ- / (y~ Z-- ,"-" -~, ARca DS 3-10 GYROSCOPIC SURVEY 17 SEP 79 ~EASU~ED DEPTH AND OTHER ~ATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE f~/; E 1\ ~S lJ R ED VE[~T I CAL SUB ~'iD-TVD VERTICAL DEPTH DEPTH SEA D I FFEREr'JCE CORRECTION TOTAL COORDINATES 134 134. 100 0 0 0.00 S 0.00 Vj 234 234. 200 0 0 0.00 S 0.00 II! 334 334. 300 0 0 0.00 S 0.00 'tJ ,-.\ '-" 434 434. 400 0 ,... 0.00 S 0.00 'vi u 534 534. 500 0 0 0.00 S 0.00 Iii 634 634. 600 0 '" 0.00 S 0.00 hi v 73/+ 734. 700 '0 0.00 S 0.00 Vi 834 834. 800 0 0.00 S 0.00 I¡J 934 934. 900 0 0.00 S 0.00 W 103l~ 1034. 1000 0 0.00 S 0 . 0 0 ~'J 1134 1134. 1100 0 0.00 S 0.00 W 1234 1234. 1200 0 0.00 S 0 . 0 0 \'J 1334 1334. 1300 0 0.00 S 0.00 ~\i 1434 1434. 1400 0 0.00 S 0.00 \v 1534 1534. 1500 0 0.00 S 0 . 0 0 ~\, 1634 1634. 1600 0 :: ,0 . 00 S 0.00 \,."i 1734 1 7 3 1+. 1700 0 0.00 S 0.00 \!J 1834 1834. 1800 0 0 0.00 S 0 . 0 0 v; 1934 1934. 1900 0 0 0.04 N 0.01 E ,.-, ~ 2034 203"". 2000 0 0 0.47 N 0.43 E 2134 2134. 2100 0 0 0.67 N 0.46 E 2234 2234. 2200 0 0 0.67 N 0.46 E 2334 2334. 2300 0 0 0.67 ¡\j 0.46 E 2434 2434. 2400 0 0 0.77 N 0.49 E 2534 2534. 2500 0 0 1.18 N 1.60 E 2634 2634. 2600 0 0 1.37 N 2.89 E 2734 2734. 2700 0 0 1.69 N 2,95 E 2834 2834. 2800 0 0 1.78 N 2.99 E 2934 2934. 2900 0 0 1.48 N 3,91 E 3034 3034. 3000 0 0 0.55 N 4.53 E 3134 313L¡.. 3100 0 0 0.89 S 5.15 E 323l~ 3234. 3200 0 0 2.71 S 6.11 E 3334 3334. 3300 0 0 4.19 S 6.93 E 3434 3434. 3400 0 0 3.ó5 S 7.24 E 353lJ. 3534. 3500 0 0 3.83 S 5.90 E I\RCO GYROSCOPIC SURVEY AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. DS 3-10 >;EA.SU¡':?ED DEPTH ¡RUE ¡V¡EÞ.SURED VERTICAL SUB ~I¡D-TVD DEPTH DEPïH SEA DIFFERENCE 3634 36::-ú.. 3600 0 3736. 3 7 3 1+. 3700 0 3835 3834, 3300 0 ''"-'' 3936 3934, 3900 2 4037 403Ltt 4000 2 4132 4134. 4100 4 4241 4234. 4200 7 4345 4334. 4300 11 4452 4434. 4400 17 1-+ 5 6 1 4534. 4500 26 4675 4634, 4600 L~O 4792 4734. 4700 58 if 9 1 4 4834. 4800 80 5041 4934& 4900 106 5168 5034. 5000 134 5295 5134. 5100 161 5424 5234. 5200 190 5553 ,5334e 5300 219 5681 5434. 5400 246 ~ 5813 5534. 5500 278 5951 5634. 5600 317 60PS 5734. 5700 351 6212 583[+. 5800 378 6332 5934. 5900 398 6448 6034. 6000 414 6563 6134. 6100 429 6677 6234. 6200 4l~3 6790 6334. 6300 456 6903 6434. 6400 469 7015 6534- 6500 481 7125 6634. 6600 491 7234 673{+* 6700 500 7342 6e,34. 6800 508 74~e. 6934. 6900 514 7553 7034. 7000 519 VERT I CA.L CORRECiION c 0 0 2 0 2 3 4 6 9 14 18 29 27 32 39 34 27 20 16 15 14 13 13 12 10 0 J 8 6, k ~ 17 SEP 79 TCTAl COORD Ir'lA TES 2.9~ S 1.60 f\J 11.94 N 2 5 . 5 2 i\~ 39.68 r~ 56.46 N 77.61 N 103.27 N 135.46 N 17¿~.O4 N 221.58 N 276,,72 ;\j 7.49 N 4.86 N 468.74 N 31 . 74 N 99.33 N 667.91 N 734.42 N 805.21 N 884.54 N 9 56 . l~ 1 N 1023.95 N 1085.75 N 1143.12 ¡\) 119B.32 N 1252.7B N 1305.52 N 1356.60 N 1405,87 N 1451.02 N 1493.21 N 1532.46 N 1568.39 N 1599,51 N 5.65 E 4.18 E 0.53 E 0.67 '\\' 1.44 E 7,76 :: 17.89 E 31.27 E 47.78 E 68.35 E 95.83 E 122.99 E 157.22 E 195.83 E 241.15 E 288.56 E 333.43 E 376.27 E 421.28 E 469.93 E 522.73 E 575.18 E 613.72 E 639.70 E 652.28 E 660.27 E 667.92 E 676.68 E 687.52 E 697.51 E 708.39 E 716.77 E 723.13 E 728.55 E 731.34 E ~ ,.-..., AG:CO DS 3-10 GYROSCOÞIC SURVËY DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. ;/E.tl,SLJ;~ED Tf~US r,,~ E ,L\ SUR E~) VERiICAL SUB Ì'/¡D-TVD DEPTH DEPTH SEA DIFFERENCE 7656 7134. 7'''''('\ 522 J..vv 7758 7234. 7200 524 7860 733L, 7300 526 -",_'i/~ 7962 7434. 7400 528 806Lt 7534., 7500 530 8165, 7634. 7600 531 826ó 7734. 7700 532 8366 7834. 7800 5:32 3467 7934. 7900 533 8567 8034. 8000 533 8668 8134. 8100 534 8763 8234. 8200 534 8868 8 3 3 L¡.. 8300 534 8968 8434. 8400 534. 906-3 8534. 8500 534 9168 8634. 8600 534 9268 8731+if 8700 534 936f3 8ß34. 8800 534 91+6 S 8934. 8900 534 "~ S 562; 9034. 9000 534 9668 9134. 9100 534 9768 9234. 9200 534 VERTICAL CORRECTION 3 2 2 2 2 1 1 0 1 0 1 0 0 0 n .... c 0 17 SEP 79 TOTÞ,L COOf~D INA TES 1624.56 ~~ 16'+5.88 N 1665.82 N 1685.29 r-: 1703.34 N 1718.92 N 1732.02 N 1742.61 ¡\) 1751.30 N 1759.51 N 1766.92 i\ 1 7 73 . 1 2 ;\j 777.45 N 780 . 5 5 ¡\J 1783.77 N .,: ,1 7 86 . 49 N 1788.45 N 1788.59 N 1788.79 N 1789.42 ì'-! 1789"1-6 N 1789,46 N 732.34 E 733.21 E 734.85 E 737.53 E 738.89 E 739.91 E 743.52 E 746.15 E 748.27 E 750.óO E 752.82 E 755.18 E 757,89 E 761.03 E' 763.50 E 764.79 E 765.32 E 765.28 E 765.29 E 765.32 E 765,32 E 765.32 E ,.-..., ~ /~RCO DS 3-10 GYROSCOPIC SURVEY 1 7 ,S E P 79 INTERPOLATE0 VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. TRUE ~\iE A.SUR E D VERTICA.L SUB DEPTH DEPTH SEA 1000 1000. 966. 2000 1999. 1965. 3 C)OO 2999. 2965. úQOG 3997. 3963. "-" 5000 4901. 4867. 6000 5670. 5636. 7000 6520. 6486. 8000 7471. 7437, 9000 8466. 8432. ............. TOTf.\L COORDINATES 0.00 S 0.33 N 0.85 N 34.39 N 383.44 N 911642 N 1399.39 N 1692.27 N 1781.60 N 0 .00 VJ 0.23 E 4.35 E 0.28 E 182.84 E 542,31 E 696,22 E 738.23 E 761.95 E -~, ~, (~ 4 ( . ~~,. ...-....,..",..,,"...~... , -,. '. "''''''''-''''''''''''''''''....""".-..,.........-,. ',:_""" ",..~. ," " ARCO OIL a GAS DRILL SITE 3-10 GY ROSCOPIC SURVEY RADIUS OF 'CURVATURE SCALE: I": 500' SEPT. 18, 1979 .,..,' """''''-''''''''''''''''' . ...., '~'.'"''''''''-'''''''''''''''''''''M''''''''''''''' -'-....."..... , ".""""..,..... """,-,,,,,,,,,,,,,,,,,.,,,,,-...., ,-.-. -...'.., ..,.-,,' ,-.-. , .. ALL.;.., DEPTHS, ARE' TVD. "",''''.''~',.,,~~ """"'-",'-""""''''''''..,'''''''' ..', , , '"',-., '.' ..._"..,. ~ 'W'"...,.."",~_.. ..,...... """-""'-''''''''_'_'n.,"..~.""" ..r._......."....,......",....... ,. ''''''''''''';''''''--'''''''''''''''''''''''''''-''''''''''''''''''~---''''''''''''''-',-. ..".,~".- ~"._..,.~..... '... '.,., ."",- '''-~'''''' .. ......- """'-"'.........--. .---. ,--~~'.... ,- .,.,\,..~,,,, ,--.......,.....- .....-.~~ . . . _......_"......._.._.~...._^ --"'--'-'._''''''''~'''''-' ,... .- ~,~.-.,...- ,_...,,- ."""-'~'" """. ---...... ._......-,~.._-,.....-.._-_...."...._..,,,......,,...,..,, -,"'-""""'...""'..'",,,...... '''''"'''''.''._.'.,~....-''. . . ..~,.."... -" ..~ -... ,---,--~"---'" .. "., ""'.~ . .~... '-""'--~"'~'~"~""--.'_.''''~'- . .. '~'...-.m'" ...~. .,_..,.... ... -~ ..-.... -," . . "'.-.-'.--""""-' . i _.....~..-... "'".''-''' -"-",-,,,---'--.' .-.....---......--------............ -... .....~ ""-'~_W'-'_.--'-'--"- "---'''''-''''. ,--",-4._~.~'--. ...---. ..... ._~.-----_._----- --_._...-.~...".. ......_~- .. ... .,..~ ...."...... '.'" ~~.......- ......_, , . .~~.... ---. -"~~ --"~""~''''''''.''' . ~_. _h- --." "'.U '.- . "".'-'~-'_._-'''''-'. . ~..... ._.....~ ........... .- -. --.--.-..---,- . !~' .--..'._'--'-." -~ ... -. ~ .-. . ""r-''''''''.'-''-' ..... "-'-'.-- " "..-"...-.---- , ._---_.._--.__._~.. -.- ...-.. '~'_.'''''-'--_..._-. .-.. -.-- --- --.-----~-~._.._.._..__.... ....-...... ,.-.-.. . ... _.,~....~.. -...,.~ ..~ ----....- .. ~ . . -". ..- ". ... .. '. '."".-"-""-- ._.,,~ ._. .--,.._~----, - - - '- ~~....-._--._--------- '. .--"-~ --'-.--'--""-------'------- ~.- _....._~-_._- --"-_.~-"'.'--'._"'R -""'''''-------~_... ,.~ .. '--'.....-.'. .. ~: . . ¡ ~. "-..."-'''''- -,- ~ . -'..1'" i . ... -- - t ~- "._~,_."..~"'_.- 0" - ." ~~.'--"" -"'---.'-'__''''''''_0-'- ----. -- ---~ --.w _.-.-<.._.- - ---- ."--------..--. -- '.-__h____~_'--- .-"--~---~-" ._..._....~.....-_._.. 0- t .._..~.,.. ...~ _.~ C' J, ~.~~-~~~~__I:=~~=- ---c._u )- . '''.''- ~'--~"'~'.''''''''''---'' , I .. ..~ /, "-,'~'] , I "--I' ~---..). .. -' .-..\ - _.~.. ...~._..... ~''''~' . ..._._-....-_.~. - - ,. "...~.__.'- ..~" . " . "-"'~"""-'''_.'-_._-'''~'' ..~"... ....--... ,,,.., .- .-. ,-,',,,,,.. . . ....,,--....._~ .~.".,---..._--_..._._-....,."...."''' è. , (". .( 800 ARCOOIL8.GAS DRILL SITE 3-10 GYROSCOPIC SURVEY RADIUS OF CURVATURE . SCALE: I":: 10001 SE PT. 18,' 1979 ~. . .......-.....0...,.,................................... 400 '''''''1''''''''''''''''''''.''1'.'''''''''' "''''''''''''''''',1...... ,,,,,,,,.""'''''''.''''''', ,'..-,' ,/0- '~" "".."_..,-".~,..~......,...I',...,....._...-.......,'.,,. -. . -.' """ ,.""."..- ,'."--'''~''''-- .-''''''- '.., ....... '" .,..." ~"....,.,.~,,,.....,._..._...., '_e....._..........-",' '-"""""""'."""''''''''''~''''''~'¡'''''''''''''''''''"'''''.'''''''''''_'-'''''' ....."."", .",'. '.",. . , ,.. ......"-..,-.."....',.......-.......-,...,...,..-,-.--",.,.....",,,- -' "'"'' "',"" '.'~..."...,...... ..,.....,~...~..... ...'~,.....-.............,_......_~.'-.. , .. "'."""~"'~-"''''-'''''',,,,,,,,,~~-,,,,,,,,.,.,,.., "-00l'00o- "-T .~...-.. ,--"''''-.-..- .... ,~"""",,,,,,,"~'''''''-'"--',_' .... - ""W_'--- ~--. 7200 -:- ¡. ----. --- - ----- -- ----~~--:_-:~-~60~x~4== . ....---.-.--0"-,,,---'-"--"-'-'."".--' ...... 8000 ,"'" -- ." ...... ---_.._-...-. . . "'1 .r 8400 T . ..-" "'''. . ¡ . . " ._..._..~._--_..._~. .... ....~~=.~~I~LI.~t , . ... ". ... --' ....t i.- ~:.. ~:;.",," , .,. .....~ "n.,'" . ,..---....... _.._,~......- ...--- ,.......-..-...,....,._._0''''''' . """",,-,-'......c....-., -,-,,~., .. ~'''"'..._'''----.-'--' ..",-"... ~--." -. '-"""---'''--'W'-' I ...' ,-,--" ", ., ~ ~.".. '--.--""---' ~.,.. '.- .._......_0_- '"-. ¡ 8800 - . r - . ...-~. .." '-'--~-' -------"'-."'_'-0..