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Home My WebLink About201-112 Ima~ Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~,~ O L- _[ J c~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: /~ Diskettes, No. o~, [] Maps: OVERSIZED (Scannable) [] Grayscale items: [] Poor Quality Originals: E] Other: NOTES: Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~WINDY. [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation ~ x 30 = ~-')('~ Ill Illllllllll II I]I BY: BEVERLY ROBIN VINCENT SHERYLj~ARIA.,)WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~f YES BEVER OBIN ~ ENT (~.l__} S [~ERYL MARIA WINDY DATE: l l- ] ~'' C,~! ~ IF NO IN STAGE 1: PAGE(S) DISCREPANCIES WERE FOUND: __ YES ., (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO I I I RESCANNEDBT: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is~ Quality Checked 12110/02Rev3NOTScanned.wpd RECEIVED • STATE OF ALASKA • DEC 2 7 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 4OGCC la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class • 20AAC25.105 20AAC25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero . ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., orAband.: 12. Permit to Drill Number: BP 12/3/2012 201 -112 , 312 -380 Exploration (Alaska) Inc. 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 9/9/2001 50 029 - 20707 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 9/16/2001 PBU D -19B • 1880' FNL, 1692' FEL, Sec. 23, T11N, R13E, UM • 8. KB (ft above MSL): 76 • 15. Field / Pool(s) Top of Productive Horizon: Prudhoe Bay /Prudhoe Ba 1583' FNL, 2571' FEL, Sec. 23, T11N, R13E, UM GL (ft above MSL): 41.45' Y Bay , Total Depth: 9. Plug Back Depth (MD +TVD) 1150' FNL, 3421' FEL, Sec. 23, T11N, R13E, UM 8810' 8630' 4b. Location of Well (State Base Plane Coordinates, NAD: 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x - 653467 ' y- 5959108 ' Zone- ASP4 • 10230' 9033' • ADL 028285 • TPI: x - 652581 y- 5959387 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 651722 y- 5959803 Zone- ASP4 None 18. Directional Surve y : 19. Water depth, if offshore: 20. Thickness ef-Permmafrost (TVD): ❑ Yes _� No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, GR, RES, PWD, DEN, NEU 6231' 6084' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu yds Concrete 13 -3/8" 72# L -80 Surface 2702' Surface 2702' 17 -1/2" 3549 cu ft Permaftost II 9 -5/8" 47# L -80 _Surface 6231' Surface 6084' 12 -1/4" 1177 cu ft Class 'G', 130 cu ft PF 'C' 7" 26# L -80 6079' 8694' 5943' 8516' 8 -1/2" 230 cu ft Class 'G' 4 -1/2" 12.6# 13Cr80 8528' 10227' 8352' 9033' 6 -1/8" 270 cu ft Class 'G'_ 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 12.6 #, 13Cr80 8527' 8461' / 8285' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. LIAR d 6 2013 WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No SCANNED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8810' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 9 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No • Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBc MS DEC 2 8 2011 Form 10-407 Revised 10/2012 Submit Original Only 0 CONTINUED ON REVERSE /� / 2 ,� 7 / Z ✓' 0 2 .iT-'3 G } 29. GEOLOGIC MARKERS (List all formations an rkers encounter 30. FORMATION TESTS • NAME TVD Well Tested. Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 8687' 8509' None Shublik A 8714' 8536' Shublik B 8748' 8569' Shublik C 8766' 8587' Sadlerochit / Zone 4B 8782' 8603' Zone 4A 8871' 8689' Zone 3 8978' 8790' Zone 2C 9055' 8859' Zone 2B 9126' 8916' Zone 2A 9267' 9008' HOT 9358' 9042' Formation at Total Depth: 31. List of Attachment: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston, 564 5 Email: David.Johnston2 @bp.com Printed Name: Title: Drilling Technologist Jo La a n Signature: Phone 564 - 4091 Date: 12.12110—, 0—, v INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation 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 13: 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 28. Item 23: Attached supplemental records for this well 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. Form 10-407 Revised 10/2012 Submit Original Only • • D -19B, Well History (Pre Rig Sidetrack) Date Summary 10/28/12 T /I /O 1260/320/260 Temp= HOT Assist E -Line (set whipstock) Freeze protect flowline with 10 bbls meth, 64 bbls crude. PSI flowline to 1500 psi. Load tubing with 3 bbls meth, 223 bbls 1% KCL. Freeze protect with 40 bbls diesel. Load well with 41 bbls diesel prior to whipstock set. Job continued on 10 -29 -12 WSR. 10/28/12 PRIOR TO ARRIVAL, LRS S/I & FREEZE PROTECT FLOWLINE. INITIAL T /I /O = 2450/0/125 PSI. RIH W/ WELLTEC MILLER TOOL W/ 3.806" MILL, MILL XN NIP AT 8515'. DRIFT THRU XN NIP AND PULL 5 UP PASS FROM 8536' -8350' - NO RESTRICTIONS. RECONFIRM MILL BIT= 3.806" AFTER POOH. LRS PUMPED 3 BBL METH, 223 BBL 1% KCL, 40 BBL DIESEL. RIH AND SET 4 -1/2" BAKER KB PACKER WHIPSTOCK AT 8802' ORIENTED 145 DEG ROHS . CCL TO TOP OF WHIPSTOCK = 17.8'. 8 16 2 CCL STOP DEPTH = 8784.2'. 2 RA TAGS INSTALLED 9' FROM TOP OF WHIPSTOCK. 10/29/12 MIT -T PASSED to 2000 psi. Pumped 12 bbls diesel to achieve test pressure. Tubing lost 11 psi in 1st 15 min and 5 psi in 2nd 15 min for a total loss of 16 psi over 30 min test. Bleed tubing psi, approx 2 bbls. FWHP 0/0/97 SLB on well at departure. 10/29/12 DIFFICULTY ORIENTING WHIPSTOCK AT SETTING DEPTH. ADDITIONAL PASSES REQUIRED TO CORRECTLY ORIENT WHIPSTOCK. WHIPSTOCK TOP SET AT 8802'. CCL TO TOP OF WHIPSTOCK = 17.8'. CCL STOP DEPTH = 8784.2'. RA PIP TAG = 8811'. UPON FIRING TO SET WHIPSTOCK, TELEMETRY WAS LOST. UNABLE TO POWER TOOL BACK UP AFTER SETTING. GOOD CONFIRMATION OF WHIPSTOCK SET, HOWEVER UNABLE TO LOG FROM SETTING DEPTH. BEGIN POOH. MIT -T AT 2000 PSI PASSED. WELL SHUT IN ON DEPARTURE. FINAL T /I /O = 0/0/100. 11/17/12 T /I /O= Vac /50/50; Conduct PJSM; Start Barriers List, barriers= SSV and MV verified by applying 300 and 3500 psi against SSV for 5 min. LTT Passed and Charted for Rig pressure test record; R/U lubricator with TWC and test against SSV to 300 and 3500 psi for 5 min. LTT passed; Open Barriers and Set 6 -3/8" CIW "J" TWC #423 thru tree for Nordic 1 Pre -CTD Torque & Test using Cameron lubricator #48 -840, tagged @ 130 "; S/I barriers and c/o setting tool for pulling tool and re- install lubricator on tree; Torque tree to API specs. using Hytorq pump #2, ratchet head #1 and power head #1; * * *NO MOVEMENT ON ANY STUDS * ** Test lubricator to 300 and 3500 psi for 5 min. LTT passed; Open barriers and Shell test to 250 and 5000 psi for 5 min. LTT passed and charted; Pull TWC, RDMO and test Tree -cap against SV to 300 and 3500 psi for 5 min. LTT passed and charted for Rig Pressure Test Record. 11/18/12 T /I /O = SSVNAC /62. Temp = SI. Bleed IAP & OAP to 0 psi (Pre CTD). AL SI & blinded @ casing valve, ALP = 0 psi. OA FL near surface. Bled OAP to slop trailer from 62 psi to 0 psi in 1.5 hrs. Monitor for 30 min. OAP increased 4 psi, Held open bleed for 1 hr. Monitor for 1 hr. Pressure syayed at 0 psi. Job complete. Final WHPs = SSVNAC /0. SV, WV, SSV, MV = C. IA, OA = OTG. 01:00. 11/20/12 T /I /O = SSVNAC /8. Temp = SI. WHP's (Pre CTD). ALP = 0 psi, AL SI & blinded @ casing valve. OAP increased 8 psi in 2 days. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 0330 hrs. Page 1 of 1 • • • . + Common Well Name: D -19 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/1/2012 End Date: X3 012WL C:DRILL (2,273,392.00 ) Project: Prudhoe Bay Site: PB D Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 4/24/1982 12:OO:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: D -19B: @76.42ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/1/2012 10:00 - 11:30 1.50 MOB P PRE RIG DOWN. PREPAIR TO MOVE. ARRANGE SECURITY FOR ESCORT. 11:30 - 15:15 3.75 MOB P PRE MOVE RIG FROM E PAD TO D PAD. 15:15 - 18:00 2.75 MOB P PRE WELLS GROUP REMOVING TAPPED FLANGE ON BLOCK "T" ON TREE AND REPLACE BLIND FLANGE. - LINE UP RIG WITH WELL. PJSM. BACK RIG OVER WELL AND SET DOWN. 18:00 19:00 1.00 MOB P PRE RIG MOVED OVER WELL AND READY TO TAKE ON FLUIDS AND NU BOP. ACCEPT RIG AT 18:0OHRS PACK SNOW AROUND CELLAR, SPOT SAT OFFICE AND OUTSIDE EQUIPMENT. RIG UP CELLAR EQUIPMENT (I.E. CAGES AND DRIP PANS). 19:00 - 19:30 0.50 RIGU P PRE RU AND ESTABLISH WELL BARRIERS. INSTALL PRESSURE -GAUGE TO MONITOR PRESSURE IN TREE CAVITY. 19:30 - 22:00 2.50 RIGU P PRE NIPPLE DOWN TREE CAP AND NIPPLE UP BOP. INSTALL HOT TUB AND GRATINGS. - CONFIRM TREE BOLTS ARE MARKED. 22:00 - 00:00 2.00 RIGU P PRE COMMENCE GREASING CHOKE AND ALL VALVES ON RIGFLOOR, IN SHAKER ROOM, REEL HOUSE AND PIPESHED. SUCCESSFULLY MAG -TEST CABLE. 12/2/2012 00:00 - 00:30 0.50 RIGU P PRE FINISH GREASING. 00:30 - 01:30 1.00 RIGU P PRE RIG UP TT AND PRESSURE -TEST HARDLINE. INSTALL STAIRS TO RIG AND SPOT EQUIPMENT AROUND RIG. 01:30 - 02:45 1.25 RIGU P PRE FLUID PACK STACK AND MGS. DRAIN MGS. 02:45 - 03:10 0.42 RIGU P PRE CONDUCT RIG EVACUATION DRILL. HOLD AAR: GOOD RESPONSE BY CREWS, BUT IT WAS MENTIONED THAT THE AUDIBLE ALARM WAS NOT WELL HEARD INSIDE THE OPS CAB. 03:10 - 03:30 0.33 RIGU P PRE HOLD PRE -SPUD MEETING WITH ALL CREWS. 03:30 - 04:30 1.00 BOPSUR P PRE _ PERFORM FULL BODY SHELL TEST TO 250PSI LOW AND 4,500PSI HIGH. ACHIEVE GOOD TEST. PERFORM ACCUMULATOR DRAWDOWN TEST. - STARTING ACCUMULATOR PRESSURE = 3,000 PSI - FINAL PRESSURE AFTER FUNCTIONING ALL PREVENTERS AND HCR = 2,100 PSI - 10 SEC TO BUILD 200 PSI, 99 SEC TO FULL PRESSURE. - 3 NITROGEN BACKUP BOTTLES WITH 2,000 PSI. Printed 12/17/2012 1:29:01 PM Common Well Name: D -19 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/1/2012 End Date: X3- 012WL- C:DRILL (2,273,392.00 ) Project: Prudhoe Bay Site: PB D Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 4/24/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: D -19B: @76.42ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 11:45 7.25 BOPSUR P PRE CONDUCT BOPE PRESSURE ANP Fl IN(:TIfN -TFST PER NORDIC PROCEDURE, AOGCC REGS & DWOP POLICY. INSTALL 2 -3/8 X 3 -1/2" TEST JOINT AND PERFORM PRESSURE -TEST TO 250PSI / 5MINS AND 3,500PSI / 5MIN ON FOLLOWING ITEMS: - ANNULAR BAG #1 RAM - BLIND SHEARS oQ - #2 RAM - 2 -3/8" COMBIS (2 -3/8" TEST JOINT) - #3 RAM - 2 -3/8" x 3 -1/2" VBR (2 -3/8" TEST i t JOINT) - #4 RAM - 2 -3/8" COMBIS (2 -3/8" TEST JOINT) ALL RAMS CLOSED WITHIN LESS THAN 2 SECONDS. ALSO TESTED HCR AND ALL VALVES ON KILL AND CHOKE LINE AS WELL AS KILL AND CHOKE MANIFOLDS. SUCCESSFULLY TESTED ALL VISUAL AND AUDIBLE GAS ALARMS. SEE ATTACHED CHARTS. FUNCTION ALL RAMS FROM OPS CAB AND DRILLERS STATION WITNESS OF THE BOP TEST WAS WAIVED BY JOHN CRISP (AOGCC), BUT WITNESSED BY BP WSL & NORDIC TOOLPUSHER. 11:45 - 14:00 2.25 BOPSUR P PRE PUMP 40 BBL FRESH WATER INTO COIL FOR SLACK MANAGEMENT. STAB INJECTOR ON WELL. PUMP E -LINE SLACK BACK. TEST INNER REEL VALVE 250 PSI LOW AND 3500 PSI HIGH. SLOW LEAK IN VALVE. CHANGE VALVE AND RE TEST. 14:00 - 15:00 1.00 BOPSUR P PRE DISCONNECT INJECTOR FROM WELL. CUT 310' OF COIL. END OF E -LINE NOT FOUND. STAB INJECTOR ONTO WELL. PUMP FORWARD TO LOCATE E -LINE END. MAKE UP SLB COIL CONNECTOR PULL TEST TO 35K AND PRESURE TEST TO 4000 PSI TEST PACK OFF TO 4000 PSI. 15:00 - 17:15 2.25 BOPSUR P PRE MAKE UP BAKER UPPER QUICK CONNECT WITH DFCV. CONNECT INJECTOR TO LUBRICATOR. PUMP 60 BBL AT 3 GPM WITH 1241 PSI TO PUMP E -LINE FORWARD. TEST BAKER CHECK VALVES. DID NOT HOLD. REMOVE INJECTOR. CHANGE BOTH BPVS. RE TEST BAKER DFCV. REMOVE INJECTOR FROM WELL AND STAND BACK. CIRCULATE AT MINIMUM RATE. INSTALL NIGHT CAP ON LUBRICATOR. PRESSURE TEST LUBRICATOR AND NIGHT CAP TO 250 PSI LOW AND 3500 PSI HIGH. 17:15 - 17:45 0.50 BOPSUR P PRE RIG EVACUATION DRILL. CREW AND ALL THIRD PARY PERSONEL RESPOND. AAR CARRIED OUT. GOOD DRILL. Printed 12/17/2012 1:29:01 PM " Common Well Name: D -19 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/1/2012 End Date: X3- 012WL- C:DRILL (2,273,392.00 ) Project: Prudhoe Bay Site: PB D Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 4/24/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: D -19B: @76.42ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:45 - 18:15 0.50 BOPSUR P PRE OPEN UP WELL - OPEN UP TREE VALVES, SEE NO PRESSURE. OPEN UP CHOKE, OBSERVE NOW FLOW (OPSI WHP). 18:15 - 18:45 0.50 BOPSUR P PRE FLOWCHECK WELL FOR 30MINS. 18:45 - 19:45 1.00 STWHIP P WEXIT HOLD PJSM BEFORE MU MILLING -BHA (BHA #1). 19:45 - 20:20 0.58 STWHIP P WEXIT - MU BHA #1 WITH 2 -7/8" EXTREME MUD MOTOR AND 3.80" WINDOW MILL (3.80" NO -GO / 3.81" GO) AND STRING REAMER (3.79" NO -GO / 3.80" GO). 20:20 - 20:45 0.42 STWHIP P WEXIT STAB ON INJECTOR AND PRESSURE -TEST QTS TO 300PSV5MINS AND 3,500PSV5MINS. 20:45 - 22:30 1.75 STWHIP P WEXIT RIH AT 88FT /MIN WITH WINDOW MILLING BHA PUMPING KCL OFF THE TRUCK. MM -IN: 0.38BPM / MM -OUT: 0.89BPM, MM-IN: 8.28BPM / MM -OUT: 7.14PPG (FREEZE- PROTECT FROM WELL). 22:30 - 23:10 0.67 STWHIP P WEXIT SLOW DOWN TO 100FT /HR AND COMMENCE LOGGING FOR TIE -IN PASS ONWARDS FROM 8,730'. MM -IN: 0.95BPM / MM -OUT: 0.97BPM, MM-IN: 8.28BPM / MM -OUT: 7.62PPG - RETURNS TAKES LONG TO CLEAR UP. 23:10 - 23:15 0.08 STWHIP P WEXIT LOG DOWN TO 8,780'. STOP AND APPLY +1 FT CORRECTION. CONTINUE RIH SLOWLY. 