-"...- -.... "-'-, ...-. . .. ---'''-~~'--r'' ._- .. . 9200 ..:.- \ . ..._--_._...~- ,..- 0"'.....-..- . ~.. ."- .".-"'- ---_.. I .....~_...----- (',,' .I" , . ~ .'-..' "-",. '.".. - è J--' . .~.-"'... ....,......-... '-" '",,_.. .~. . j> ---------_:-:1 " ¡ .... ........'"'" ".-f- j" .. . TVD = 9246' TMD = 9780' . )~':.:'~':-.'~.~~-. ~:.._- . - .-.-.-.....------"'--- .- { ( LOCATED .IN THE. APPENDIX DWFL DIPRLOG. . 0 CALIPER SURVEY 0 VOLAN 0 CURVE DATA 8 STRATIGRAPHIC ¡lHIGH RESOLUTION DIPMETER 0 OTHER: Post GWt loX 368 AnChO!'J(~;, l;ìSi<(l ~,:~J:.;10 T c h::p h 0 n r; .:CJ ï 277 ::if):: ì ~¡ ,/.J \':\ .,(.,,..' '"" :,'~: """"'."':J ',_c:-,- '. ", .., (,~ý ""':{/ I ,J[ li") (\!{'I~;:\:: [)¡,,~ ¡~:t (' October 16, 1979 Reference: Enclosed are Open Hole Logs for the follmving .A.R.CO wells: 1VGI # 1 7/27/79 TT If FDC/CNL FDC/GG BI-I CS DIL CPL RFT 2!T & 5" 2'! & 5!'! 2!! & 51! 2!'! & 51! Sir 51! & 251! II " t! " I! I! ~"D:dŠ:-3~ / 31/ 79 ~-"::"-,-,,,...~.,,,.,",,,,,,,,.,,,,/J " /hease sign and return the attached copy as receipt 1/ of data. K. J. SallIs tram North F~gineering TRANSMITTAL ft 408 f) r: ,,"'''' [ f ~ \;, \.. L.; lC, , I I. ( II.. ,f. C') /. I '. ,., /.-~,! ,,' ¡.,.. ,'\. 't I n:rSTRJBlrrIO~: North Ccology Lxxo[l IJri 11 j ng 0!ohi 1 Lng. ~;~:lI1agcr . Cotty E r, D Sohi~ Ccology 0!ar(1thon St~l te of A In.sKa Ph ill ips J) (1 01 Chevron d'¡;":é:~~"--r- ;' I ,l.I¡ ,.1 ,i ~"--:, /2...y ,.~' ~'- !.,~,......" ", ,~;,.;,I'. J ""'.....~\ , " ...---;¿:-~~ ...,.~ " ."\~r ~':¡'~ li.:: ~~", ¡ :~: ~ ,;(: ,.-;.:! (~(~-:: ~':~ f) J ìì Y NOi':i1 ~,n:<:.'ric.'1n F'foducins Di\!;~;!Of CCV\M._- . ..-- \ C, .J\M- --.--- \ Cc; MM -,----'---'r-'- :~-.lG \ RCj L,I --- --' \ 1 ENG- -r-2ENG.___- ---'-r'3 t f'J? '-T- 4 ENG- --I 1 GEqL \-2 GE<?~ ----I 3 GEOL --- \ STAT TEC '\__?!~~~_TEC \~~¿NF{R~ 1 .--- FIlF: ~Jorth AI-'" l!S~rict P,., ~t 01f( " ...,roo \,..;.;::, ~ t " ').." d C) (' Anchor:Jgf:, t:.I('):;~"~,.1 9:):; !~) T,~ kplï ()nc :~:? ?'"U ::;~ì:n October 8. 1979 Reference: FMc10sed are Open Hole Logs for the following ARCa wells' D.S. 3-10 " 8/31/79 Continuous Dipmeter Run 1 5" " FDC/GG Run 1 5" 11 FDC/CNL Run 1 5" I! CPL Run 1 5" " BHCS Run 1 2" & 5" I! DIL Roo 1 2" & 5" " !! IT " ~se sign and return the attached copy as receipt of elata. K. J. Sah1strom North Engineering TR4.NSMITTAL # 390 ~~ ,1"" :'" ,r. .,' . ,'';.; ¿(,~" ,~ -.,-:; '~,., (T",:",o- "..::~1 r;" "1 ! çz~'Æ f c 1",,', E,C EJJII~4L' - é/ ~7¿-U . Alaska Oil ~ ,. . 1979' ~ & Gs I . )!¡nchora'~ g" :,' .:.1 (" '.: I . " . 11 <.;, . . ' ...' . 'o('/ì , DTS'J'[ZI¡:;rr['TO:\ :-Jorth Ccology Exxon Dr:ilJing r.tohiJ, En,g. Ì\!anager Cotty R E¡ D Sohio Ceo lo¿,;y f\Iaratllorl St(1tc of Alaska Phillips D (I Ì'-[ Chevron " ( : "'J:';, . i :: ¡ \..: ~ ¡ ; i :~: ~¡ c: ç,} i~~¡ r,; ~,l ;1 ~.r 01 () r ~,;"! ':'" ¡ ':,:,1 r' ; i ':: ~:!;'"1 }'J ¡' ,:~" : ¡ I.; ~; i 1'1 CJ f',l i ¡ / i ";~ j :) ~"1 t,:Ü¡'(;1 t\l( nL:;~i"i(;¡ r'\.'J~)t o~n"... ,'):~ :,)::;0 ( ( ¡.\ n G f ~ 0 r a ~ l ::, ,.:\ ¡ ,.~ ..: :.: é1 :J~) >~) 1 (] ~rr~¡~'~';--)!:,);! :-.' ~~(.:? ~~~~? ~:;~;~.~~: Octobcr 3. 1979 Reference: Enclosed are Directional Surveys for the following p.J.~CO '\.ve11s ! ~ lllGI ÎÎ 3 WGT H 3 ~ease sign of data. 9/11/79 9/24/79 9/21/79 Gyroscopic Scientific Drilling Controls f! Sperry-Sun Magnetic 1\Jul tishot Sperry-Sun and return the attached copy as receipt K. J. Sahls trOTH North EngineeTing TRANSMITTAL if 389' /7 N) r if'" F' r \ f 11'. r... ij\"~,, " d ''',,',11 í~. q, "I' ~.,....... ~ l1.i! r/ \I., ,. J i ",' , - ',., &:.... .\1.,....,!:1.. II , ~-,.c. /'" .. '~""" ~ Vv ~" . , ' ,'. (;(''1' "i "? '~If',r'(:'~ " \.J \.: .,~,. t !.~)I: \i AI&jsJ{a Oi¡1 GOi¡i,n¡:;:c:;lon AnOhora¡;Ir¡¡ Tn S' I']<J B U'j' .I n>'J 1'<01' th Ceo 1 ogy l,:,'\xcm UriJ 1 in::.), '~¡ohìJ .Eng. j\bni.15.!,c:l' Cc Ltv l( è¡ ]) (' t." .)()11 J() CcoJ og)' ~.hra l-!1oIJ St:rLc of !\ l~lska 1 . 1\ uJ 1 ip::, ]) r¡ ¡\1 Ch cvro.n } ARCO Oil and G{- 'mpany North Aias¡Ù. _)¡strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 8, 1979 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Subject: Core Summary, Drill Site 3-10 Commission Dear Mr. Hamilton: (, \ CÕ~Mi'j\ I 'COMM ~ - ~ll~~S=R' --~s¡\f:./~, , _.-, ;~, I:¡'.:_. ". :~_l..E~jG J? 't ~-2~,NG.;¿~._,,~ ."'". I 3 E~.::3 -[4 ENG-- 1 GEOL 1--2-GE~ - -àsËÖL ,... 5T /\ T TEC--- -~,ßJ 'S~_\T TEC'- i I CONï=ER~- -'."'-.0.-'_- FILF: Enclosed please find the Core Summary for D.S. 3-10, submitted as Item No. 36 on Form P-7 for the above well. Very truly yours, R~~M Sr. Geological Associate RWC:GSL:kdm Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ~ Af~{,: .. "'''''~''JJ{~~I ,ç t ( ( DRILL SITE 3-10 Sec. ll-T10N-R15E, UM ARCo Oil & Gas Co. CORE SUMMARY Core Recovered No. Drilled Ft. % Lithology 1 9130-9189 61 100% Shale, mudstone 2 9191-9249 58 100% Sandstone 3 9249-9308 59 100% Sandstone, shale 4 9308-9362 53 100% Shale, siltstone, sandstone, conglomerate 5 9362-9397 32 91% Pebbly sandstone 6 9397-9455 52.5 90% Sandstone - 7 9455-9513 55 95% Sandstone, siltstone, conglomerate 8 9513-9573 58 97% Sandstone, siltstone 9 9573-9631 57 98% Sandstone 10 9631-9690 59 100% Sandstone, siltstone, shale I' I' t ARCO Oil and Ga",f Company Nor t h A I Z1{ .) i s t r i c t Post Offic\ ::>x 3':;') A n c 1'1 0 rag (>, A I J S k é1 99 51 0 Telephone 907 27ï 5537 \ A~ ~.' ~~ SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska Division of Oil and Gas 3001 Porcupine Dr. Anchorage, AK 99501 Attn: ~ID. Van Allen . DATE: Conservation October 5, 1979 OPERATOR: Arco NAME: Dri11site 3-10 s~œLE TYPE: core chips NUMBER OF BOXES: 10 in 1 large box s~.œLES SEN.T: 9131)-9190 9191-9249 9250-9307 9308-9360 9362-9393 9397-9454 9455-9509 9513-9571 9573...,9620; 9631-9689 fi) <YCtrf~ : - '17 {~ B-1 '1\( (' c.. 5' (' , 9625-9629 c"'- t-f'0 SHIPJ?ED By:1&'~a, j ~,~ C1~J()ú (i.eLf) . ~ RECEIPT OF THESE SAMPLE~ PLEASE NOTE ANY DISCREPANè~ES AND ~IL A SIGNED COpy OF THIS FORH TO: . (¿cvr C /A.~/5 PIA fJ Cc; (f~c- l(" J - jI,-o ARCO OIL ~~D GAS CO. P.O. BOX 360 ANCHORAGE, ALASKA 99510 ATTN: DICK BROOKS r~ [ C E.f V E D lICT [) 1919 /) / 'i) ¡} (~ì- ~/ RECEIVED B{£,z/.'L,(!J(~,- ? ;t~ C&1.~ , Alask?- Oil & Gas C(I,I~;, Gomm/s,;¡: !,ndwrqo '0 / cj/~/c¡' DATE ' / :'RCO ()¡, Jnd G3S Comp<Jn¡IS a Division of AtlanticRichfleldComp(lny PO,Jt OJ" "',' !:)O:~ :180 "hch"'( ,', ,,,,,""" 0':)" '0 .'-\;. ,\..' ' , J, t,1":;:"\. -...J:':) 1 ( '\ / ..j, .~ ~'"-" ' '. ~ê, 0"., .,M'-, " "'.^" ¡" ':::'~:<~~~"/', \,~',". - "'.t",,' \, ,. "'" v' , .." I. \1 ,i C,OtoMv\ "':.' :'~'; /: ~OMM ~", 7 ¡ ,1:¿!'S'f}jI:- ¡ : 1 r. .., J''-. ¡" ,,;\ ',; .,i i i 2 Er'::-:- J ì ~.-- i 3c;. i "=.... i I 4 r:~,JG ¡'Ai r-~ .- ! M- 1 ,:¡;:OL ¡ -,_.. ,"'? r: ,~~7; ---, )'--/ :; ;;~O('T' ¡ I ST',T T[C' , 113 I §_T:~~_T-§f~~: " I . .__h'. ~ CONFER: / FILF:---'-- j" ,. .1 ¡ I \ I ; J .,..: I [)! '.l ì ; ,': I .r,~:I.:'pr1C~' . ; SC)7 7.71 :~ìGlï October 2, 1979 Reference: F:J1Clos.eè. are Cased Hole Logs for the following AECO ,'ælls: D.S. 4-13 5/1/79 D.S.~' 7/31/79 l',::1!;:[~:."~":~~Q,,,, ,.' 9/11/79 D.S. /-j 9/5/79 D.S. 9-18 7/26/78 Continuous CCL/Perf. C,NL Sp iImer Continuous Flow Survey Flow Survey S!I, 5" 5" 5" Sf! ¿,/Íéase sign and return the attached copy a.s Teccipt . of data. K. J. Sahlstrom North Engineering TRJ\¡\JSMITfAL It 383 ""'-'7 ; ...' '---'''f¿"~/--,." I . /L ¿2:;:'~ ,. .é:,.~~'" ,.' , " " '. {- ~-?Ç:~ , \~' ':"l.\ ,,--......., c. (.' <J (è L" I') r S'J']\T .\1,rr [0\ North c;':~ology Lxxor 1 UrilLi.!1g, Ì\!ohi' Ln51.. Ì\!Cf!l~lgcr Cc l: ty H é; J) Soh Lo Gco~! o~~y ~b fit thon Stfltc of i\laska P11 i llln::~ U é~ 1'. Chcv n)~1 ;\ \ ¡ ~: n : ¡ c; R i ç h ¡ j c: i:~ C -.:, ;~ì P Q íl Y North J'di1( North Alas;t ( \ n P r':1':! u ,.:;j 11 s¡ D ivisÎ on )!st¡jCÌ Po~t Ofi¡ce Box 350 AnC~1Oré1ge, /d83;,<1 995! 0 T~':j~p¡:Oiì~ 90ì 2?7 58.1; September 7, 1979 Reference: Enclosed are ARCa 1'1e11s = ~~~;¡;) . WGI 2 . ~Sign of data. Directional Surveys of the following I COM~ ~'" ~:. J<,I ..-.. I ,', "', ~,I, COMM""" " /:': :;:,~:~:. _G:°MM'-' . 6,-:' "':::~;; I Rr'" r, .,' "~.... ,'" :è'. ,:::' l.y.I'--, "'< ., ',' ;', ¡'. ., .. ,..:,.:.;:.: --. , '" :. 1 ~,...r' I 1 FNG '. . :.,;' -,-- .-, ;-. "'''i ~ _.,1. 2 EN;~, I .,.. :'J' -- -..,..1 : '-"'" I 4 n,JG ~I 1 G:~OL --, _1'--2 G.t.-~, . I .... ......'i:: ,,' ,-:::,;..Ol --I STAT TcC-' 7!i I STAT TEC- ./ CONF'Ër I=JlI=;------ 8/31/79 Magnetic ~fu1tishot Eastman \~ipstock 9/1/79 Gyroscopic Eastman 1Vhipstock and return the attached copy as receipt Very truly yours, K. J. Sahlstrom North Engineering a !5 fr;¡! v'hf' '-V 4ê~ '.W [:it:',P 1 ~ ~Ð ..,~\ C~47 A/ask' , t,., Q (n¡ '* t).~n- . ,J ,. II r: AI1!J!1()t~fJ~l ""';ll/tI/iSt;fon TRÞui\JSr.UTTAL # 319 DISTRIBUTION North Geology Exxon Drilling Mobil Eng. Manager Gcttv R 6 D Sohi~ Geology Marathon State of Alaska Phillips D [I M Chevron . " e"'''' Y"" ARCO Oil and G ' ompany Alaska Re( Post Office box 360 Anchorage, Alask::¡ 99510 Telephone 907 277 5637 September 4, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subj ect: \,>",~WJJl-,"#2G~.~ermi ~ No. 79-43 i~" OS 3- 1 0 ) Perml t No. 79- 21 i': -'"ÕŠ~''''r2':''3~''' Perm; t No. 79-41 Dear Sir: if ( OS 14-6, Permit No. 78-65 OS 14-8, Permit No. 78-67 CPF-1-23, Per~it No. 79-42 Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, r/l. -zI~~ P. A. VanDusen District Drilling Engineer PA V: j h Enclosures ABCO 011 and Gas Company Is a Division 01 AtlanticRlchlleldCompany R E eEl ',," ;: f)" ~. .tv (~ ;. P1 "', ~t)"7~) ~. -, ... 6{,' RN ¡1 t,I;:;$!~a OJ, R. (;, ' ... ~ b tJ'I:. 'J" , ~" ~ A","', "'I ,,',. ('OIl!/ìHfision 1It;J!1fJfF.!O? Form No. P-4 REV. 3-1-70 (' STATE OF ALASKA SUBMIT IN DUPLICATE l 01 L AND GAS CONSERVATION COMMITTEE S. API NUMERICAL CODE 50-029-20361 MONTHL Y REPORT OF DRILLING 6. LEASE DESIGNATION AND SERIAL NO, AND WORKOVER OPERATIONS ADL 28328 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL ŒJ GAS 0 WELL X WELL OTHER 2. NAME OF OPERATO~ 8, UNIT FARM OR LEASE NAME ARCO Oi and Gas Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO, P. O. Box 360, Anchorage, AK 99510 DS 3-10 (23-11-10-15) 4. LOCATION OF WELL 10, FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil 11. SEC. T, R, M. (BOTTOM HOLE 21341N & 6381E of SW cr Sec 11, T10N, R15E, UM OBJECTIVE) Sec 11, T10N, R15E, UM 12. PERMIT NO, 79-21 Poc 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND' ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS, Report of Operations for the Month of August, 1979 Spudded well @ 0300 hrs 8/8/79. Drld 17-1/211 hole to 27501. Ran 13-3/811 72# L-80 csg w/shoe set @ 2730. & FC @ 26481. Cmtd w/50 sx red dye cmt, followed by 400 sx experimental cmt, followed by 50 sx red dye, followed by 4000 sx Arcticset II cmt. First 500 sx including red dye cmt was part of sur cmt experimental tst. Installed & tstd pkoff, did 20 sx top job. NU & tstd BOP. Drld shoe & 101 new hole to 27601. Tstd form to 500 psi 'or 12.5 ppg equiv mud. Drld 12-1/4" hole to 90801. Ran & cmtd 9-5/8" 47# L-80 & S-95 csg w/800 sx Class G cmt, shoe @ 90651. Installed & tstd pkoff. Dwnsqz 9-5/8" x 13-3/8" ann thru FO w/300 sx Arcticset cmt. Arcticpkd 9-5/811 x 13-3/8" ann thru FO w/240 bbls Arcticpk. Drld shoe & cmt to 90901. Tstd form to equiv of 12.5 ppg mud. Drld to 91301. Cored from 91301-96891. As of 8/31/79 POH to log @ 97801 /1 (? (.)0 :/ .f,-l tJ ($ -f;t~--.----' ¡( SIGNED TITLE Di stri ct Drl 9 Engi neer DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless otherwise directed. 1 ,: d ,) i ; I C ~' , i ) . ~ . \ :J,) AI)C;~(''H;l~~1 ¡\I,l:;:W ~;~)') I U TCI':~;);( ~;..Jï ~(/( SGTI" t """"~~, ", "'." ':~"1 (,. '<".. /~ " '~ August 28, 1979 Reference: Enclosed are Magnetic nircctioJlal Surveys of the follo\~'ing AI~CO wells: . ì\',GL-l....7(jl/79 Ì'Iulti-Shot " ,,,""',, . ,':.. :- -.: ,''''~,""" 8/19/79 ~lulti-S]lOt '¥'. 'I\'l~l- i~) '.' 6/21/79 r.Iulti -Shot NGI-13 6/7/79 'Single-Shot ì\{J ..1 7/9/79 Single -Shot / /Please sign and return the attached copy as rcceipt of data. Vel)T truly yours, {i?9/~p- Iz. 1\. Bellinger North Engineering 'TRANS0IITTAL H 29rl ~'} 1 ,~ / ;'" / ~/. " -':':),./' . . .,: ,/ I' .' .,;'//'" .¡I' /"?" '" 1/ ,I /,.. ., ..^- ~ ~/" ,r'" ,,""" ~ ' ; ~, .' ,r \ ,,, ;.. -, ~ ..///1 ,,/I'~........... t', I' .. ¡' ,. ~I.I /'~ ;, DISTHrBUTIO\J ¡\:orth Gcology Drilling Fng. ~bnagcl' R é~ D . Gcology S t(1 to of 1'\10 sktl D c¡ i'l E"\.xOI1 Ì'lobil Cctty Sahio Ì',1:1 X'd t 11 on })h:i '["j ij)::; Chevron I ¡,~. ';... i,',"¡' ' ~ '. '" \ . ~'" ! ' " ~ J l I, ,\ tl 1,¡¡lil,. l,n.IO Alaska Oil and Gas Conservation Camnission ø/t./ Hoyle H. Hamilton ,,/i/,., Cha.i.Irnan of the camdss' . 'tC Lonnie c. SIni th '1 -' 1; Camdssioner Ben H. LeNorman ~ Petroleum Inspector August 16, 1979 B.O.P.E. test on ARCOls DS 3-10, SWc 11, TI0N, RISE, m.i Prudhoe Bay Unit Friday, August 10 - I departed my hane at 7:00 AM for a 7:30 AM shCMUp and 8:40 AM departure via the AR<X> Charter for Deadhorse arriving at 10:20 AM. An attempt to reach Deadhorse the evening before resulted in our deplaØing in Fairbanks due .to bad weather and our subsequent return to Anchorage at 11:50 PM. I proœeded to RoW'an Rig #34 where I met with ARCD drilling foreman Tony zieto and rig pusher Rayford Robinson. Nippling up was in progress. Weather: +38°F, light wind, heavy fog. Tests began at 6:50 PM with the shoo on the 13 3/B" at 2730'. Annular preventer tested to 3000 psig. Upp:tt' pipe rams, check valve in the kill line, and wing valve in, the choke line tested to 5000 psig. Outside valve in the kill line and HeR valve in the choke line teste:1 to 5000 paige Loœr pipe rams tested to 5000 paig. Accumulator pressure was 3000 psig. ~li th the punps off we closed both pipe ram and annular preventers and opened the HeR valve simultaneously. Accumulator pressure dropped to 1250 psig and stabilized. The pumps were then turned on and a 200 psi buildup was recorded in forty seconds. N2 bottles tested 1200, 2250" 1250, 1350, 2350, and 2450 paig. We requested that those N2 bottles testing to less than 1500 psig be replaced with fully charga:ì OOtt.les. i~ile pulling the test joint to test the blind rams I walked the location which was well organized, the reserve pit well built, the rig in good repair, but the well sign was not in place, Blind rams then tested to 5000 psig. While testing the choke manifold two flange ].eaY~ developed, were hamnered up, and subsequently twelve valves and twenty-four flanges were tested to 5000 psig. The manual adjustable choke was free moving and the SWaco super-choke actuated fullYCFen and fully closed. Kelly cock and lower Kelly valve tested to 5000 psig and both dart and ball type floor valves were in place. Tests were concluded at 9: 15 ~1 and a field inspection report prepared with a copy given to Tony Zieto, a copy mailed to Bob Hines, and the origillal attached to this report. Saturday, August 11 - E.O.P.E. test on ARro's W3I #2 carrpleted, the subject of a separate re¡;ort. - -... -. - ----"' - -, - -, - -- -- -- -,-, -, ,- -. .-. --- "---~-- --- -~ -- _. '...._- -- ,-- - -- - 'ii' ~ '{ SUnday, August 12 - SSV and SSSV tests began on Drill Site '1, the subject of a separate report. Monday, August 13 - SSV and SSSV tests ccmpleted on Drill Site #1 and SSV and SSSV tests began on Drill Site IS, the subject of a separate re¡;:ort. Tuesday, August 14 - SSV and SSSV tests on Drill Site is cœpleted at 6:30 R-1. Tone Ziet.o advise the N2 bottles on D.S. 3-10 had 1::ee.n replaced as ~ art reguest. I departed Ðeadhorse via Wien FIt. #20 at 9:35 PM arriving in Anchorage via Fairbanks at 11:55 PM and at rqy hone at 12: 25 Af~. In summary, I witnessed successful B.O.P.E. test on ARCO'a DB 3-10. -',,- ,_,'_""_"'-"'-,,',-. -"'--",1-,,-----:'-,-"--'-1,,-_.,----.,,:'-1,.----..'-"'-'-"__"r_..-- '-",-;.,- ,0---,-"----""",,,, { ( -- -- - - ---~. -_..~ " Al~ ,a Oil and Gas Conservation Commi' .!e Field Inspection Report Dr 1 g. Pe rm it No. . ~le lllP~ Sec II T 10 AlR/.:>r::., fJ ~1 Operator AA~r--;--.- Represel}ted by~A.lý Z~.o Name & Number D.s; a::7D- -.- ¡{OI-U Þ4-AJ Æk; 43.r :?:ß? ",'" ~f,4)';::Ö,e.D ~6,¿:...r60,v Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (~Location,General Yes No Item ( ) BOPE Tests () (....r ~ ~~ell Sign (~ ( ) --,-s:- /~Casinq set @;2'Þ7-ro;1 (1-1' () 2. General Housekeeping (~ () 16. Tesc fluid-( )wtr. )mud (>r'oil (~ () '3. Reserve Pit-( )open( )filled (~() 17. ~1aster Hyd. Control Sys.-.5b~'e)psig (~ () 4. Rig () (~ 18. N2 btlsv~,~~~sig.z~~ ( ) Safety Valve Tests (~ () 19. Remote Controls ..:\çl...)lð () () 5. Surface-No. ~Iells- (-1" () 20. Drilling spool-~'lout1ets () () 6. Subsurface-No. Wells (~ () 21. Kill Line-(~Check valve ( ) Well Test Data ----- (~ () 22. Choke Flowline (ø1'HCR valve () () 7. Well Nos._,_,-,- (~() 23. Choke ~~anifold No. valvs~fl~s..:t¥ () () 8. Hrs. obser_,_,_,- (~() 24. Chokes-(~emote('..rros.(;rAdj. () () 9. BS&W , " (~ () 25. Test Plu9-(~ellhd( )csq( )none () () 10. Gr. Bbls._,_,- -,-- (~() 26. Annular Preventer,~"JOPsïq ( ) Final Abandonment (~ () 27. Bl ind Rams ,.;1'Dt¥~siCl () () 11. P&A ~1arker (~ () 28. Pipe Rams ~DPsiq(..:(..) () () 12. vJater well-( )capped( )plugged (~ () 29. Kelly & Kelly-cock~>psig () () 13. Clean-up (~ () 30. Lower Kelly valve":'-"D~si0 () () 14. Pad leveled (~ () 31. Safety Floor valve5=1~V (~art Total inspection observation time.;t&hrs/~ Total number leaks and/or equip. failures. ~ Rema r k S h.L~r£::- ÆL~~ e¿: -4 L!!Ze' ...:;>::.;>"..¿....~~ , ~: G~'" ~p~ ~ /:.J'~ D_¿£Zç;:. ~------....-,..__._- cc:/~8 /-hk.~ Notify in __days or when ready_- Inspected by£np....u.MA~Dàtè8!~/D'.-?1. May 17, 1979 Re: Prudhoe Bay Unit DS 3-10 Atlan.tic Richfield Company Permit No. 79-21 Sur. Loc.; 2134 'N & 638 'E of SW cr Sec. 11, Tl0N I R15E, U.