23:15 - 23:45 0.50 STWHIP P WEXIT TAG TOP OF WHIPSTOCK AT 8,811'. PU TO 8786, OPEN EDC AND LINE UP TO 8.5PPG DRILL MUD. PiPc PVT = 297BBLS, MM-IN: 2.73BPM / MM -OUT: 2.74BPM, MM-IN: 8.48BPM (MUD) / MM -OUT: 8.37PPG (KCL). 23:45 - 00:00 0.25 STWHIP P WEXIT DRILL MUD AT THE MILL. TAKE SLOW PUMP • RATES. 12/3/2012 00:00 - 00:15 0.25 STWHIP P WEXIT DRY -TAG TOP OF WHIPSTOCK AT 8,810.6'. PU 3�Q�' AND BRING PUMPS ONLINE. �� "" RUN BACK IN TO 8,807' AND START {, -1 I L TIME - MILLING AT 1' /HR ONWARDS FROM O 8,809'. FREE SPIN: 1,963PS1 AT 2.7BPM / WOB: 0.40K LBS. 00:15 - 00:50 0.58 STWHIP P WEXIT AT 8,810' FIND PINCH POINT / TOP OF WHIPSTOCK. OBSERVE AN INCREASE IN MOTORWORK OF - 250PSI. CIRC PRESSURE: 2,219PSI / WOB: 0.21K LBS / PUMPRATE: 2.7BPM. 00:50 - 01:00 0.17 STWHIP P WEXIT NOTICE INCREASE IN CIRC - PRESSURE UP TO -2,500PSI (DRILL MUD NOW ALL THE WAY ROUND), HOWEVER MOTORWORK DOES NOT SEEM TO CHANGE BUT REMAINS AT 300PSI. PU, TAKE NEW FREESPIN: 2,520PSI AT 2.70BPM. 01:00 - 03:00 2.00 STWHIP P WEXIT RESTART TIME - MILLING AND SLOWLY RIH. . CIRC PRESSURE: 2,540PSI / WOB: 0.6K LBS / PUMPRATE:2.7BPM. Printed 12/17/2012 1:29:01 PM 94:1 �, �.�_,. �..... ✓ c' Common Well Name: D -19 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/1/2012 End Date: X3- 012WL- C:DRILL (2,273,392.00 ) Project: Prudhoe Bay Site: PB D Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 4/24/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: D -19B: @76.42ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 18:00 15.00 STWHIP P WEXIT NOTICE 1ST STALL. PU UP AND CONTINUE MILLING OPS. CIRC PRESSURE: 2,600 - 2,900 PSI / WOB: 3 - 4K LBS / PUMPRATE: 2.7 BPM. MILLING - PROGRESS IS FAIRLY SLOW. HAVE TO STOP 6 MIN / 10TH FOOT TIME - MILLING INTERVALS TO ALLOW MILL TO DRILL OFF. CONTINUE MILLING. AT 8814.9' MILLING PROGRESS SLOWS TO 10 MIN / 10TH FOOT. INCREASED WOB TO 4120-4260 AT 8816.8' MILLING PROGRESS INCREASED TO 6 -8 MIN / 10TH FOOT. WOB 4260 AT 8818.3' MILLING PROGRESS SLOWED TO A STOP AND THE MOTOR STALLED. PICK UP OFF BOTTOM TO 8810'. SLOWLY WORK MILL BACK DOWN. PUMP AT 2.9 GPM WITH 2501 PSI FREE SPIN. SLOWLY TAG UP ON BOTTOM RESUME MILLING AT 3 GBM WITH 2840 PSI 4150 WEIGHT ON BIT. MILL TO BOTTOM OF WHIPSTOCK TRAY. TOP OF WINDOW AT 8810' BOTTOM OF WINDOW AT 8819' MILL PENETRATE OPEN HOLE AT 8819'. MILL AT 2.9 GPM WITH 2780 PSI 2800 WOB MILL RAT HOLE. FIRST SAMPLE CAUGHT AT 8819.6' SHOWED 35% FORMATION 18:00 - 21:50 3.83 STWHIP P WEXIT COMPLETE MILLING RATHOLE TO 8,829'. 21:50 - 23:30 1.67 STWHIP P WEXIT PICK UP AND PERFORM 3 UP / 3 DOWN REAMING PASSES BETWEEN 8,829' TO 8,807'. SEE A LITTLE MOTORWORK INITIALLY, BUT NOT THEREAFTER. WINDOW IS CLEAN. 23:30 - 23:45 0.25 STWHIP P WEXIT PERFORM DRY DRIFT, NO ISSUES. 23:45 - 00:00 0.25 STWHIP P WEXIT FLOWCHECK WELL FOR 5MINS, ACHIEVE GOOD NO FLOW. 12/4/2012 00:00 - 01:30 1.50 STWHIP P WEXIT POOH WITH BHA #1TO SURFACE. 01:30 - 01:40 0.17 STWHIP P WEXIT "JOG" BACK IN HOLE TO 200FT AND FLOWCHECK WELL. OBTAIN GOOD NO FLOW. 01:40 - 02:20 0.67 STWHIP P WEXIT LD BHA #1. MILL GRADED AT 3.8" GO AND 3.79" NO GO. STRING MILL 3.79" GO AND 3.77" NO GO 02:20 - 02:45 0.42 DRILL P PROD1 MU BHA #2. 02:45 - 03:20 0.58 DRILL P PROD1 STAB ON INJECTOR AND PRESSURE -TETS QTS TO 300PSI / 5MINS AND 3,500PSI / 5MINS. 03:20 - 05:00 1.67 DRILL P PROD1 COMMENCE RIH. PVT = 260BBLS. 05:00 - 06:15 1.25 DRILL P PROD1 RUN PRIMARY TIE -IN LOG FROM 8,680' AND 8,811' AT 100FT /HR. CLOSE EDC 06:15 - 06:30 0.25 DRILL P PROD1 RIH. TAG BOTTOM AT 8826'. RECORD SLOW PUMP RATES. Printed 12/17/2012 1:29:01 PM 1 * TREE= 6" CIW • SAF1DNOTES: WELL ANGLE > 70° @ 9325'. VFELLFEAD = MCEVOY D-19B _ ACTUATOR = BAKER C *** 4-1/2" CHROME TBG & LNR** KB. REV = 764' BE Et _EV = 42.95' KOP 4250' Max Angle :r. 95"9566' 1 Datum ND= 90761 Datum TVD = 8800' 551 I I II1 2128' — 14-1/2 HES X NP, D - 3.813 13-3/8" CSG, 72#, L-80 BTRS, 0 = 12.347" --1 2702' GAS LIFT MANDRELS Minimum ID = 3.80" @ 8515' ST MD !VD DEV TYPE VLV LTCH FORT DATE 4-1/2" MILLED HES XN NIPPLE Li. 6 2988 2988 1 WMGM DMY RK 0 1 09/20/01 5 3729 3729 0 hilli/GM DMY RK 0 07/17/12 4 5270 5199 24 KBG2 DMY BK 0 07117112 3 6600 6441 5 KBG2 DMY BK 0 09/20/01 9-5/8" X 7 BKR ZXP PKR 6079' r 2 763517470 7 K8G2 DMY BK 0 09/20/01 w / 6' TEBACK, ID = 6.151" T 1 837318198 9 KBG2 DMY BK 0 09120/01 9-5/8" X r BKR FLEX-LOCK --1 6092' LNR HGR, ID = 6.151 9-5/8" MILOUT WINDOW (D-1913) 6231' - 6247' PERFORATION S1AIMARY 8440' 1— 4-1/2" HES X NP, 0 = 3.813" REF LOG: SPRY-SUN MIND RESISTIVTY ON 09/16/01 ANGLE AT TOP FERE 60° @ 9270' \\.\\\N Note: Refer to Production DB for historical perf data SIZE SR F INTERVAL Opn/Sqz DATE 8461' — 7" X 4-1/2" BKR S-3 PKR, 2-7/8" 6 9270 - 9290 0 01/17/10 0 0 _ D - 3 875" 2-7/8" 6 9290 - 9320 0 04/18/08 MI I '. 2-718" 6 9325- 9350 0 04/20/06 • 4 4 . 4 8484' —14-1/2" HES X NP, ID= 3.813" 1 2-7/8" 6 9325 - 9355 0 04/18/08 • ■• • • * ■ • . • . 4 2-7/8" 6 9380 - — 4-1/2° HES XN NP, 9410 0 04/18/08 8515' 4.4 2-112" 4 9750 - 10100 0 09/18/01 0 kV C MLLE!) TO 3.80" (10/29/12) ,....., rS4MSTI 8527' - 14 - 1/2" WLEG, ID = 3.958" 1 •40•40•4 ■•••••••4 r, .0404* 11 I 8528' _ 7 X 4-1/2" BKRZXP LTP • 4 • • • • • • # • • • • * 4 4 • o• • • • • • • • • • • * * * I / w / 6' TEBACK, D = 4.408" ■•••••••1 1' — 7 X 4-1/2 BKR HMC LNR 9-5/8" CSG 47#, L-80, ID = 8.681" H 8758' 1 I • M • N 8541' ■•••••44•1 HGR, Et = 4.410" 4...0.4 8548' - 14 - 1/2" X0 SUB, ID = 3.940" 1 7 LNR, 26#, L-80 U4S, .0383 bpf, 0 = 6 276" H 9618' t4.....0.01A I 4-1/2" TBG 12.6#, 13CR-80, .0152 bpf, 10= 3.958' 1—{ 8526' I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 8694' 1 . 4-1/2" BKR KB W-IPSTOCK (10/29/12) —{ 8802' I II PBTD 1— 10140' gr •■■'1 ....A 4-1/2" LNR, 12.6#, 13CR-80 VAM TOP, .0152 bpf, D= 3.958" H 10227' (ATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/12/82 ORIGINAL COMPLETION 07/19/12 C.IN/J1‘43 GLV CO (07/17/12) WELL: D-19B 06/11/96 PA B SIDETRACK COMPLETION 10/31/12 SET/JND IVILLED XN & WS (10129/12) PSRMIT No: 2011120 09/20/01 CHIKAK RIG SIDETRACK 1 irii PJC XN 1•8 API No: 50-029-20707-02 07/29/11 JJLJ PJC FLU WRP (07/14/11) SEC 23, TI IN, R13E, 1880' RI_ & 1692' FE.. 09/20/11 3.1 PJC TREE CIO (09116/11) I 11/09/11 CDJ/ PJC GLV CIO (10/30/11) BP Exploration (Alaska) ■ A • �w I �y� s , THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Main: 0 79.3 ALAS 907 2 433 SCANNED JAN 10 2013 Fax: 907.276.7542 John McMullen Engineering Team Leader Ov°1- - BP , Inc. Exploration Alaska p (Alaska), P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D -19B Sundry Number: 312 -380 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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. Foerster Chair DATED this {? day of October, 2012. Encl. 1 STATE OF ALASKA {� ALA KA OIL AND GAS CONSERVATION COMMISSION �` ` APPLICATION FOR SUNDRY APPROVAL OCT 0 4 z,` 20 AAC 25.280 1. Type of Request: A OG (0 ❑ Abandon ® Plug for Redrill . ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. . ® Development ❑ Exploratory 201 -112 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20707 -02 -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 D -19B • Spacing Exception Required? ❑ Yes 0 No 9. Property Designation: 10. Field / Pool(s): ADL 028285 • Prudhoe Bay / Prudhoe Bay ■ 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): 10230' • 9033' • 10140' 9033' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2702' 13 -3/8" 2702' 2702' 4930 2670 Intermediate 6231' 9 -5/8" 6231' 6084' 6870 4760 Production Liner 2615' 7" 6079' - 8694' 5943' - 8516' 7240 5410 Liner 1699' 4 -1/2" 8528' - 10227' 8352' - 9033' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9270' - 10100' 9009' - 9034' 4 - 1/2 ", 12.6# 13Cr80 8527' Packers and SSSV Type: 7" x 4 - 1/2" Baker 'S - Packer Packers and SSSV 8461' / 8285' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ■'_ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Johnston, 564 -5985 Printed Name Jo 4 - r -' J / Title Engineering Team Leader � Prepared By Name /Number. Signature / Phone 564 - 4711 Date /0 //2 Joe Lastufka, 564 -4091 Commission Use Only ` Condition • approval: Notify Commission so that a representative may witness Sundry Number l Z/ ❑ Plug Integrity 121 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Ate Other: 3.5151) ,p $L A Del ! ; Z C a /a� e.4... - ¢ppt c 2b i4.4c- Z tl J Subsequent Form Required: /C --/107 O 1 f • � APPROVED BY Approved By: C " � 4 � A vAV7 COMMISSIONER THE COMMISSION Date � c' - / Z — ! C_.. Form 10-403 Revised 01/ 010 R Submit In Duplicate r � 3 r,, ' S OCT 15 101 /a •�z•�z, • • • To: Alaska Oil & Gas Conservation Commission From: David E. Johnston by CTD Engineer Date: October 4, 2012 Re: D -19B Sundry Approval Sundry approval is requested to plug the D -19B perforations as part of drilling the . D -19C coiled tubing sidetrack. History: D -19B is a horizontal rotary ST completed in Sept 2001 with 350' of perfs in Zn 2A. The well produced fulltime up to 2004 when it started cycling for high GOR for -2 years. As field MGORs rose, its production became more competitive so its ontime increased. In April 2006, 25' of perfs were shot close to the tar in the heel of the well. This provided minimal production benefit. The well continued to cycle until April 2008 when a WRP was set at 9,580' to shut off gas, and 65' of heel adperfs were shot. This decreased both gas and oil rates and restored the well to full time service. To increase oil production, 20' of shallower heel perfs were shot in Jan 2010. Production rates increased but it started cycling after -6 mos. On 6/4/11, the WRP was pulled. The well did show some oil recharge but the gas tested at the rates pre -GSO in 2007. Reason for sidetrack: D -19B is not a competitive producer due to a high GOR, and 7 there are no remaining wellwork options. The proposed sidetrack will access reserves in a . -32 acre Zn 2A/2BI tar.et in central D -pad. Proposed plan for D -19C is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around November 15 2012. The existing perforations will temporarily be isolated by KB Packer whipstock, and permanently abandoned with the D -19C liner cement job. The sidetrack, D -19C, will exit the existing 4.5" liner, kick off in Z4 and land in Zone 2. This sidetrack will be completed with a 3 -1/4" x 2 -7/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. c oral. 6vh , ( & f , O n la rat/pc/44 ,4,s vac /( / c1, G D A 10 - zo MScr rl 4rihv ire Cl ( f� ov� i'�►�`v rc /rco�P . #00e0,D�%L �� °'�k,�3� w , ‘ • • . Pre -Rig Work: (scheduled to begin October 15, 2012) 1. S Set Dummy GLV's (Done 7/17/2012) 2. F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi (passed 7/17/2012) 3. W Cycle LDS; PPPOT- T to 5,000 psi (passed 7/16 ?2012) 4. S Dummy WS Drift to deviation or 9,000' MD (28° Inc) 5. E Mill XN nipple at 8,529' to 3.80" 6. E Set 4 -1/2" KB Packer Whipstock at 8,802' MD 7. V Set TWC and PT MV, SV, WV 8. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 9. 0 Remove wellhouse, level pad (),,Q Rig Work: (scheduled to begin November 15 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window at 8,802' and 10' of rathole. 3. Drill Build: 4.125" OH, 853' (25 deg /100 planned) • 4. Drill Lateral: 4.125" OH, 1,210' (12 deg /100 planned) with resistivity' v 5. Run 3 -1/4" x 2 -7/8" liner leaving TOL at 8,740' MD. �,,,,,,) 6. Pump primary cement leaving TOC at 8,740' MD, 22 bbls of 15.8 ppg liner cmt planned �D 7. Cleanout liner and run MCNUGR /CCL log. • ff 8. Test liner lap to 2,400 psi. 9. Stage perforate liner toe per asset instructions ( -200') 10. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set 4 -W liner top packer, and test to 3,000 psi (If liner lap test fails) 3. Generic GLV's David E. Johnston CTD Engineer 564 -5985 CC: Well File Joe Lastufka TREE= 6" CM/ WELLHEAD = MCEVOY • SAf NOTES: WEL-ANGLE> 70° @ 9325' *** ACTUATOR = BAKER C D-1 9 B 4-1/2" CHROME TBG & LNR*** KB. ELEV = 76.4' BF. ELEV = 42.95" KOP = 4250' Max Angie = 95° Q9566' Datum TV D = 8800 S I I I 2128' H4-1/2" HES X NIP, ID = 3.813" I 113 -3/8" CSG, 72#, L -80 BTRS, ID = 12.347" H 2702' GAS LET MANDRELS Minimum ID = 3.725" @ 8515' ST MD 1VD DEV' TYPE VLV LTCH PORT DATE 4 -1/2" HES XN NIPPLE C 6 2988 2988 1 MMGM DMY RK 0 09/20/01 5 3729 3729 0 MMGM DMY RK 0 07/17/12 4 5270 5199 24 KBG2 DMY BK 0 07/17/12 9 -5/8 " X T BKR ZXP PKR 6079' 3 6600 6441 5 KBG2 DMY BK 0 09/20/01 w / 6' TIEBACK, ID = 6.151 " 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 ■ 1 8373 8198 9 KBG2 _ DMY BK _ 0 09/20/01 9-5/8" X 7" BKR FLEX -LOCK H 6092' LNR HGR, ID = 6.151" 9 -5/8" MILLOUT WINDOW (D -19B) 6231' - 6247' I PERFORATION SUMMARY 8440' H4-1/2 " HES X NP, O = 3.813" I REF LOG: SPERRY -SUN AIFND RESISTVTY ON 09/16/01 ANGLE AT TOP PERF: 60° @ 9270' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I $461' 1-7" X 4-1/2" BKR S -3 PKR, 2 -7/8" 6 9270 - 9290 0 01/17/10 ®; ID= 3.875 "' 2 -718" 6 9290 -9320 0 04/18/08 2-7/8" 6 9325 - 9360 0 04/20/06 � 2 -7/8" 6 9325 - 9355 0 04/18/08 �1�1� 8494' H 41/2" HES X NP, ID = 3.813" 2 -7/8" 6 9380 - 9410 0 04/18/08 - j� - Y 2 -1/2" 4 9750 - 10100 0 09/18/01 ►�� X ►. ' 8515' H4-1/2" HES XN NIP, ID = 3.725" I � 1H11111 ►11111 r • • 0••�►11 8627' ,,41/2" WLEG, ID= 3.958" I 4••••••1 t 11111111 •1 I 8528' 7" X 4-1/2" BKR ZXP LW ■ • 1 1 1 / 1 1 1 w / 6' TIEBACK, ID = 4.408" ► 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8758' • � �11111111 1 • I 8541' I-- 7" X 4 -1/2" BKR HMC LNR j1 j a j 1 1 1 1 1 j 1 1 1 4 HGR ID = 4.410 17" LNR, 26#, L -80 IJ4S, .0383 bpf, O = 6.276' H 9618' 400A 4S, 8548' I- 14112" XO SUB, ID = 3.940" 141/2" 18G 12.68, 13CR -B0, .0152 bpf, O = 3.958" H 8526' I7" LNR, 268, L -80, .0383 bpf, ID = 6.276" H 8694' 1 I te a Z' I PBTD 10140' ,ow r. 14-1/2" LNR, 12.68, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" H 10227' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/12182 ORIGINAL COMPLETION 07/29/11 JJU PJC PULL WRP(07 /14/11) WELL: D-19B 06/11196 PAB SIDETRACK COM PLETION 09/20/11 JMO/ PJC TREE CIO (09116/11) PERMT No: 201 -1120 09120/01 CHIKAK RIG SIDETRACK 11/09/11 CDJ/ PJC GLV C1O (10/30111) AR No: 50- 029 - 20707 -02 04/26/08 D3M/SV SET WRP/AD ERF (04/18/08) 1 07/19/12 , CJNIJMD GLV C/O (07/17/12) SEC 23, T11 N, R13E, 3400' FSL & 1692' FEL 05/06/08 PJC PERF CORRECTIONS 02/02/10 KJB/PJC PERFS (01/17/10) BP Exploration (Alaska) TRH't= 6" CMV • S NOTES: WELL ANGLE > 70° @ 9325' * ** V1�LFEAD= MCEVOY D-1 9 C 4 -1/2" CHROMETBG& LNR * ** ACTUATOR = BAKER C KB. ELEV = 76.4' Proposed CTD Sidetrack BE ELEV = 42.95' KOP = 4250' Max Angle = 95° @ 9566' Datum MD = 9076' WD= 8800' SS I ' 2128' - -I4 -1/2" HES X NP, D = 3.813" 13 -3/8" CSG, 72#, L -80 BTRS, ID = 12.347" —1 2702' Minimum ID = 3.725" GAS E VLV LT CH 8515' ST MD TVD DEV TYPE VLV ETCH PORT DATE 4-1/2" HES XN NIPPLE E s 2988 2988 1 !MGM DMY RK 0 09/20/01 5 3729 3729 0 !MGM DMY RK 0 07/17/12 4 5270 5199 24 KBG2 DMY BK 0 07/17/12 9-5/8" X 7" BKR ZXP PKR — 6079' 3 6600 6441 5 KBG2 DMY BK 0 09/20 /01 w / 6' TACK ID = 6.151 " 2 7635 7470 7 KBG2 DMY BK 0 09/20/01 ■ 1 8373 8198 9 KBG2 DMY BK 0 09/20 /01 9-5/8" X 7" BKR FLEX -LOCK —I 6092' LNR HGR, D= 6.151" 9 - 5/8" MLLOUT WINDOW (D -198) 6231' - 6247' R3RFORAT1ON SUMMARY 8440' —14-1/2" HES X NP, D = 3.813" I RIT LOG: SPERRY -SUN MAD RESISTNTY ON 09/16/01 ANGLE AT TOP F EF : 60° @ 9270' Note: Refer to Production DB for historical pert data 8494' — 1 -- 4 - 1/2" HES X NIP, ID = 3.813" SIZE SR= INTERVAL Opn /Sqz DATE 2 -7/8" 6 9270 - 9290 0 01/17/10 0 / 8515' . 4 -1/2" HES XN NP, 0 = 3.725' 2 -7/8" 6 9290 - 9320 0 04/18/08 , Mill to 3.80° 2 -7/8" 6 9325 - 9350 0 04/20/06 �4�4� 2 -7/8" 6 9325 - 9355 0 04/18/08 . I 8527' 1-14-1/2" WLEG, ID = 3.958" 2 - 7/8" 6 9380 - 9410 0 04/18/08 *�4�* I 8528' _ 7" X 4 BKR ZXP LTP 2 -1/2" 4 9750 - 10100 0 09/18/01 ►:i 1 ►: w / 6' TDSACK, D = 4.408" MA' I 8541' 1 X 4 -1/2' BKR HMC LNR 1'1'11'1'11'17 . X 4 4 4 1 4 4 4 4 1 ■ HGR, D = 4.410" 14414444444441 ►1 I 44444444 1/4444441 / 4 I Top of 3-1/2" Liner & cement 8740' I . 4 4 4 4 4 4 4 4 4 4 4 4 4 1 1 » . r ; 19 - 5/8" CSG, 47 #, L -80, D= 8.681" H 8758' •■•••••• '4 13 x 2-7/8" crossover - 9700' 4 7" LNR, 26#, L -80 IJ4S, .0383 bpf, ID = 6.276" H 9618' .4.4.4.4.4.4.1 I I4 -1/2" TBG 12.6 #, 13CR -80, .0152 bpf, ID = 3.958' H 8526' I I 17" LNR, 26#, L -80, .0383 bpf, ID = 6.276" I--I 8694' 1 2-7/8" L -80 liner with TD @ 10,865' Top of 4 -1/2" KB PKR Whipstock @ 8,802' I DATE REV BY COMMENTS DATE REV BY COMMENTS P RUDHOE BAY UNIT 05/12/82 ORIGINAL COMPLETION 07/29/11 JJL/ PJC FULL WRP (07/14/11) WELL: D-19B 06/11/96 PAB SIDETRACK COMPLETION 09/20/11 JM10! PJC TREE GO(09 /16/11) PERMIT No: 201 -1120 09/20/01 CWKAK RIG SIDETRACK 11 /09/11 CDJ/ PJC GLV GO (10/30/11) ARM: 50- 029 - 20707 -02 04/26/08 DBMSV SET WRP/ADPEF F (04/18/08) 07/19/12 CJN/JMD GLV GO (07/17/12) SEC 23, T11 N, R13E 3400' FSL & 1692' FEL 05/06/08 PJC PERE CORRECTIONS 07/24/2012 JCL CTD Sidetrack 02/02/10 KJB/PJC PE ES (01/17/10) BP Exploration (Alaska) • NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM , V12 —� f•— la V14 Ilk 7 0 - 1/16" 5000 psi BOP's ID = 7.06" V15 V11 I7tns••5000 psi, RX-4s Transducers 0 1 1 1 1 1 OR e 1 GASSE V2 I V1 V 16 —4a t45— • Note typical HOP 1 r gement for 2-318" .,.:` soiled tubing : t0 ii ., i V17 HCR I C •' IK OK as To Poor Boy Gas Buster ,',.. iltge V16 V19 ' ar!'e 2111e ^s000 psi .RXaa I 3.00" 5000 Per HCR II s ■ l `* INN 2-1/15 psi CHECK VALVE I Manual Choke ww ts1�1•- �� , Tr: , 71 /78 aNea 500 ps Gate �. wlw><5000pai Irr Mr i1 li il, MEOH /Diesel , , , . , 4-- FP Line • Wig - - CoFlex Hose .-. f 114 Turn Halos . . 1OWOG To Production Tree or Cross Over • r.. e transducers uces ) T - CoFlex Hose CV11 0 ■ 1 cvu To Coiled Tubing Bleed Off Inner Reel Valve = j , - r CV13 Cement Line In 1 j Oround Level Tie-in CV30 -1 CV3 _ CV2 .� Stand Pip T Stae • �_ _ _ = p Manual Choke _ a/ - _�_ -_ ••• Y - w - .. I•P - —C 0 Pressure Transducers .. - CVt I I WV 11111Min I 111111 -- IMII Tiger Tank Mud Pump 2 arii _ In From ■ Baker MP 1 d MP 2 F ' Choke •_ -_- - _ - - -• CV14 to Pits I- Rig Floor i Mud Pump 01 " CV16 Reverse Ci - ■ ' .• , Cur CT while OOH Ea JIM 11111 O _ To Manifold CV15 1- Jun -2010 Revere. rjr.- .Hatl.n Ilan / rT while. note CoFlex Hose OPERABLE: Producer D -19B (PTD #201112,ubing Integrity Restored • Page 1 9f�2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] Sent: Saturday, October 29, 2011 4:49 PM ii( /// To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael J Subject: OPERABLE: Producer D -19B (PTD #2011120) Tubing Integrity Restored All, Producer D -19B (PTD #2011120) passed an MIT -IA to 3000 psi on 10/29/2011 after installing dummy gas lift valves in the well. The passing test confirms two competentbarriers in the wellbore. The well is reclassified as Operable. Please be aware of potential for annular fluid expansion when bringing the well online. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator 4t , Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: Reynolds, Charles (Alaska) Sent: Sunday, October 09, 2011 7:21 AM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Brooks, Phoebe L (DO' ; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; A., BPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK • S GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Phillips, Patti J Subject: UNDER EVALUATION: Producer D -19B (PTD #2011120) Sustained IA Casing P ssure Above MOASP All, Producer D -19B (PTD #2011120) has confirmed sustaine• A casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2350/2 '0/10 on 10/6/2011. A TIFL failed on 10/8/2011. The well has been reclassified as Under Evaluation. e well may remain online while work is conducted to attempt to restore integrity. 