~1. Botton\hole Loc.: 1320'S & 1320'E of ml or Sec. 11, Tl0fi1 RI5E, UM. Mr. P. A. VanDusen District Drilling Engineer ARca Oil & Gas Company P. O. Box 360 AnoboX'&ge, Alaska 99510 Dear )~r. VanDusen t Enclosed is the approved a,pp11cation for permit to drill the abQve referenced, we 11 ., Core chips are required; well sa,mples and a mud log are not required. A d,irectionalsurvey is required. If available, a tape con'ca.ining t.he digitized log in.formation" on all logs shall be submitted for copying except experimental logs, velocity s.urveys and dipmetér S\1rveys. ~~.ny rivers in Alaska and their drainage systems have been classified as important for the spawn.ing or migration of anadromous fish. Operations in these areas are subjeot. to AS 16.50.870 and the regulations promulgat:ed thereunder (Title 5, Alaska Administrative Cooe). Prior to com,lreenoing operations you maybe contacted by the Hahitat Coordinator's office, Department of Fieh and Game. Pol1ution of any waters of the State i.s prohibited by AS 46, Chapt.er 3, Article 7 and the regu,lations promulgated thereunder (Title 18, Ala.sk,a Administrative Code, Chapter 70) and by the Federal tfater Pollut.ion Control Act., as amended. Prior to commenci.ngoperations you may be contacted by a representative of the D~partnlEU'1t. of Enviro,nmental Conservation. -"-"'_._"'~-'--'''''-''._'''--'''--''-''-.'-''''C_'''''''--~.__I\'_.__'''-''---''''-I'''-\''-----'''''~'''--''I'---.''-''.-'''- Mr. P. A. VanDusen Prudhoe Bay Unit DS 3-10 -2- May 17, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issua.nce 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 spudded. ~'¡e 'Wo\\ld also like to be n.otifiedso that a repre- sentative of theoOOtm!ssion may be present to witness testing of blowout preventer eguiprnent bef,ore surface casing shoe is drilled. . In the event of suspension o,r abandonrnent, please give this office adequate ad,vance notification so that 'We may have a witness present. Very truly yours, ;I ~ t:J 1,",,'.'/' /Î(' r -.,""'" '.Ji"'''''''''''''''''/'''',.'! " ¡'{"'t;; \' J ,,_..¡I' ,,,""".' .,t, ~ ," '~...' , > ..~," T ,I Harry W. Kugler' Commissioner )3Jf .oBPgß DE lHI;;COMM!SSgON Alaska oil & Gas Conservation Comm.1.ss1on Enclosure cc: Department ofFish & Game, EJab1tat Sect-ion w/o encl. Department of Env!ronmentalConservation wlo/encl. Department of !..a.bor ; Supervisor , fOilabar Law ComI~l iance Division w/o encl. In'~:~!'., -,-- ,- - -- - -',,- - - - ,_..'- - ~ -- -- - - --'- --, - -- - - - - - - ,-,- -- ARCO Oil and Gas î! 'pany Alaska Regior. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 (\ May 11, 1979 Mr. Hoyle Hamilton State of Alaska A 1 as ka 0 i 1 & Ga s Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: OS 3-10 Dear Mr. Hamilton: / .// ~~ ~~ Enclosed herewith is our Application for Permit to Drill OS 3-10, a $100.00 filing fee, and the required survey plat. Very truly yours, ¡/il. 11~ P. A. VanDusen District Drilling Engineer PAV:cs Enclosures ¡bl""; ~ ,i fi.., ,".,~ "" (! I"> "., .ii', I ''f. ,1/ 44&!~ ' ~" I"~ " ,,-,/.I' l (~: r. t,;. //,'1 ¡(jl)ij ,i" ", 1)'(,..,. ß"w" ARCO Oíl and Gas Company is a Division of AllanllcRichfieldCompany ,¡ l~~ ~ \',~~I,f 1..". 1-11)/¡¡ , '~~$'" '01) Form 10-401' REV, 1.1.71 { SUBMIT IN TRIP( E (Other instruction. ' ,I reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE API 50-029-20361 5, PERMIT TO DRILL OR DEEPEN 6. LEASE DESIGNATION AND SERIAL NO, AOL 28328 la, TYPE OF WORK b, TYPE OF WELL OIL rv1 WELL L..ill 2. NAME OF OPERATOR DRILL ~ GAS D WELL DEEPEN D 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OTHER SINGLE M ~~,' ,I'" ~:J¡~\~J;.IJ ZONE l:ðJ i~.',., l~æNB" ¡,,,,l.bf Atlantic Richfield Company I' . 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO, OS 3-10 (xx-ll-10-15) 3. ADDRESS OF OPERATOR P.o. Box 360 Anchorage, AK 99510 4, LOCATION OF WELL At surface :, J', ,.d\~). l;ü¡¡¡n1ïss am. FpE~~aho~OLB~R WIFi~l d þ.I1GlìuraQ~ 21341N & 6381E of SW cr Sec. 11, T10N, R15E, UM r32Õ~eSPro&. zY320 I E of NW cr Sec. 11, Tl ON, R15E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE'" 5 miles NE of Oeadhorse, Alaska Sec. 11, Tl ON, Rl 5E, UM 12. 14. BOND INFORMATION: 13201 2560 Amount $100,,000 17, NO. ACRES ASSIGNED TO THIS WELL 1 60 TYPE Sta tewi desurety and/or No, Federal Insurance Co. #8011-38-40 15. DISTANCE FROM PROPOSED '" LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT, (Also to nearest ddg, unit, if any) 18, DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 16, No. OF ACRES IN LEASE 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS 26401 9710'MO Rotary 22. . APPROX. DATE WORK WILL START June, 1979 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Pad Level - 301 RKB - 641 23, PROPOSED CASING AND CEMENTING PROGRAM WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement stage ~tlantic Richfield Company proposes to directionally drill this well to 97101MO, 9339 TVD to pro- luce the Sadlerochit zone. The Sag River, Shubl ik, and Sadlerochit Sands ~.!J.J..,þ~~qred. Logs will )e run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will -be used. It will be )ressure tested each week and operationally tested each trip. A string of 5-1/2" 17# N-80 tubing, )acker and necessary provisions for subsurface safety equipment will be run. The packer will be jet above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the )ermafrost interval. Selected intervals within the Sadlerochit will be perforated, and reported or ;ubsequent report. A 5000 psi WP wire1ine lubricator, tested to working pressure, will be utilized dth all wireline work. Well will be flowed to production facilities during perforating and test- ing. The downhole safety valve will be installed and tested upon conclusion of job. 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. DATE 5/2/79 TITLE Oi st. Orl g. Enqr. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED " YES D NO MUD LOG DYES ~NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: Co I; r-c.. cJ-t' ~ ~~ DIRECTIONAL SURVEY REQUIRED, '~YES DNO A,P.I, NUMERICAL CODE 50 - 01-'1- t 0]&/ PERMIT NO. 79 - 1-1 APPROVAL DATE- APPOVED BY ~/ ,;1. 7 V TITLE Canmissioner / " *See I nstruction On Reverse Side SY ORDER OF THE COMMISSION May 17, J 979 DATE 5/17/79 10 II 15 \ 14.- CERTIFICATE OF SURVEYOR f HEREBY CERTiFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE.LAND SURVEYIN,G IN THE STATE OF ALASKA AND THAT THIS PLAT REPRqSENTS A LOCA TlON SURVEY MADE BY -ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. APRIL 25,1976--_---- DATE OF SURVEY SURVEYo;r- ~ I I I I I- 0: 0 Z 664' r- 6aa' \ 713' F:::, ...--- 787' I w z ::J z Q I- U W (/) 8121 837' c\ iJJ ~.. , UI 4, , 0:. I- 0 a:: a.. L() C\J (\j ------- I APRIL 28, 1979 I DATEOF ADDITIONAL SURVEY (We-lis 9 8 10 ) /~2. ;:). ---.,.- " l~ ""'., AS f'l LT 11\ WELL NO.1 LAT. 70° 14' 01,50911 Y 5 938074.68 LONG, 148°16'22.77311 X 713903.73 W ELL No, 2 LAT. 70°14100,39311 Y 5937961.93 LONG, 148°16' 22,066" X 71393125 WELL NO.:3 LAT. 70°13' 59.23811 Y 5 937845.28 LONG. 148°16'21.335'1 X 713959,73 WELL No, 4 LA T. 70°13' 58,08511 LONG, 148() 16' 20.610" Y 5 937 728.76 X 7 I 3 988.0 I WELL No 5 . LAT. 70°13' 56,933" LONG, 148016' 19,88011 Y 5 937612 .40 X 714 016.42 WELL NO.6 LAT. 10° 13' 55,77411 LONG. 148016' 19,15611 Y 5 937495.34 X 714 044.61 WELL No.7 LAT. 70°13' 54,620'1 ,Y 5937378.76 LONG. 148°16' 18,428" X 714073.07 WELL No.8 LAT.. 70°13' 53.47011 Y 5 937 262,50 LONG. 148°16' 17,701" X 714 101.37 WELL No.9 LAT. 70°14' 03.814" Y 5 938 307.51 LONG, 148°16124.24711 X 713 846.37 WELL No.IO LAT. 70°14' 02,66211 Y 5 938 191.14 LONG, 148°16'23.509" X 713875.09 -.--------------.--- NOTE 0 EXISTING WELL OR CONDUCTOR PIPE -.-.-- # 2 ADDED WELLS 9610 APRIL 1979 G.D, # 1 ADDED WELLS 566 JUNE 22,76 GD. REVISION OAT E 'CKD. ARCO No. HVL No.34-DS3-76 _._-,............----_._~"'--_....._..__.......- ATLANTIC RICHFIELD CO. AS BUILT ^"..' 1~ ,;ß DRILL SITE No.3 WELLS No. I thru 10 LOCATED IN PROTRACTE D SECTION II, T.! 0 N., R. I 5 E., U. M. PREPARED BY HEWITT V. LOUNSBURY a ASSOC. 723W. 61b.- A'{E, ANCHOR~GE 1 ALASKA DATE MAY...? I 1976 SCALE I" = 300' C HKD. BY G.DD. FIELD BK LOOSE LEAF _.--.-"......-~-- ----"'''-'-'''-'--'.''-' . RLC At Ian ti c R i c hfieici Cornpany North Arnc'n Produc ¡rig Division North Alas(' trict Post Office L-,v,", 360 Anchorage, Alaska 9~;5-1 0 Telephone 9072775637 ( .~--~u_.. ~~ . .þ~~'" , . I );; - ~ JlUle 21, 1978 '--,', +(, -.'1. :"! Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 ::.1/ C>.': ,\F T I ~."'C <.. " ' In response to your request for data pertaining to reservoir pressure, information, please find the enclosed data. A. list of stabilized flow rates prior to shut in and cummulative oil produced since last pressure equalization has been tabulated for all wells requested; with the exception of the following: D. S. #1-11, 1-12, and l-14-To be TIm in the future. D. S. #2-11,Z-;12,,:Are currently being run. D. S. #3-9'i3-10-Nb plans for these wells to be drilled at ',' ,-.- this time. Per your request, copies of Initial Static Pressure reports are again being submitted for the following: D. S. #4-7-Distributed to State 5-19-77 D. S. #9-3-Distributed to State 11-24-77 NGI #3- Distributed to State 19-78 NGI #5- Distributed to State 10-9-77 To date, no pressure buildups have been TIm on NGI wells. Plans are to run pressure surveys only at this tjme. I hope that this information will satisfy the state requirements adequatel) Very truly yours, . /'"¡ /:> / "" ' ',( ,:;~{.;:,..:.c/'.i~~:~--_.. / J. A. Rochon jAR/RAL/ er f.: ). :.. ~ ' "". ,\...,~ '. , j,. JtJ.Ni Z 6 ~;~8 lr.:~ ; ',,1 {;, 11/,,; ¡,,"ii :.i11 HKVP CHECK LI~;T FOR NE'~ 1-.'ELL PER~HTS (..r1pany -IJß. C-o Yes No Remarks .