1. DHD: TIFL when well is warm 2. Slickline: Change out OGLV's (If TIF fails) 3. DHD: TIFL (if OGLV changed ut) A TIO plot and wellbore sche . tic have been included for reference. Thanks, 11/2/2011 UNDER EVALUATION: Producer D -19B (PTT2011120) Sustained IA Casing Press,Abov... Page 1 of 1 Regg, James B (DOA) From: Reynolds, Charles (Alaska) [Charles. Reynolds @bp.com] Sent: Sunday, October 09, 2011 7:21 AM 1 7. ' (D ' tb ci To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Phillips, Patti J Subject: UNDER EVALUATION: Producer D -19B (PTD #2011120) Sustained IA Casing Pressure Above MOASP Attachments: D- 19B.pdf; Producer D -19B TIO 10- 9- 11.doc All, Producer D -19B (PTD #2011120) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2350/2330/10 on 10/6/2011. A TIFL failed on 10/8/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. 1. DHD: TIFL when well is warm 2. Slickline: Change out OGLV's (If TIFL fails) J ' cP = 33,1,`>, A -cep 3. DHD: TIFL (if OGLV changed out) r1'ee A TIO plot and wellbore schematic have been included for reference. «D- 19B.pdf» «Producer D -19B TIO 10- 9- 11.doc» Thanks, Charles Reynolds =$t 'j Filling in for... Mclireen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 10/10/2011 PBU D -19B PTD #2011120 10/9/2011 TIO Pressures Plot Wet. D-19 4,000 3.000 • —�— Tbp IA 2,000 —A— OA OOA — 000A — On 1,000 Mir 07/09/11 07/16/11 07/23/11 07/30/11 08/06/11 00/13/11 00/20/11 08/27/11 09/03/11 09/10/11 09/17/11 09/24/11 10/01/11 10/06/11 • TREE = 6" CM/ SAFETY NOTES: W AS 4 - 1 /2" CHROME TBG & WELLHEAD = MCEVOY_ 4Ib ACTUATOR = BAKER 'e ®1 C LNR. WELL ANGLE > 0 @ 9325' KB. ELEV = 76.4' VV BF. ELEV = 42.95' KOP = 4250' Max Angle = 95 @ 9566' D MD = 9076' Datum TV D = 8800' SS 1 1 I 2128' 1-14-1/2" HES X NIP, ID = 3.813" I 113 -3/8" CSG, 72 4, L -80 BTRS, ID = 12.347" I--{ 2702' HA GAS LIFT MANDRELS Minimum ID = 3.72 @ 8 NNNN MD TVD DEV TYPE VLV LTCH PORT DATE 4 -1/2" HES XN NIPPLE 6 2988 2909 0 MMGM DMY RK 0 09/20/01 J 5 3729 3650 0 MMGM DOME RK 16 04/23/06 4 5270 5122 26 KBG2 SO BK 20 04/23/06 9 -5/8" X 7" BKR ZXP PKR 6079' 3 6600 6365 8 KBG2 DMY BK 0 09/20/01 2 7635 7394 8 KBG2 DMY BK 0 09/20/01 w / 6' TIEBACK, ID = 6.151" 1 8373 8122 8 KBG2 DMY BK 0 09/20/01 9 -5/8" X 7" BKR FLEX - LOCK -I 6092' LNR HGR, ID = 6.151" 9 -5/8" MILLOUT WINDOW (D -1913) 6231' - 6247' 1 8440' H4 -1/2" HES X NIP, ID = 3.813" I PERFORATION SUMMARY REF LOG: SPERRY -SUN MWD RESISTIVTY ON 09/16/01 ANGLE AT TOP PERF: 60° @ 9270' Note: Refer to Production DB for historical perf data srl SIZE SPF INTERVAL Opn /Sqz DATE 8461' 1- X 4 -1/2" BKR S -3 PKR, 2 -7/8" 6 9270 - 9290 0 01/17/10 Mil 2 ID = 3.875" 2 -7/8" 6 9290 - 9320 0 04/18/08 � 1 " I t 2 -7/8" 6 9325 - 9350 0 04/20/06 11111 ' ' ---- I 8494' H 4 -112" HES X NIP, ID = 3.813" I 2 -7/8" 6 9325 - 9355 O 04/18/08 *11* 2 -7/8" 6 9380 - 9410 0 04/18/08 i, ,.1�.4 is eer--1 8515' I- 14-1/2" HES XN NIP, ID = 3.725" I 2 -1/2" 4 9750 - 10100 0 09/18/01 ■ At 8515' 4 -112" PXN PLUG (09/08/11) I 1 '� 8527' I- 14-1/2" WLEG, ID = 3958" d I 852$' Id " X 4 -1/2" BKR ZXP LTP w! 6' TIEBACK, ID = 4.408" 1N11 9-5/8" CSG, 47 #, L -80, ID = 8.681" 8758' ■ H 11 1 1 1 11 1 1 1 1 11 1 1 1 I 8541' '-{ 7" X 4 -1/2" BKR HMC LNR AI N(' = 6457cDp ■ 1 I HGR, ID = 4.410" I 7" LNR, 26 #, L -80 U4S, .0383 bpf, ID = 6.276" H I 9618' I .... t , ++ I 8548' H 4-1/2" XO SUB, ID = 3.940" I 4 -1/2" TBG 12.6 #, 13CR -80, .0152 bpf, ID = 3.958" H 8526' I 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H I 8694' I I I I PBTD J-I 10140' I I4 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" H 10227 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/12/82 ORIGINAL COMPLETION 07/29/11 JJL/ PJC PULL WRP (07/14/11) WELL: D-19B 06/11/96 PAB SIDETRACK COMPLETION 09/20/11 TA/ PJC SET PXN (9/8/11) PERMIT No: 201 -1120 09/20/01 CH/KAK RIG SIDETRACK 09/20/11 JMO/ PJC TREE C/O (09/16/11) API No: 50- 029 - 20707 -02 04/26/08 DBM/SV SET WRP /ADPERF (04/18/08) SEC 23, T11 N, R13E, 3400' FSL & 1692' FEL 05/06/08 PJC PERF CORRECTIONS 02/02/10 KJB /PJC PERFS (01/17/10) BP Exploration (Alaska) STATE OF ALASKA ALASKAPAND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei PULL PLUG Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension El Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development III Exploratory ❑ - 201 -1120 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20707 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028285 a PBU D -19B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10230 feet Plugs (measured) None feet true vertical 9032.62 feet Junk (measured) None feet Effective Depth measured 10139 feet Packer (measured) 6079 8461 8528 feet true vertical 9033.09 feet (true vertical) 5942 8285 8352 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 30 - 110 30 - 110 Surface 2673' 13 -3/8" 72# L -80 29 - 2702 29 - 2702 5380 2670 Production 6219' 9 -5/8" 47# L -80 28 - 6247 28 - 6098 6870 4760 Liner 2615' 7" 26# L -80 6079 - 8694 5942 - 8516 7240 5410 Liner 1699' 4 -1/2" 12.6# 13CR80 8528 - 10227 8352 - 9033 8440 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ - - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 27 - 8527 27 - 8350 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 6079 5942 4 -1/2" Baker S -3 Perm Packer 8461 8285 4 -1/2" Baker ZXP Packer 8528 8352 ¢ 12. Stimulation or cement squeeze summary: ' .x { ' Intervals treated (measured): ' ; , i ,; ' a i v t�C I v? ZU1' Treatment descriptions including volumes used and final pressure: „ , „ ' , • ' r . '' t r ; .1,,im isswn 13. Representative Daily Average Production or Injection Data ` ' "V Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 403 22,844 0 1,334 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - oe Lastuf a i Title Petrotechnical Data Technologist Signat 111111 1 Phone 564-4091 Date 8/12/2011 NIP RQDAIIS AUG 12 201i / l< Form 10 -404 Revised 10/2010 Submit Original Only D -19B 201 -112 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D -19B 9/18/01 PER 9,750. 10,100. 9,036.91 9,033.46 D -19B 4/20/06 APF 9,325. 9,350. 9,032.21 9,039.77 D -19B 4/17/08 BPS 9,580. 10,100. 9,043.7 9,033.46 D -19B 4/18/08 APF 9,290. 9,320. 9,018.53 9,030.47 D -19B 4/18/08 APF 9,325. 9,355. 9,032.21 9,041.05 D -19B 4/18/08 APF 9,380. 9,410. 9,046.17 9,049.74 D -19B 1/17/10 APF 9,270. 9,290. 9,009.16 9,018.53 D -19B 7/14/11 BPP 9,580. 10,100. 