~ - . . . . . . . . . . . !-e.I- Is ä registered survey plat attached. . . . . . . . . . . . . . . . ~ --- .,----'-.-----.-- .~ . IE=, Is sufficient undedicated acreage available in thlS pool ~ Is well to be deviated. . . . . . . . . . . . . : . .. : : : : : :. ~ 0 per at ryr the 0 n 1 y a f f e c t e d par t y . . . . . . . . . . . . . . . . 9"- ..........~ .......~-- cons~rvation order needed. . . . . . . . . . . . . . . . . .. . " .~,",~ Is administrative approval needed. . . . . . . . . . . . . . . ' Is @;~)nductor string provided .. . . . . . . . . . . . . . . . . . . ¿PItJ Is cfl()ugh cement used' to circula te on conductor and surface. . . . ,(!ß12 \\fUl':cement tie in surface and intermediate or production strings. ~~ ft!2 ~Ell s1Jrfacc' c<lsjng protect frc'sh \.:at('~. zones. . . . . . . . . . . ¡fa¡¿ .-'-- ------,-.-,-,------ tfA;P RIJ}) Is the permit fee attached. . . . . . . . . . . . . . Is well to be located in a defined po~l Is well located proper distance from property line . . . . .' . Is well located proper distance from other wells . . . . . ~ . permit be approved before ten-day wait operator have a bond in force . . . . Is Will cement cover all known productive horizons . . . . Will all casing give adequate safety in 6ol1apse, tension & burst Does ßOPE b.1V(> suffi j,pnt preSSllrc~ rating - Test to ~J!..:'2-, jis Approval Recommen~ed_: ,j,tional Requirements: ...-.---.---....-..---.,-......--"....-.-'...... ~'I - ,1/ - ~, "'~"".'''''''''' """"'''''''''-'.,..-0> """,-"",.""'.... """"'''''_'''.' -"--'."""'"'~-''~'''-'''''-'",'-''''''' '..' .-,..,.-'.--.,..,.. '''''""._'",,-~..-, Fe 11 :J 0 . 113 fA. Item ~pprove-T).::;'të--- -~.._- -(1) Fee ~- S--(k~7~ Lease & ,-_.~"""""-,,,"-"'-""--"'--"'-'--"'- ""'.""---- .~eolo~: I-mK '~" '" WVA, ' ~L (2) Loc. t0t- (3) Admin'fe-t-- ( 4) !;a s g . ~RJ) - (5) BOPE i'trj) ¡Js 3-/0 !:S -; t, - 7 '; ~ S -; ,~ 7 $ ~ ...?/!l-/79 ~ _5/11./21 <f En~~~l1g : LC.S ~,ßE~.J~ Pf::~'7ised n~~~C'J* 4-, ,+-, Q, c\..;'-.. "-- 0 <.. c:..c: 0 c' c:: :~ . ~ ~ 0 ~ z '::! ....... U) -.... :::! '- ..¡.J .:J r-i rt I ro+J "- 'r-! ~ "- +J ''-; s:: U) . H ~ ~ C <:;";\ C,'~' '----. '. -.'.- '.. '-,....-. "'.''''-'-'.' 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 APPEN.DIX. No'special'effort has been made to chronologically , . . organize this category of information. . ,) ( ti ( fJ5 ~3-/ò **************** * * **************** * SCHIJ.uMBERG~:R '* **************** . f'" ~~; .,f. H.IGI:J ,,:R~;S~.l UTl ON, DIPM~~T~R ~. *******~, &) r:irr:/~,.fr:D ~\. 2~ ~ ( \l c 0 cr s) í 1978. Alaska em ' II A~"~~, Con8. '-OIlImlttsfOt1 l"U,uflutsMï CLUSTF~R LISTI.NG ******",.** J.\'l~LANT.IC "BICHFrEl.,D COMP.ANY NOR TN .".' Sl"OPE,ALASKA ..s. :3 -10 CINE: J.CJßN o. 3513 CLOS.'FERRES U LTS "'" 0 N I, Y. CORR. .. 2F'T. STEP gO IrE G.J¡2 SEARCHANGL f; f¡ ( (' --- , -.,-. '.._~.__.- '_..~ _. ._- ,--"..; ~.~_._.. '---,." "'"--'-"" '"..--... .--... ..----- ---. ,.-- , . ,--", '-'---" ". .-.... ",,-'-' -_..- "--'--' ,_..... ,..'..-.-' "---.,,~ .,'.'--- .. _h' ,.. ~---' --"-" -...., --,- -,.---... .---..-. ---... .--... -_....,- --- --- --- .---.. ._._~", '--- t ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE i-FILE 2 ************************************************************************* * * (ì'ORMA T ION * BOREHOLE * ("UAL. '* * *~~.~--------------*-------------------~--~-----------* INDEX * * DEPTH * DIP DIP * DEV. DEV. DIAM DIAM * BEST * * '* AZI. * AZl. 1-3 2-4 * =A * ************'************************************************************* * * * 9082 4.3 103 2.4 14 9.4 9.4 A * * 9084 4.8 109 2.4 19 9.4 9.6 A * * 9086 4.6 106 2.4 24 9.4 9.9 A * * 9088 2.5 97 2.5 28 9.5 11.1 A * * 9090 2.1 146 2.5 32 9.7 12.0 A * * 9092 2.4 31 10.1 11.4 * * 9094 2.6 155 2.4 24 10.4 10.5 C * * 9096 4.0 125 2.4 16 10.1 10.0 A * * 9098 5.0 112 2.4 15 9.7 9.8 A * * 9100 3.2 230 2.4 19 9.7 10.2 A * * 9102 3.0 69 2.4 18 10.6 10.7 A * * 9104 1.9 73 2.3 16 11.1 10.7 A * * 9106 5.5 195 2.3 12 10.6 10.6 A if * 9108 1.7 157 2.3 4 9.8 10.1 A * '* 9110 1.7 125 2..3355 9.1 9.4 A * * 9112 2.1 104 2.2 351 9.0 9.3 A * '* ~114 2.5 74 2.2 352 9.2 9.4 Ä * * 9116 4.0 160 2.2 3 9.4 9.5 C * * 9118 3.8 t63 2.2 9 9.6 9.8 C * * 9120 20.5 44 2.2 7 9.7 9.8 D * *912.2 3.6 153 2.26 9. 79.e A * 6 117 2.2 10 9.6 9.9 A * 2';2 12 9.5 fO~2C it 2.2 15 9.3 10.0 A * 2.2 20 9.0 9.4 A * 2.2 22 B.9 9.3 A * 2~2 25 9.9 9.2 A * 2.2 28 8.9 9.1 A * 2..2 2S 8.9 9.0 * 2.2 24 9.0 9.0 * 2.2 23 9.09,~O 2.2 15 9.0 9.1 2.2 9,.9 2 357 8.9 357 9iO 355 9 0 357 2.1 4.5 *, 2~O 6 fl~7 l~.D * * 9160 2.0 1 11.9 9.8 * ,*,,****iffEi,*,j*,*,,*****.****,****t'*****.'*****'****** **********.********,*'**i***** it,**:** ( . "'_... ... .~, -~ "."" ...- '--,-", ,_. ."...--- ."~. ,- ._- .-.' .._~_. . '..-- .-......- .--' ..",' .-.." -, _... -.." ,_._~, - '.~" .--- ._-- ~-_.- .--..,... ---., -.." ".'"~"~ -.--.. _..- ...-- --" -_. -..-- .._,,- .."""-.-, .-..-- .....,.".'.. -~~" - ,-,.'.._., ,--'- (. ( ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE 2-FILE 2 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *------------------*----------------------------------* INDEX * * DEPTH * DIP DIP * DEV. DEV. DIAM DIAM * BEST * * * AZl. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9162 3.4 305 2.0 0 10.9 9.8 D * * 9164 8.0 164 2.0 5 9.5 9.8 D * * 9166 8.5 184 2.0 10 9.0 9.4 D * * 9168 2.1 14 8.8 9.2 * * 9170 23.2 21 2.2 17 8.7 9.2 D * * 9172 21.9 19 2.2 19 8.7 9.1 B * * 9174 2.2 23 8.8 9.0 * * 9176 2.7 180 2.2 25 8.9 8.9 A * * 9178 1.6 144 2.2 23 8.9 8.9 A * * 91.80 1.3 89 2.2 15 8.8 8.9 C * * 9182 2~7 59 2.2 355 8.7 8.8 A * * 9184 6.3 345 2.2 343 8.5 8.7 A * * '1&6 .~1 236 2.1 338 8.4 8.6 C * * 9188 6.1 210 2.0 341 8.4 8.6 C * *' 9190 12.5 211 2.0 356 a. 5 8.6 D * 9192 2.0 1 8.5 8.6 * 91,94 11.9 124 2.0 359 8.6 8.6 C it 9196 3.0 69 2.0 355 8.5 8.6 C '* 919a 4.5 323 2.0 3578.. 5 8.6 A '* 9200 2.0 liB 2.0 4 8.5 8.6 A * 9~Ø26.86B 2 .> () 2 8.4 8 . 6 A * 9204 10.3 117 2.0 7 8.4 8.6 C * 9~Ø6 9.1101 2. 0 27 8.5 8.7 A '* 4.0 92 2.0 19 8.7 8.8 A * 3\.6 40 2.0 355 8.6 tf., '1 A * 3.9 321 2.0 348 8.5 8.5 A * 14>.3 1,62 2.0 347~l.5 8.5 B * 15.9 143 2.0 345 8.5 8.5 B * $~2 1,>10 2.0 345 8. sa. 5 B * 90 2.0 350 8.5 8.5 B * 1462.0352 8.5 9.6 D * 0 2.0 355 8.5 8.6 D * 2.0 5 8.5 8,.6 D.. 2.0 9 8.5 8.6 0 * 2. 0158.58.6 B * 2.0 25 8.5 8.6 D * 2.>0 28 B.5 8.6 0... 2.0 21 8.5 8.6 A * 2.0 3 8.5 8.6 A * * 9240 2.0 351 8.5 8.6 *' ***--********************************************************************* * { c=== ~ - --- -, 0_. -,' - -~ -- _.- -- --~ -- ---. -..- --.-.-" _.~..- -.-., ~,-_. -~,,- ._.~ -..--. ~....~ ...,~._.~ "'.-.---' .----... ~~~ ..-.,- .~_._.. .--- .'-- _._-~ ~"""- .-- --- -~,-,-..... .--.--' -"- '-.-.-...... .-.-..- ---- __n'.' . ATLANTIC RICHr~IELD COIV1PA D.S. 3-10 P.AGE 3-F'ILE 2 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *-------~-------~--*-~--~---~------------~-------~----* IND~X * * DEPTH * DIP DIP * DEV. DEV. DIAM DIAM * BEST * * * AZI. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9242 3.5 80 2.0 349 8.5 8.6 C * * 9244 2.2 18 2.0 349 8.5 8.7 C * * 9246 1.2 341 2.0 348 8.5 8.7 A * * 9248 0.6 20 2.0 351 8.5 8.7 A * * 9250 1.0 18 2.0 354 8.6 8.6 A * * 9252 6.6 14 2.0 353 8.5 8.6 C * * 9254 4.9 131 2.0 356 8.5 8.6 A * * 9256 3.2 49 2.0 357 8.5 8.6 A * * 9258 3.3 140 2.0 356 8.5 8.6 A * * 9260 2.3 80 2.0 1 8.5 8.6 A * * 9262 J .1 3 2 . 0 6 8 . 5 8. 6 C * * 9264 1.8 68 2.0 9 8.5 8.6 C * * iZ56 1~4 Lt9 2.0 1~ 8.5 &.6 C * * 9268 2.3 207 2.0 26 8.5 8.6 A * *9270 0.2 216 2.0 22 8.5 8.6 C *' * 92722.0 356 8.5 8.6 * *9274 2.0,340 8..,4 8.6 C * 2.0 345 8.4 8.6 C * 2..0 343 8.4 8.6 * 2.0 338 8.5 8.6 * 2.0 )44 8.5 8~6 C * 2.0 353 B.6 8.7 * 12.0 352 8.6 a~'7 2.0 351 8.5 8.6 ~~O 1. 8.58..6 2.0 15 8.7 8.8 2.0 26 9.1 9.3 2.0 31 9.4 9.4 i~Ø 34 ~.S ~~~ 2.0 33 10.1 9.9 2.0 29 ~..6 9.7 2.0 22 9.0 9.4 2.0 11 El.9 9.3 2.0 a 8.9 9.1 2..0 6 9.1 2.0 2 9.5 .8 1.0 1 9.5 9~1 137 2.0 4 9.4 9.5 143 2.0 9.1 9.2 A * 9320 1.2 209 2.0 1 8.9 9.1 A * *~j*...*tf~,*,...****i**,"'****~*******.*******'I-.********.* **'** ************ *******,**** (' A A A, A A A A A A C A A C * * * * * * * * * * ( ~ .__. _._"." -'-- .--- ._- -'- -- --- - - --.... --, -. - - - --.. --- -- - -~...- - "- -, -.- -- -- -- ,-- --, - -- - --" -- -- - - "- _. -- ( ~. ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE 4-FILE 2 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *--------------~---*---~------------~------~----------* INDEX * * DEPTH * DIP DIP * DEV. DEV. 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() 6 8.9 9.1 A * o. 2.0 6 9.3 9.5 A * 3.:72. 0 59 .59.6 A * 3.6 2.0 9 9.3 9.4 A * 1.42.0 11 9.19.2 14* * 9320 1.2 206 2.0 7 8.9 9.1 A * ******************* ***************** *** *** ****** ** *' ** * ****, *** '* ***** ** **** ( -- -.,.-" -u_-.... ,.--- - .~._-, .-- _. --- - --.- --- --,., --- ..._~. ....- --- <-.-.... '.-..--, .--.--- --,,- _._,~- ----,- ....--.- ----_. --... .-- '---' ---. ---- -.-:..- _'R_"- ...._,- .-.... ---- -- - -- - - - - (' , ' ~ ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE 4-FILE 1 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *------------------*----------------------------------* INDEX * * DEPTH * DIP DIP * DEV. DEV. DIAM DIAM * BEST * * * AZI. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9322 2.3 154 2.0 7 8.6 8.9 A * * 9324 1.4 136 2.0 3 8.3 8.7 A * * 9326 2.0 2 8.3 8.5 * * 9328 2.0 5 8.3 8.5 * * 9330 2.0 5 8.3 8.5 * * 9332 2.0 4 8.3 8.5 * * 9334 2.0 358 8.3 8.5 * * 9336 2.0 355 8.3 8.5 * * 9338 13.1 186 2.0 357 8.3 8.6 B * * 9340 12.2 175 1.9 3 8.7 8.9 B * * 934,2 2 .3 S 3 1 . B 9 9 . 0 9. 1 A * * 9344 2.2 162 1.8 11 9.1 9.1 A * "* 93.46 2.0 1$0 1. 8 .., 9 .4 9,.3 A * * 9348 1.0 108 1.8 360 9.2 9.1 A * *' 9350 6.124 1.8 358 8.6 e.7 B *' * 9352 7.7 21 1.8 359 8.3 8.4 B * * 9aS4 0.9 29 1..9 360 8.3 8.4 D * 9356 2.0 359 8.3 8.4 * 935$ f~5 2.0 352 8..3 8.4 B * 9360 167 2.0 349 8.3 8.4 B * gg621ó 2.0 34.98.38.4 B * 3 2.0 350 8.3 8.4 B * 14 1.9 154 a.3 8.4 D* 73 1.9 2 8.3 8.4 D * teO 1~8 16 B .3 .8.0 D * 351 1.8 22 8.3 7.8 D * 335 1.a 168.3 1.9 j) * 1.8 12 8.3 7.9 * f.8 1,6 8 .2 7.9* 1.8 21 8.2 7.9 D * r¡ø 23 8.2 1~' D * 1.8 24 8.2 7.9 0 * 1.821 8.2 1..9 a 1.9 11 8.2 8.1 0 a.Q 1 8~3 8~1 2.0 356 8.3 8.5 * 2.Ó 348 8.3$.4* * 9396 2.0 345 8.3 8.4 * *~3~<a t~9344 8.3 a.3 * * 9400 1.8 345 8.3 8.4 * ~..."it*~~**...**~..*:*".~.****...*,***,*********** ********* *************************.* *' ( _. -- -_. - -~.- _. --. ...-.. -~ -. .-. _. -. ._- -- -~-, - - - -- -_. - - - -~ ---, -- -- - --- - - --- ,- ,-- - - ---. --- -- - ( ( ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE 5-FILE 1 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *------------------*----------------------------------* INDEX * * DEPTH * DIP DIP * DEV. 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DIAM DIAM * BEST * * * AZI. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9402 3.9 232 1.8 350 8.3 8.4 D * * 9404 5.3 222 1.8 354 8.3 8.5 D * * 9406 1.8 2 8.3 8.5 * * 9408 4.8 167 1.8 9 8.3 8.5 D * * 9410 3.4 145 1.8 12 8.3 8.5 D * * 9412 1.8 13 8.3 8.5 * * 9414 1.8 15 8.3 8.5 * * 9416 8.3 99 1.8 12 8.3 8.5 0 * * 9418 6.4 275 1.8 8 8.3 8.5 D * * 9420 2.5 298 1.9 8 8.3 8.5 D * * 9422 4.3 Z37 2.0 9 8.3 8.5 D * * 9424 2.0 4 8.3 8.4 * *9426 2 . 0 .3 55 8 .,3 8 . 4 * * 9428 5.4 232 2.0 353 8.3 8.4 B * * 'ff' 4~1 265 2.~ 355 8.3 8.4 B * 9432 6.2 196 2.0 356 8.4 8.4 B * . 943i4 6>.5 ltlO2. 0 351 8.4 B.4 A * 9436 7.1 156 1.9 348 8.4 8.4 A * 9438 '~I~O 129 1.8 35 3 B .3 a . 4 C* 9440 1.8 1 8.3 8.4 * Q4*,2 65 1.8 5 B'.3 8.4 C * 9444 43 1.8 5 8.3 8.4 A * 9.'6 421 . 9 68. 3 8.r5 A* 48 162 1.8 5 8.4 8.5 A * 1.8 lei 0 8.7 8.8 A * 1.8 3 9.1 9.2 A * 1.8 10 9,.0 Sf.. 1 A * 1.8 10 8.7 8.8 A * 1.8 10 8.4 8.6 A * 1.8 10 8.4 8.6 A '* f.8 6 8.4 8.6 A * 1.8 1 8.4 8.6 A * 1.93 8.4 8.6A* 2.0 6 8.4 B.6 * 2.0 1 8.4 8.6 C * 2.0 354 8.3 8.5 A * 2.0 354 8.5 a ...7 .A '* 9476 4 1.9 358 8.9 9.0 A * 9.4'$1151.82 9.1 9.1 A '* * 9480 123 1.8 5 9.0 9.1 A * ***** **"*"h*,...**,***** ****************** *** **** *... ***** ** * ***** ** ** **** ** * * '* '* * * l ( [~=~" , - .-- _.~- --" -~. -~_. 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DIAM DIAM * BEST * * * AZI. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9482 0.6 87 1.9 6 8.9 9.1 A * * 94B4 0.3 332 1.8 5 9.0 9.1 A * * 9486 1.5 98 1.8 8 8.9 9.0 A * * 9488 1.8 lB2 1.8 11 8.9 9.0 A * * 9490 2.,7 187 1.9 11 9.1 9.3 A * * 9492 2.3 1B6 2.0 B 9.3 9.5 A * * 9494 1.8 226 2.0 5 9.3 9.4 A * * 9496 1.5 340 2.0 7 9.0 9.1 A * * 9.498 0.6 86 2.0 9 8.7 8.B A * * 9500 0.9 123 2.0 8 8.4 8.6 A * * 9502 2.0 101 2.0 1 9.3 8.5 A * * 9504 1.7 77 2.0 353 8.3 8.5 A * 'M- 9506 2.0 354 8.3 8.5 * * 9508 6.1 147 2.0 356 B.3 8.5 A * * 9510 6.1 1912.0 359 8.3 8.5 C * * 95.12 2.4 166 2.0 0 8.4 8.5 A '* *' 9$1.42.4109 2.0 356 8 .5 8.6 C '* * 9516 1.3 152 2.0 356 8.7 8.7 A * .' 9S)t$2~5 185 1.9 1 8 . 9 9~ 0 A * * 9520 3.5 177 1.8 2 8.9 9.0 A * 9522 2~9 2>4131. 8 6 9 .,3 9.3 A... 4 1.8 8 9.6 9.6 * 1.8 3 9.3 9.4 A * 1.9 2 9.9 9.0 A '* 2.0 3 8.5 8.6 A '* 2.0 4 8.3 8.5 A * 2.() 7 8.3 8.5 A* 2.0 10 B.3 8.5 C * 2.0 5 8.3 8.5 A * 2.0 351 B.3 8.5 C * 2._<0 347. 8. :2 8.5 A... 2.0 350 8.3 B.5 A * 1..9 352 8.3 Si,.5 '* 119 1.8 358 8.3 8.5 A '* 961~84 8.3 8.5A* 73 1.8 5 8.3 8.5 C * 155 1..8 78. J 9~,5 It 133 1.8 10 8.4 8.6 A * 101t.8 9 8.4$i51* * 9560 6.1 138 1.8 7 8.3 8.4 A * ******,**************,************* ******** ** ***,**** **** *********,**** ****** ( -. -- _.- -- - --- - -, -- - - -.--. - ._,- - -." - ,--' - -- - -- .- -_. - -- --- ,- - -.- .--- - __0.. __0- .,..--. -.", ._,--""- ..w.-.-_. .'-'- -". ---- ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE 7-FILE 1 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *-----------~---~--*~~~~-----~~._----~----~------~----* INDEX * * DEPTH * DIP DIP * DEV. DEV. DIAM DIAM * BEST * * * AZI. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9562 5.4 5 1.8 0 B.3 8.5 C * * 9564 8.7 349 1.8 348 8.2 8.5 C * * 9566 5.8 117 1.8 342 8.2 8.5 A * * 9568 3.4 96 1.8 350 8.1 8.5 A * * 9570 1.2 87 1.8 360 8.1 8.5 A * * 9572 4.2 156 1.8 1 8.1 8.5 A * * 9574 2.4 125 1.8 3 8.2 8.5 A * * 9576 0.6 81 1.8 6 8.2 8.5 A * * 95 7 8 1 .,5 2 9 7 1 . 8 4 8 . 2 8 . 5 A * * 9580 3.0 306 1.8 2 8.3 8.5 A * * 9582 4.3 219 1.8 358 8.3 8.5 C * * 9584 3.4 63 1.8 353 8.3 8.4 C * * 91&6 1.4 343 1.8 351 8.3 8.5 A * * 9~88 12.3 148 1.8 352 8.3 8.5 B * *9590 7.994 1.7 354 8.3 8.5 A * * 9592 8.5 43 1.6 353 8.3 8.5 A * 9594 8.5 18 1.6 353 8.3 8.5 A '* 9596 6.0 81 1.6 1 8.3 8.5 C *' 9598 5.2 121 1. 6 7 8 .. 3 8. 4 A * 9600 4.4 89 1.6 5 8.3 8.4 A *' 96026.6 292 1.6 3 8.3 8.5 A * 9604 12.2 42 1.6 1 8.3 8.5 C * ~606 l.6 355 8.3 8.5 * 9608 1.6 351 B.3 B.5 * 9t>lQ 1. 6 347 8 .3a.5 A * 9612 1.6 347 8.2 8.5 A * 9614, 1. 6 352 8.. 2 8 .. 48 * 96 16 1 . 6 3 5 7 8 . 2 8 . 4 C '* ;618 1.6 360 8.,2 8.4 A * 1.6 1 8.3 8.4 C * 1.6 3 8.3 8~5 C * 1.6 2 8.3 8.4 D * 1.6 349 8 . 3 8.. 5 C * 110 1.6 341 8.3 8.5 A * 180 1.6 345 8.2 8.4 A * 3.5 146 1.6 350 8.2 8.4 A-t . 2.2 133 1.6 358 8.2 9.5 A'" 9636 1.3 122 1.6 4 8.3 8.5 A * 9638 S~9 179 1.6 2 8..4 8.6 A * * 9640 1.1 135 1.6 2 8.5 8.7 A * *****>********* if**** ****** ** *... **' * **** * * ** *,.. ** ** *' *. * ** * * '* * * * '* '* ** '* *' iE' *** * * * * '* * 'I' ~ { * * * '* i(' '* * '* * '-'_""_'~~M.~___~~---''''''''-----'''''''' ( { -~.'_.' ._-~ --,' '---'" ---~ -~_. ~~ _--.0.' __..M "-,~_.' ------ h_".__..'" 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DIAM DIAM * BEST * * * AZI. * AZI. 1-3 2-4 * =A * ************************************************************************* * * * 9642 1.3 297 1.6 3 8.5 8.6 A * * 9644 2.5 246 1.6 355 8.3 8.5 A * * 9646 3.0 173 1.6 346 8.3 8.5 A * * 9648 2.8 152 1.6 343 8.3 8.5 A * * 9650 1.6 148 1.6 343 8.3 8.5 A * * 9652 2.1 104 1.6 347 8.3 8.5 A * * 9654 1.2 184 1.6 354 8.3 8.5 A * * 9656 4.4 88 1.6 356 8.3 8.5 A * * 9658 1.0 91 1.6 0 8.5 8.7 A * * 9660 1.6 214 1.6 5 8.7 8.9 A * *, 9662 2.2 215 1.6 358 8.7 8.8 A * * 9664 2.5 222 1.6 355 8.6 8.7 A * * 9666 3.3 245 1.6 1 8.6 8.8 A * * 9668 2.7 292 1.6 2 8.6 8.8 A * *' 9610 5. 0 262 1. 6 1 8 . 6 8.. 8 A * * 9672 4.1 157 1.6 357 8.7 8.9 A * * 9614 6.0 104 t.6 352 8.7 8.9 A * 9676 1.1 119 1.6 349 8.7 8.9 A * g6"'.Sf. 6 349 8.7 8.9 * 9680 1.6 353 8.7 8.9 * 9£>8299 1.6 351 8. 88. 9A '* 90 1.5 356 8.9 9.0 A * 210 1,.4 358 9.0 9.1 A *' 203 1.4 5 9.0 9.1 A * 178 f. 4: 5 9.1 9.2 ,A * 175 1.4 3 9.1 9.1 A * 19~ 1~A 2 9.0 9.0 A * 184 1.4 2 9.0 9.0 A * 151 1.4 2 9.1 9.2 A * 9 1.5 2 9.1 9.3 A * 116 1 9;~ 9i3 A * 1.6 1 9.1 9.3 A * 7 3 9.0 9.2 1.8 3 B.8 9.0 1.a 358 8. 6 8i.9 A 1.8 351 B.7 B.8 A t.7 345 8..7 8.9 A 240 1.6 342 8.7 8.8 A 195 t. 6 34: 58.7a~8 Ä * 9720 1.1 197 1.6 350 8.7 8.8 A * ...if>****.*******it**************************.*** '* ** ********* * ***** ************ * ( - --- _. -- --, -'- - -,,_. -, -- _. ,-- ---" --' .~-, -- - --. - -- - -- --~ .-.-- ----. -- - -~ -- ,-_. ._~. --... ---. ,----- ._-, -_.- ...-_.~ --"... -_.~_.. _."- ---.-." _.~-, ~ ( (, ATLANTIC RICHFIELD COMPA D.S. 3-10 PAGE 9-FILE 1 ************************************************************************* * * FORMATION * BOREHOLE * QUAL. * * *---------~--~---~-*----~-----~-.---~~------~----~-~--* INDEX * * DEPTH * DIP DIP * DEV. 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' 1 (, , ~, ATLANTIC RICHFIELD COMPA D.S. 3-10 SUMMARY ************************************************************************* * DEPTH * DIP DIP * DEV DEV DIAM DIAM * QUAL * * * AZM * AZM 1-3 2-4 * * ************************************************************************* * * * TOP * * 9082.0 4.3 103. 2.4 14. 9.4 9.4 A * * * * BOTTOM * * 9768.0 1.3 196. 1.4 357. 8.6 8.7 A * * * * TOP * * 9082.0 5.4 109. 2.5 16. 9.3 9.3 A * * * * BOTTOM * * 9768.0 1.8 177. 1.5 354. 8.7 8.8 A * * * ************************************************************************* ( ,.......--..------ ... -,,~ ---. -.-- ---. ---'-' --.-- .-- -- ._- .-.. -- .-. -_. --- --- ..-- .-..-. - - .- ---. --- ~-,~ ,--- ,-- --- -- ,-.- - ---~ -- ,-- -~- -- -- -_..- .,.-- _..~'._,. --~-- _....