9,043.7 9,033.46 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . . D -19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY *, "Wit:ZtNZ4,P3t7:::4iil)PTT4E1T:t:IW:L:itlni:r:Siagtaniift7?Z 7/14/2011' CTU #9 1.75" SCOPE OF WORK: PULL WRP Kill well with 10 bbl 60/40 spear followed by 211 bbls of slick 1%KCI w/ Safe Lube. `RIH w/ 4.5" WRP retrieval tool. Latch WRP at 9581'CTM after 5 attempts. WRP fish free at 5K overpull. POOH w/ 2.5K overpull working WRP fish through tight spots. ( Recovered 4.5" WRP. Left center element of WRP in hole. Freeze protect well with '40 BBLS of 50/50 meth. 13.65" OD x 1.25" wide x .25 thick center element from WRP left in hole. ISSV REQUIRES MAINTENANCE - WILL NOT CLOSE WHEN DUMPED Job Complete FLUIDS PUMPED BBLS 110 60/40 METH 235 1% KCL W/ SAFE LUBE 345 TOTAL TREE 6" CNV WELLHEAD = MCEVOY • SAFETY :WELL HAS 4-1/2" CHROME TBG & ACTUATOR = OTIS D -1 9 B LNR WEL GLE> 70° @ 9325' KB. ELEV = 76.4' BF. ELEV = 42.95' - - KOP = 4250' Max Angle = 95 @ 9566' Datum MD = 9076' Datum ND = 8800' SS 1 ' I 2128' H 4 -1/2" HES X NIP, ID = 3.813" I 1 13 -3/8" CSG, 72 #, L -80 BTRS, ID = 12.347" I — I 2702' I — A GAS LIFT MANDRELS Minimum ID = 3.725" @ 8515' ST MD TVD DEV TYPE VLV LTCH PORT DATE 4 -1/2" HES XN NIPPLE 6 2988 2909 0 MMGM DMY RK 0 09/20/01 ' 5 3729 3650 0 MMGM DOME RK 16 04/23/06 L 4 5270 5122 26 KBG2 SO BK 20 04/23/06 9-5/8" X 7" BKR ZXP PKR 6079' 3 6600 6365 8 KBG2 DMY BK 0 09/20/01 t R 2 7635 7394 8 KBG2 DMY BK 0 09/20/01 w/ 6' TIEBACK, ID = 6.151" 7 1 8373 8122 8 KBG2 DMY BK 0 09/20/01 9 -5/8" X 7" BKR FLEX -LOCK —I 6092' LNR HGR, ID = 6.151" 9 -5/8" MILLOUT WINDOW (D -19B) 6231' - 6247' I PERFORATION SUMMARY , a g 8440' H4 -1/2" HES X NIP, ID = 3.813" I REF LOG: SPERRY -SUN MWD RESISTIVTY ON 09/16/01 `" ., ANGLE AT TOP PERF: 60° @ 9270'. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 14' F2 8461' I�7" X 4 -112" BKR S-3 PKR, 2 -7/8" 6 9270 - 9290 0 01/17/10 ID = 3.875" t'•'• 2 -7/8" 6 9290 9320 0 04/18/08 • 8494' I — I4 - 1/2" HES X NIP, ID = 3.813" I 2 -7/8" 6 9325 - 9350 0 04/20/06 �� 1 2 -7/8" 6 9325 - 9355 0 04/18/08 '•1••• : 2 -7/8" 6 9380 - 9410 0 04/18/00 �i A � 8515' H4-1/2" HES XN NIP, ID = 3.725" 2 -1/2" 4 9750 - 10100 0 09/18/01 P vt't t't't ft'/ 1 1 1 .1 1 1 1 t'. 1 1 1 1 �I�NIt�11 ' i l ill 1 8527' 1 WLEG, ID = 3.958" 111 �1 4 I 8528' I_ r X 4-1/2" BKR ZXP LTP ■ w / 6' TIEBACK, ID = 4.408" 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I--I 8758' I ,■1./.1+1�I�y1 • I 8541' I 7" X 4 -112" BKR HMC LNR 11111111 HGR, ID= 4.410" 7" LNR, 26 #, L-80 IJ4S, .0383 bpf, ID = 6.276" H 9618 ∎111 I 1 I 8548' H4 -1/2" XO SUB, ID = 3.940" I I4 -1/2" TBG 12.6 #, 13CR -80, .0152 bpf, ID = 3.958" H 8526' 1 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I--I 8694' 1 1 fLJ(J w,.f 1 I PBTD I 10140' 14-1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" I — I 10227 :4 41 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/12/82 ORIGINAL COMPLETION 04/26/08 DBM/SV SET WRP / ADPERF (04/18/08) WELL: D-19B 06/11/96 PAB SIDETRACK COMPLETION 05/06/08 PJC PERF CORRECTIONS PERMIT No: 201 -1120 09/20/01 CH/KAK RIG SIDETRACK 02/02/10 KJB /PJC PERFS (01/17/10) API No: 50- 029 - 20707 -02 07/09/03 CMO /TLP KB ELEVATION CORRECTION 07/29/11 JJL/ PJC PULL WRP (07/14/11) SEC 23, T11 N, R13E, 3400' FSL & 1692' FEL 04/20/06 DMS /PJC ADPERF 04/23/06 RCT /PJC GLV C/0 BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011M R `LL � 't Mr. Tom Maunder , �� 1 Alaska Oil and Gas Conservation Commission � 333 West 7 m Avenue Anchorage, Alaska 99501 ! ke Oil job }/� [ /� (�y��+ [/_� Sd �,+l�a iY KaY6a di3O.)pry� Subject: Corrosion Inhibitor Treatments of GPB D Pad chor Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal 0-01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1 /7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 0-11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 0-24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D-31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 r STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS ~~c~iv~® JAN 2 ~ 210 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ e Pertormed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ AflCh~rnQ! Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-e er Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory 201-1120 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20707-02-00 8. Property Designation (Lease Number) : 9. Well Name and Numbdc: ADLO-028285 ! PBU D-196 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10230 feet Plugs (measured) 9582' 4/18/08 feet true vertical 9032.62 feet Junk (measured) None feet Effective Depth measured 10139 feet Packer (measured) 6079 8461 8528 true vertical 9033 feet (true vertical) 5942 8285 8352 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30 - 110 30 - 110 Surface 2673 13-3/8" 72# L-80 29 - 2702 2- - 2702 5380 2670 Intermediate Production 6219 9-5/8" 47# L-80 28 - 6247 28 - 6098 6870 4760 Liner 2615 7"26# L-80 6079 - 8694 5942 - 8516 7240 5410 Liner 1699 4-1/2" 12.6# 13CD80 8528 - 10227 8352 - 9033 8440 7500 Perforation depth: Measured depth: SEE ATTACHED - ~ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR-80 SURFACE - 8526' SURFACE-8350 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X7" BKR ZXP PKR 6079 .5942 7" 4-1/2" BKR S-3 PKR 8461 8285 7"X4-1/2" BKR ZXP LPT 8528 8352 12. Stimulation or cement squeeze summary: Intervals treated (measured): .~=v~lN .1A`~~ ~ 6 211 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: 317 14007 0 - 1239 Subsequent to operation: 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 1/21/2010 Form 10-404 wised 7/2009 R6DMS JAN 2 2 2010 ~ ~S!ubmit Original Only D-19B 201-112 PERF oTTACHMFNT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D-19B 9/18/01 PER 9,750. 10,100. 9,036.91 9,033.46 D-19B 4/20/06 APF 9,325. 9,350. 9,032.21 9,039.77 D-19B 4/17/08 BPS 9,580. 10,100. 9,043.7 9,033.46 D-19B 4/18108 APF 9,290. 9,320. 9,018.53 9,030.47 D-19B 4/18/08 APF 9,325. 9,355. 9,032.21 9,041.05 D-19B 4/18/08 APF 9,380. 9,410. 9,046.17 9,049.74 D-19B 1/17/10 APF 9,270. 9,290. 9,009.16 9,018.53 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i • L~ D-19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/16/2010 "k*WELL FLOWING ON ARRIVAL""*(E-LINE PERFO) FLOWING INITIAL T/I/O = 1400/300/0 PSI--SHUT IN T/I/O = 2500/500/0 PSI SSV, MASTER, SSSV, WING =OPEN, SWAB =CLOSED IA/OA OTG RIG UP ELINE TO PERFORATE 9270'-9290' ***JOB IN PROGRESS CONTINUED ON 1-17-2010 WSR*"" 1/16/2010 T/I/0=2250/500/0. Temp=S1. TBG (E-line). TBG FL @ 7770' (120 bbls). E-line in control of well. 1/16/2010 T/I/0=2400/500/0 Temp=S1 Assist EL as directed. Pumped down TBG 2 bbls neat meth spear and 48 bbls crude to start loading TBG for EL. *"Job in progress, cont. on WSR 01-17-10"" 1/17/2010 ***JOB CONTINUED FROM16-JAN-10**"(E-LINE PERFO) AFTER PUMPING T/I/O = 140/500/0 PSI PERFORATED 9270'-9290' WITH 2-7/8" POWERJET OMEGA HSD GUNS FINAL T/I/O = 0/300/0 PSI ***WELL LEFT SHUT IN, SSV, MASTER, SSSV =OPEN, SWAB, WING =CLOSED IA/OA OTG, DSO NOTIFIED, JOB COMPLETE** FLUIDS PUMPED