- "'- LIBRARY TAPE CURVE SPECIFICATIONS pg /)5 3-/6 (r2C<-Led. Ju/e) 11c,"" /'1'" /¡,¿/ / Ii {.I, II);:) Company ARCO ALASKA, INC. Well D.S. 3-10 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 10-29-82 ***Casing Collar Locator Corrected As Per Log*** Curve Name (Abbrev. ) Standard Curve Name Logs Used Scale LSN2 Long Spaced Neutron Pass 2 CNL 0 - 1250 SSN2 Short " " " 2 " 0 - 1000 CN2 Compensated Neutron " 2 " 60 - 0 GR2 Gamma Ray " 2 " 0-100, 100-200 CCL2 Casing Collar Locator" 2 " 0 - 1 LSN3 Long Spaced Neutron " 3 " 0 - 1250 SSN3 Short II " IV 3 " 0 - 1000 CN3 Compensated Neutron " 3 " 60 - 0 GR3 Gamma Ray " 3 " 0-100, 100-200 CCL3 Casing Collar Locator" 3 " 0 - 1 LSN4 Long Spaced Neutron " 4 " 0 - 1250 SSN4 Short " " " 4 " 0 - 1000 CN4 Compensated Neutron " '4 " 60 - 0 GR4 Gamma Ray " 4 " 0-100, 100-200 CCL4 Casing Collar Locator" 4 " 0 - 1 LSN5 Long Spaced Neutron " 5 " 0 - 1250 SSN5 Short " " " 5 " 0 - 10~E t \: \ \ E ~' CN5 Compensated Neutron " 5 " 60 - i\{()\I l ù \9~ ~ . rr"~"" ,""" '; ('\l>'"Ij . , (' ~ C3ns. Ccm,¡!:¡;::,_:-!, l' 0' 1 &,:¡a" ' A\as¡,m l'þ,\: ~\10!agD LIBRARY TAPE CURVE SPECIFICATIONS Company ARC 0 ALASKA, INC. Well D.S. 3-10 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 10-29-82 ***Casing Collar Locator Corrected As Per Log*** Curve Name (Abbrev. ) Standard Curve Name Logs Used Scale GR5 Gamma Ray Pass 5 CNL 0-100, 100-200 CCLS Casing Collar Locator Pass 5 " 0 - 1 CN6 Compensated Neutron Pass 6 " 60 - 0 GR6 Gamma Ray Pass 6 " 0-100, 100-200 CCL6 Casing Collar Locator Pass 6 " 0 - 1 Pf.:(E~VED :\ ¡\",,' ..., MnV 1 () 1982 M.. d.C::1 on & Gas C'::ms. CommJSJ . An~noragD on FILE=LA1507 PROG.RAM=LISTER ~'--~-'-_'~-'_""_~-'-_~---- -----------"--___~"""_k'n~_~_'_''''~R_''_W''--~'R_'_'h_'''''~_h_''-h'_."'_--'-----_W'''''---------- -------.--..---..--..-..-....-...-....-.. ECC NUMBER t5 Q_I~_O Q--------------- "--"'--'---"-'-'----"----"'''-'''-'_'_''_h'_h'h_-.~''-''''...........-..........---...-.............-. 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S~RvlC~ NAME: EDIT PF~L CONTINUATIUN NUMbER: 01 Pk~V lUUS REEL NAf'i1E:: CUMMENTS: LIS tURMAT CUSTUMER TAP~ DATE: 79/10/18 TAPE HE-AOER LENGTH: 132 bYTE.S TAP~ ~AME: 57011 S~RVIÇ~ NAME: EDIT TAPE CUNTINUATION NUMB~k: 01 p H f'~ V 1 U U S TAP t N A [<1 E ; COf'¡!!'i1r.3NTS: T APf~ cor\!ltv1~NTS CASJNG-DRILL~R 13.37@2730/TYPE DAlE: 79/10/18 FLUID HLANO/fLUIU LOSS 5.hML/O~NS 10.1/ Vise 50./PH 7.0/RM 4.44@80 f/RMf 5.91@56 f/RMC 4.48@57 fl t 't .. ;f' * .. f * * * * .f .¡: J- * .;: 'T' í;X} F .. .. * * * if .. ~ * ~ ~ *' *- * " * fILE. HE;ADEH J.}:~NGTH: 62 ß'tTl:..':> FI]JE: NAME: E:DIT' .001 MAXIMUM PHYSICAL RECORD L~NGTH: PFE; VI UUS F rllE. NAU¡J:.,: 1024 BïTES ~~q':LL S 111:. INfuRMA T ION RE:CORD LF,NGIH: CUíV1P ANï : vJr~LL : fJELD: RAf-vGt: TO\¡<4 N : S f:(, T I UN . COÚNl~(: . STP.TE: 185 BYT~S ATLAN1IC RICHFIELD CUMPANY Û.S 3-10 PRUDHOE BAY 1St iON 1 J N. SLUPt:; ALf\ SKA ! .~--=... . ~ ..~ ...... ,..' X. H 2:' (;¡J u;: { ....... ~~ .-, .....;. 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'750 NRAT' -999.250 N C I\i 1.1 -999.250 FC N ¡.J "'999.250 GR 26.984 DT -999.250 2800.000 SP -1019.250 1L.o -999.250 11.1/'\1\ -999.250 LIJBU -999. ,250 GR -999.250 CALI "'999.250 DHHIJ .'999.250 NPHi -9\J925.00Q RHUB ""999.250 NHAI' -999.250 1\1 C N lJ -999.250 r,'C N L. ...999.250 GR 15.734: DT -999.250 2700.000 SP -1019.250 llJD -999.250 lLNi .999.250 lJl.J8U -999.250 Gf< -999.250 CAld, -999.250 DRHU -999.250 NPHI -99925.000 RHC.IB ..,999.250 NHA'r -999.250 NCNL .,999.250 fCNL -999.250 GR 19.984 01" "'999.250 2670.500 SP -1019.250 JlIl) -999.250 I II JVI -999.250 L¡L,8U -999.250 GF~ "'999.250 CAllI -999.250 DRHO -999.250 NPl'll -99925.000 RHUb ",999_250 NHAT -999.250 1\1 CN I, -999,250 F'CNL -999.250 GR 23.781 DIl' -999.250 ( ( ( .jo S" l) ~ U \l "J'. L .("A' ;'11' DG'C"'(,l')S , 1>.,...~,r\ .1 t I" ) ,1-\["',,",. ,~ '( l. ., NUMB~R O~ RECORDS: 892 LEN G .1' ,t.¡ (..I fi R E. C U H D S : 9 6 0 .t.i 'i '.r f~ S LENGTH 0F LASt R8CORD: 966 BYTES ~ * * * f + * FIL~ THAILER LENGTH: 62 SYT~S F'ILf:NAME: . ,E;!)lT .001 M A X 1 ¡Iii U Iv) PH Y S 1 C A lj F F; CUR D L E ï\1 G 'I' H : . N EX T F lIJ E; NAME: * * 1024 BYTES * t EOf * * * * * * * * * *, * TAPE tHAILER * LENGTH: 132 BYTES TAPE NAME: 57011 SERVIC~ NAME: ~DIT TAP~ CONIINUATION NUMbER; 01 NEXT TAPE NAM~: COMM~NTS: . * * * DAT~: ) * * * * * * 19/10/18 * * * * * * * * . * * * ) /; * * * * * * ,t DRESSER ATLAS 716 TAPE FORMAT THE LA716 TAPE FORMAT CONSISTS OF A HEADER RECORD CONTAINING PERTINENT INFORMATION CONCERNING THE WELL (SEE BELOW) FOLLOWED BY THE DATA RECORDS. QATA RECORDS CONTAIN A FIXED NUMBER OF FLOATING POINT SAMPLES(AS OEFINED BY THE HEADER RECORD) OF EACH CURVE. THE DATA FOR CURVE 1 IS FOLLOWED SY THE DATA FOR CURVE 2 ETC. IN EACH DATA RECORD. THE RECORD SIZE MAY BE COMPUTED BY THE FOLLOWING EQUATION: NUMBER BYTES = NUM*FEET* ~ IA'HERE NUM = NUMBER OF CURVES ON THE TAPE (MAX. 20) FEET = NUMBER OF SAMPLES OF EACH CURVE PER RECORO(I.E.. 125) { ~," f { ******************************************************************************** * HEADER RECORO-------ASCII * *FIELD FIELD DESCRIPTION POSITION CHAR. # OF ByTES* * ST ART STOp * * 1 EPILOG COMPUTATION NUMBER 1 4 FP 4 * * 2 COMPANY NAME 5 84 AN 80 * * 3 WELL NAME 85 164 AN 80 * * 4 NUMBER OF CURVES ON TAPE 165 166 INT 2 * * 5 FILLER 167 168 2 * * 6 CURVE NAMES 169 248 AN 80 * * 7 TAPE STARTING DEPTH 249 252 FP 4 * * 8 TAPE ENDING DEPTH 253 256 FP 4 * * 9 DATA LEVEL SPACING 257 260 FP 4 * * 10 DEPTH COLUMN (=0) 261 262 INT 2 * * 11 FILLER 263 264 2 * * 12 NUMBER OF SAMPLES PER CURVE 263 268 FP 4 * * PER RECORD * * 13 FILLER 269 276 8 * *******************************************************************~************ ( { ( ( ( ( THE LAST RECORD ON TAPE IS FOLLOWED BY A DOUBLE END OF FILE MARK, ( THANKS. ( ECC NUMBEH 681.00 ( ARea OIL AND GAS----ORILLSITE 3-10 716 LIBRARY PRUDHOE BAY---~11-10N-15E,UM----NORTH SLOPE COUNTY. ALASKA DCC#6S1 ( 8 CURVES: GRI GR2 Kl TH1 TH2 Ul K2 U2 ( FROM 9090,00 TO 9800,00 LEVEL SPACING 0.5000 125. SAMPLES PER RECORD ( ( PE DS.3-/õ ~ PAGE 1 ARCO OIL AND GAS..-...-DRILLSITE 3-10 716 LIBRARY DCCtt681 PRUDHOE BAY----l1-10N-1sE,UM----NORTH SLOPE COUNTY, ALASKA GRl GR2 K1 K2 U1 U2 THl TH2 ( 9090.00 75.10 -0.18 2.14 -0.00 6.00 -0.19 10.00 0.00 9090.50 75.10 -0.09 2.14 0.00 6.00 -0.16 10.00 0.00 ( 9091.00 75.10 -0.01 2.14 0,01 6.00 -0,12 10,00 0.01 9091.50 75,10 0.08 2.14 0.01 6.00 -0,09 10.00 0.01 9092.00 75.10 0.17 2.14 0.02 6.00 -0.06 10.00 0.02 9092.50 75.10 0.25 2.14 0.02 6.00 -0.02 10.00 0.05 ( 9093.00 15.10 0.34 2.14 0.02 6.00 0.00 10.00 0.08 9093.50 75.10 0.43 2.1Lf 0.03 6.00 -0.02 10.00 0.11 9094.00 75.10 0.63 2.14 0.03 6.00 ...0,04 10.00 0.14 ( 9094.50 75,10 0.83 2.14 0.03 6.00 ...0.06 10.00 0.17 9095.00 75.10 1,04 2.14 0.04 6.00 -0.08 10.00 0.20 9095.50 -0.40 1.24 0.01 0,04 -0.30 -0.10 -0.35 0.23 ( 9096.00 -0.37 1.45 0.00 0.04 ...0.30 ",0.12 -0.40 0.32 909£)850 ...0.20 1.66 0.00 0.05 .0.30 ...0,14 ...0.'+0 0.41 9097.00 "'0.02 3.65 0.00 0.05 ...0.27 -0.17 -0.39 0.51 ( 9097.50 2.04 75.73 0.00 0.05 ...0.23 -0.16 -0.39 0.60 9098.00 91.11 90.14 0.00 0.06 ",,0.05 0.42 0.04 1.42 9098.50 96.36 99.84 0.00 0.06 0.65 21.79 0.'+7 2.72 ( 9099.00 102.28 123.56 0.04 0.19 1,71 24.52 1.10 5.41 9099.50 102.61 129.Lf.6 0.11 1,48 4.28 25.87 2.48 8.76 9100.00 124,02 138.29 1.91 1.63 13.55 26.80 25.57 16.79 ( 9100.50 135.94 132.52 1.87 1.84 12.92 25.63 31.56 20.34 9101,00 130,78 125.54 2.13 1.81 13.03 21.14 28.96 23.37 9101.50 126.98 119.94 2.16 1.29 12,35 14.00 23.72 25.61 ( 9102,00 122.02 113.89 2.10 1.67 10.37 11.10 19.54 23.98 9102.50 115.54 109.96 2.42 1.76 9,09 8,87 17.86 21.77 9103.00 95.78 106,82 2,69 1.84 7.59 6.60 19,77 18.56 ( 9103.50 92.83 98.88 2,91 2.00 6.10 6.43 21.76 17,22 9104,00 88.26 93.14 3.00 2.19 6.96 7.10 20.79 15.60 9104.50 84.98 87.54 2,29 2.44 8.31 8,97 13.16 14.15 ( 9105.00 82.02 84.19 2.35 2.09 7.21 10.24 10.54 12.32 9105.50 80.46 82.52 2.42 1.35 7.81 11.05 1 0 . 18,; 11.21 9106.00 87 . 07 86.08 1,98 1.14-3 8.89 11.41 12 44; 10.10 " ( 9106.50 91.86 92.64 1.57 1.62 18,20 11.98 14.60, 9.14 9107.00 97.63 107.76 1.65 1.66 19,79 12.55 13 . 5 O. 11.00 9107.50 110.91 114.81 1.90 1.87 18.04 16.79 12.56 14.87 ( 9108.00 160.92 127.93 2.14 0.99 14.39 19.88 16 . 0 1,. 16.71 9108.50 111.75 169.33 2.48 1.04 18.16 21.99 19,10", 19.18 9109.00 184.99 193.83 3.18 0.92 21.44 23.67 21.1$ 27.35 ( 9109.50 159.24 17'+.40 3.55 1,52 23,98 27.79 23.23 27.55 9110.00 144.85 162.68 1.68 2.12 24.77 25.46 25.29 23.44 9110.50 135.92 141.72 1.85 1.35 23.73 27.06 27.0Q 19.87 ( 9111.00 119.85 120.67 1.91 1.77 21.53 19.34 25.10 17.65 9111.50 111.57 109.78 1.68 1.60 19.32 16.67 12.92- 16.32 9112.00 96.93 99.72 1,28 1.41 21,66 17.96 10.80 13.60 { 9112,50 98.58 97.12 1.04 1.18 23.07 19.54 11.05 14.B6 9113.00 99.74 114.70 1.43 1.00 22.98 20,95 14.31- 16.24 \~: 9113.50 146.79 153.75 1.73 1.11 23.98 20.11 15.68 17.65 9114.00 152.64 163,37 1.96 1.57 28.39 20.64 16.69 19.57 9114.50 156.80 159.73 2.07 1.85 25.27 22.45 17.69 20.61 9115.00 156.58 158.81 2.53 2.11 27.42 24.26 18,05 15.14 PAGE 2 ARCO OIL AND GAS----DRILLSITE 3-10 716 LIBRARY OCC#681 I~, PRUDHOE BAY----l1-10N-15E,UM----NORTH SLOPE COUNTY. ALASKA GR1 GR2 Kl K2 U1 U2 TI-11 TH2 { 9115.50 154.84 159.07 2.86 2.69 28.47 26.26 15.59 16.10 9116.00 155.70 161.19 2.40 2.85 28.48 20.60 12.34 17.06 9116.50 154.63 164.08 2.37 2.46 27,38 22.28 11.57 18.28 f 9117.00 155.75 167.47 2.10 2.05 28.58 21.59 14.41 17.77 9117.50 160.49 168.70 2.25 2.02 29.20 21.35 16.12 19.41 9118.00 163.82 162.38 2.44 1.26 2'3.81 23.09 17.62 21.25 ( 9118.50 153.33 158.18 2.11 1.12 25.40 24.52 17.72 23.03 9119.00 147.92 154.19 2.13 0.79 26.53 25.'77 16.70 20.49 9119.50 145.03 148.75 2.74 1.39 24.58 26.27 17.71 17.64 ( 9120.00 142.15 143.21 3.00 1.41 23.17 28.03 12.54 17.93 9120.50 139.27 139.52 2.23 1.27 21.11 22.45 9.84 18.99 9121.00 129.44 135.75 2.66 1.88 19.26 20.94 8.08 17.16 ( 9121.50 126.93 136.39 2.81 2.21 19.35 20,16 8.62 15.00 9122.00 130.38 136.65 2.49 2.38 20,71 19.60 9.83" 15.97 9122.50 126.38 128.08 2.34 2.16 17.16 19.26 11.05' 16.61 ( 91.23.00 123.71 129,14 2.88 2.04 18.05 20.31 I 11.48¡ 15.83 9123.50 124.34 131.69 3.11 1.91 16.32 21.02 13.491 16.40 9124.00 128.15 133.19 3.26 1.26 16.88 22.5lf 15,71,: 17.73 ( 9124.50 121.67 129.38 3.13 1.04 15.88 23.91", 16.05! 19.40 9125.00 119.80 128.38 2.63 0.86 16.22 21.79 14.551 18.58 9125,50 121.11 128.35 2.23 1.23 16.84 21.52 15.481 16.44 If 9126.00 125.09 128.51 1.96 1.52 17,46 23.49 1 7 . 85} 15.46 9126.50 126.32 128.22 2.14 1.67 13,86 19.83 1 9 . 29; 16.93 9127,00 127.32 127.78 2.15 1.52 13.10 24.01 19.19, 18.40 (' 9127.50 128.46 133.52 2.48 1.98 20.20 24.69 I 19.44 18.071 9128.00 130.23 137.61 2.23 2.47 21.19 23,07 1 Ii . 7 5; 17,83 9128.50 132.95 1'+1.70 2.39 2.83 20,02 19,72 17.0t.¡! 16,22 ( 9129.00 136.56 150.62 2.91 2.57 19,54 18.77 16.21 15.72 9129.50 144.47 165.57 3.40 2.82 20.19 20.84 16.57 16.84 9130.00 160.01 184.12 3.55 3.10 21.07 23.11 18,13 17.95 ( 9130.50 167,37 188.56 3.34 3.45 21,95 24.15 19,69 17.30 9131.00 177.82 192.99 2.96 2.'+3 22, 7L. 27.95 21.2Lf. 18.71 9131.50 182.28 192.73 2.69 2.19 23.62 29.65 23.0~ 20.13 ( 9132,00 185.15 184.55 2.57 2.52 24.69 31.«+5 24.22 18.71 9132.50 185.11 185,27 2.82 2.69 29. 4 (+ 33.38 21,45 17.21 9133.00 182.23 187.26 2.95 2.45 28.22 34.14 16.30 16.20 ( 9133.50 178.99 189.29 2.80 2.34 27.85 33.83 20.00 15.53 9134.00 181.06 191.02 2,82 2.36 28,11 34.81. 20.87 17.62 9134.50 180.82 183.98 2.99 2.34 31.97 34.60 19.30 19.47 ( 9135.00 176.43 174.87 2.00 2.49 28,62 36.29 17.72 19.06 9135.50 171.41 161.53 2.53 2.11 25.49 25.40 1 9 . 91- 18.01 9136.00 166.16 150.99 2.12 2.48 25.10 29.13 18.32 16.96 If 9136.50 154.13 147.52 2.54 2.70 24.67 27.13 13.56 16,13 9137.00 145.99 146.52 2.66 2.92 2£4..72 18.46 11.07 15.25 913"7.50 140.61 145.53 2.42 3.14 26,14 19.02, 9,24 15.50 ( 9138.00 1.37.1'+ 146.09 3.49 2.98 21.10 20.70 11.03 16.74 9138.50 139.25 148.88 3.25 2.90 21.72 22.15 12.86 18.90 9139.00 143.82 154.66 2.93 3.06 20.36 23.61 15.06. 20,50 9133.50 149.33 157.76 2.89 3.14 20.60 25.06 17.25 21. (32 9140.00 155.41 140.71 2,41 2.98 20,59 26.67 19.11 23,52 9140.50 152.61 136.18 2.29 2.76 21,24 26.01 19.33 18.29 f ( PAGE 3 ARCa OIL AND GAS---...ORILLSITE 3-10 716 LIBRARY DCC#681 { PRUDHOE BAY----I1-10N-15E,UM-...--NORTH SLOPE COUNTY, ALASKA GRl GR2 Kl K2 U1 U2 THl TH2 ( 9141.00 142.25 133.94 2.51 2.20 21.66 23.27 18.08 15.67 9141.50 134.96 131.16 2.73 2.54 21.76 18,04 16.64 14.14 9142.00 128,66 130.17 2.27 2.76 17.40 18.78 14.37 14.97 ( 9142.50 124.91 129.16 1.84 2.98 14.75 17.41 14.00 16.83 9143.00 122.77 128.60 1.65 2.94 16.63 16.93 13.06 19.84 9143.50 120.74 128.02 1.62 2.79 18.37 15.82 13.20 21.54 ( 9144.00 119.11 127.36 2.01 2.77 19.29 14.08 13.77 24.45 9144.50 116.25 122.15 2.29 2.42 20.21 13.'+6 14.34 18.26 9145.00 115.76 118.76 2.49 2.39 18.36 1'+.81 14.62 19.09 ( 9145.50 115.77 119.23 2.65 2.62 14.98 12.07 15.02 19.92 9146.00 116.17 121.88 2.68 2.60 14.44 13.52 17,52 23.90 9146.50 117.51 125.20 2.41 2.85 15.21 16.26 16,02 22.25 (' 9147.00 116.05 119,06 2.48 2.72 16.28 11.11 14.53 18.37 9147,50 98.05 103.09 2, .12 2.52 17.30 18.53 11.40 19.10 9148.00 95.48 90.91 1.72 1.'+6 18.28 16.57 9.14 15.72 f, 9148.50 87.3~ 86.16 1,61 0.97 17.05 19.'+5 9.58 13.15 9149.00 85.36 85.00. 1.50 0.81 15,27 19.15 7,82 11.55 91"'9.50 95.99 99.50 2.15 1.33 15.64, 15.82 9.01 10.59 ( 9150.00 102.39 103.26 2.19 .1.82 15,13 17.13 10.44 13.90 9150.50 107.32 108,67 3.12 2.10 13.57 14.60 11,86 16.85 9151.00 102,88 114,04 3.30 2.36 11,76 15.05 13.27 18.38 (' 9151,50 108.86 119.39 3.41 2.58 11.92 15,39 14,67 16.78 9152.00 111.93 122.13 3.'+8 2.78 13,39 14,01 16.07 15.76 9152.50 113.75 119.27 3.27 2.76 1t+.04- 15.08 17.39 14.07 (' 9153.00 112.60 117.45 2.97 2.57 13.79 13.96 17.89 17.02 9153,50 111,46 115.72 2,79 2.50 14.L+4 11.96 15,8:3. 19.04 915q.,OO 112.26 114.96 2.85 2.'+2 15.23 11.07 13,441 18.81 ( 9154,50 112,29 115.28 2.60 2.31 15,99 13,20 12,16 16.74 9155.00 111.45 116.73 2,11 1.99 17,20 14.96 14,41: 15.06 9155.50 110.60 118.19 2.36 2.15 15.55 16.37 16.65 14.81 (, 9156.00 112.57 105.78 2.39 1.87 13.'+ 0 16.72 1 7 . If 6.: 13.73 9156.50 111.14 101.89 1.60 1.40 10.66 15.57 15. 77" 15.66 9157.00 95,70 100.57 2.01 1.19 9.25 16.53 16 . 53\. 17.38 ( 9157.50 91.'+7 97.40 2.27 1.05 8.15 17.53 1 7 . 13. 17.88 9158.00 90,15 91.33 1.99 0,90 9.25 14.38 16,95 18.29 9158.50 85.85 87.60 2.17 1.31 11.09 11.27 14.83 12.98 ( 9159.00 83.86 84.98 2.42 1.66 9.65 9.'+0 13,1'+ 13.59 9159.50 81.17 83.21 2,20 1.91 8.28 6.90 11 . 6~t 15.67 9160.00 81.59 82.65 1.75 1.89 9,98 6.65 10.56 17,78 ( 9160.50 83.61 86.56 1.59 1.19 11.51 9.58 10.0.5 19.50 9161.00 86.30 87.72 1.75 1.92 12.47 10.82 10.18 13.95 9161.50 86.98 87.03 1.31 1.88 11.00 10.32 9.26. 14,.67 ( 9162,00 84.95 84.21 1.'+9 2.11 12.88 10.05 12.0.8 14.28 9162.50 82.40 81.18 1.83 1.56 11.10 10.55 13 .l~2. 12.98 9163.00 80.10 78.41 2.05 1.28 8.34 11.05 11.68 13.36 ( 9163.50 79.43 75.81 1.97 1.03 7.83 9.85 15.0.5 10.12 9164.00 78.06 76.24 1.93 0.90 8.76 10.51 15 . 0 1. 12.15 9164.50 75.65 79.22 1.90 1.03 8.77 8.61 13. 0 9. 14.16 ~ 916fj.00 78.29 80.86 1.91 1.17 10.59 7.90 11 . 18. 14,53 9165.50 79.38 79.56 1.71 1.00 11.91 10.16 9.71 14.23 9166.00 80.69 82.18 1.25 0.96 12.75 13.12 9.7:3 11.37 .~ .' .~. f PAGE 4 ( ARea OIL AND GAS----DRILLSITE 3-10 716 LIBRARY oec#:t681 PRUDHOE BAY----11-10N-15E.UM----NORTH SLOPE COUNTY. 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'.~ g 0 q. .:"1, G 5 0 8'";(1.35 e69.2~¡ 933. 76 l' -O.8'+ 80.1.3 SGT.5(; 929.07 '+0.56 7B.28 873.97 933.98 '+0.96 77.65' 810.Ql 9,+ 9. f 90q.9"DO 8?g'Q gGB.7g 940 .23 4.0.. 60 P,6.40 ß&7.73 931.~6 '+0 .32 79.86 875.50 935'. ()9 Lf.l.'+l 7 B ,. 98 810.q.~' 950 . ~ 9 (ì '+ q 'II 5 n go. Of.) P,G6.. R3 9~2..77 l~O.95 e.O.35 859,.72 928.50 40.20 80 .6'+ 878.06 936.32 41.20 79.25 810.95: 9:59.1 , \..,Þ P B 2)S....3 -/ð G-~seJ holeJ LIBRARY TAPE CURVE SPECIFICATIONS Company Well Arco Oil & Gas RECE1VED DS 3-10 p.r:;r:; - 2 L~' 1 . Field Prudhòe Bay lijas\<a Oil & Gas Cons. Commission Aflchorage Date 3-20-81 County,State North Slope, Alaska Curve Name (Abbreviated) Standard Curve Name Logs Used Scale FILE ONE COR Correlation Capture LOQ Gamma 45--15 MON Mònitor II 0-120 SI Silicon II. 0-60K CA Calcium " O-60K SICA Silicon Calcium Ration " 1-5 CORF Correlation " 45--15 MONF Monitor " 0-120 SIF Silicon " 0-60K ....FE Iron " '0-60000 .. SIFE Silicon/Iraon Ratio " 1-5 COR1 Correlation " 45--15 MON1 Monitor " 0-120 SIl Silicon " 0-60K CAl Calcium " 0-60K SC1 S i 1 i c on/ C a l'c i urn Ration " 1-5 FILE TWO COFl Correlation CaDture Lop" Gamma 45--15 Mo . 1 ,, - MOF1 nltor 0 120 ~ ~. LIBRARY TAPE CURVE SPECIFICATIONS Company Well Areo Oil & Gas DS 3-10 Field Prudhóe Bay County, State North Slope, Alaska Date 3-20-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale SIF1 Silicon Capture Log Gamma 0-60K FE 1 Iron " 0-60000 SF1 Silicon/Iron Ration " 1-5 MOE Monitor " 0-120 COE Correlation " 45--15 HE High E " 0-60000 , LE Low E " 0-60000 LEHE Low/High E Ratio " 1-5 - FILE THREE GR4 Gamma.Ray Pass 4 CN/Multispace 0-80 LS4 Long Space Pass 4 " 0-2000 SS4 Short Space Pass 4 " 0-2000 CN4 Compensated Neutron Pass 4 " 60-0 GR3 Gamma Ray Pass 3 " 0-80 LS3 Long Space Pass 3 " 0-2000 SS3 Short Space Pass 3 " 0-2000 CN3 Compensated Neutron Pass 3 " 60-0 GR2 Gamma Ray Pass 2 " 0-80 LS2 Lon S ace Pass 2 I " 0-2000 g p LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil & Gas Well DS 3-10 Field Prudhoe Bay -1' County,State North Slope, Alaska Date 3-20-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale SS2 Short Space Pass 2 Capture Log Gamma. 0-2000 CN2 ComDensated Neutron Pass 2 " 60-0 . , GR1 Gamma Ray Pass 1 ' " 0-80 LS1 Long Space Pass 1 u 0-2000 SSl . Short Space Pass 1 " 0-2000 CNl - Compensated Neutron Pass 1 " 60-0 - -. ,'- LIBRARY TAPE CURVE SPECIFICATIONS PB DS 3-/ð (C'df-S e J h () /~ Company Arco Oil & Gas Co. Well DS 3-10 Field Prudhoe Bay County,State North Slope, Alaska Date 12-19-80 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale 100-200 GR4 Gamma Ray CN 0-100 SS4 Short Space CN 0-2000 LS4 Long Space CN 0-2000 NEU4 Compensated Neutron CN 60-0 .....- 100-200 GR3 Gamma Ray CN 0.100 SS3 Short Space CN 0-2000 "'"--- L53 Long Space CN 0-2000 _- NEU3 Compensated Neutron CN 60-0 ¡-..-....-.---- - ..^^ '"'^^ ,- .lV'-' ,,"VlJ GR2 Gamma Ray CN 0-100 --'-"-'''' NEU2 COIDDensated Neutron CN 60-0 100-200 GRl Gamma Rav CN 0-100 NEUl Comuensated Neutron CN 60-0 f---. -- -- ? t'. r~ E \ 1 iI, T L /\ !\! 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