BBLS 13 METH 34 DIESEL 47 Total TREE = 6" CMr WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = __ 76.4' _ __ BF. ELEV = _~. , _m 42.95' KOP = 4250' Max Angle = 95 @ 9566' Datum MD = 9076' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 1--~ 27 Minimum ID = 3.725" @ 8515' 4-112" HES XN NIPPLE X 7" BKR ZXP PKR w / 6' TIEBACK, ID = 6.151" 9-5/8" X 7" BKR FLEX-LOCK LNR HGR, ID = 6.151" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 6 2988 2909 0 MMGM DMY RK 0 09/20/01 5 3729 3650 0 MMGM DOME RK 16 04/23/06 4 5270 5122 26 KBG2 SO BK 20 04/23/06 3 6600 6365 8 KBG2 DMY BK 0 09/20!01 2 7635 7394 8 KBG2 DMY BK 0 09!20/01 1 8373 8122 8 KBG2 DMY BK 0 09/20/01 9-5l8" MILLOUT WINDOW (D-19Bj 6231' - 6247' PERFORATION SUMMARY REF LOG : SPERRY-SUN MWD RESISTIVTY O N 09/16101 ANGLE AT TOP PERF: 64° @ 9290' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9290 - 9320 O 04/18108 2-718" 6 9325 - 9350 O 04120106 2-718" 6 9325 - 9355 O 04!18/08 2-718" 6 9380 - 9410 O 04118!08 2-112" 4 9750 - 10100 G 09/18/01 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 8758' 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" 9618' 4-1/2" TBG 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" (4-112" HES X NIP, ID = 3.813" ~ 3461' I-j7" X 4-1i2" BKR S-3 PKR, LID = 3.875" $494' 4-1/2" HES X NIP, ID = 3.813" 8515' ~--X4-1/2" HES XN NIP, ID = 3.725" 8527' 4-1/2" WLEG, ID = 3.958" ' BKR ZXP LTP 8528 z" x a- i)2'~ ~ ---~~~ w / 6' TIEBACK, ID = 4_408" $541' 7" X 4-1/2" BKR HMC LNR HGR, ID = 4.410" $548' 4-112" XO SUB, ID = 3.940" 95$0' (-~4-112" WRP(04/18108) PBTD 4-1/2" LNR, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/12/82 ORIGINAL COMPLETION 04/26/08 DBM/SV SET WRP/ADPERF (04118!08) 06/11/96 PAB SIDETRACKCOMPt_ETION 05/06/08 PJC PERFCORRECTIONS 09/20/01 CH/KAK RIG SIDETRACK 07/09!03 CMO/TLP KB ELEVATION CORRECTION 04(20/06 DMS/PJC ADPERF 04/23/06 RCT/PJC GLV C/O PRUDHOE BAY UNff WELL D-19B PERMfT No: 201-1120 API No: 50-029-20707-02 SEC 23, Ti 1 N, R13E, 3400' FSL & 1692' FEL BP Exploration (Alaska) S TES: WELL HAS 4-ii2" CHROMETBG& ~ ~ ~ ~ LNR. L ANGLE > 70° @ 9325' 2128' I-~ 4-1 /2" HES X NIP, ID = 3.813" ,. STATE OF ALASKA ~ ~~C ALA~OIL AND GAS CONSERVATION COM~ION ~'V qP REPORT OF SUNDRY WELL OPERATIONS~~aska ~ 2 ~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other , Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension [~~ ns Che cO r Jrj Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~~' 201-1120 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20707-02-00 7. KB Eievation (ft): 9. Well Name and Number: 76.42 KB ~ PBU D-19B 8. Property Designation: 10. Field/Pool(s): ADLO-028285 PRUDHOE BAY Field/ PRUDHOE OIL Pool ~ 11. Present Well Condition Summary: Total Depth measured 10230 ~ feet Plugs (measured) W ~, Q C (;~~®~~ true vertical 9032.62 - feet ~~g~D~lU~.i~ ~~R ~ ~lu~~asured) None ~4~IL- ' ' ~"+.rj~ ~ Effective Depth measured 10139 feet true vertical 9033 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 30 - 110 30 - 110 SURFACE 2673 13-3/8" 72# L-80 29 - 2702 29 - 2702 5380 2670 PRODUCTION 6219 9-5/8" 47# L-80 28 - 6247 28 - 6098 6870 4760 LINER 2615 7" 26# L-80 6079 - 8694 5942 - 8516 7240 5410 LINER 1699 4-1/2" 12.6# 13CR80 8528 - 10227 8352 - 9033 8440 7500 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ _ _ True Vertical depth: _ _ - _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13 CR80 SURFACE - 8526' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X7" BKR ZXP PKR 6085' 7"X4-1/2" BKR S-3 PKR 8461' 7"X4-1/2" BKR ZXP PKR 8528' 0 0 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: 496 28873 1769 Subsequent to operation: SHUT-IN 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 work: Oil Gas WAG ~' GINJ WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 4/23/2008 f,: Form 10-404 Revi§ed 04/~pD~ ^ ~~ //~~ ~~ ~af~~? ~.,, ~~~ ~ ~ ~.1~ Submit Original Only ~lJ~~'L1 D-196 201-1120 PERF ATTACHMENT • I~e,~~c~cc~~~~~~ ~~~ ~, r~ ~ Wellbore: D-19B MDT MDB TVDT TVDB 9/18/2001 4/20/2006 4/17/2008 4/18/2008 9,290 9,320 9019 9030 APF 9,325 9,350 9032 9040 APF APF ,~ 9,350 9,355 9040 9041 APF ,~ 9,380 9,410 9046 9050 APF 9,750 10,100 9037 9033 PER BPS AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULL ED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOV ED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL _ FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMO VED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • D-19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/16/2008 CTU #9 Drift log & set WRP & perforate. Broadcasting=Yes. Thaw injector sump. Perform partial kill w/ 147 bbl 1 % KCL w/ safelube. RIH w/ 3.7" drift for `WRP. Continued on 04/17/08 WSR. 4/17/2008 Continued from 04/16/08 WSR. Broadcast=Yes. Continue to RIH w/ 3.7" drift for WRP. Drift clear to 9725'. POOH. MU/RIH w/ SWS GC/CCL in carrier for mem tie-in. Log 9700'-9000' w/ flag C 9525'. Set WRP C~ 9580` . MU/RIH w/Gun #1: 30' of 2 7/8" 6 spf. Lightly tag WRP. Re-set depth to top shot, off WRP. Pull up 'to set flag. Continued on 04/18/08 WSR. 4/18/2008 Continued from 04/17/08 WSR. Broadcasting=yes. Flag CT @ 9250' /top shot. Shoot interval 9380'-9410'. MU/RIH with Gun #2: 30' of 2 7/8" 6 spf. Tie in to flag @ 9250'./ Top shot. Shoot intervals 9325`-9355` MU/RIH with Gun #3. Tie in to flag @ 9250'/top shot. Shoot interval 9290'-9320'. POOH. FP backside to 2400' w/ water/meth. Found bad spot in coil @ 2114' Thickness below min. Begin rig up for reel blow down. Continued on 04/19/08 WSR. 4/19/2008~Continued from 04/1~~. _~--- ~ _.._. ~__... - _~_~.. _.. _... .. ~. _ . 8/08 WSR. Blow down reel w/ N2. Rig down. Job complete*** FLUIDS PUMPED BBLS 154 METH/WTR 5 NEAT METH 159 Total ..' A. STATE OF ALASKA .- Al~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS o o [] RECEIVED JUN 2 () 2006 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development [;'1 Stratigraphic D Stimulate 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: omrmss on 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 201-1120 D 6. API Number: 50-029-20707-02-00 9. Well Name and Number: Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 76.42 KB D-19B 8. Property Designation: ADl-028285 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Total Depth measured 10230 feet Plugs (measured) None true vertical 9032.62 feet Junk (measured) None Effective Depth measured 10139 feet true vertical 9033.09 feet Casing length Size MD TVD Burst Collapse Conductor 80 20" Conductor 30 - 110 30 - 110 Surface 2673 13-3/8" 72# l-80 29 - 2702 29 - 2701.91 5380 2670 Production 6219 9-5/8" 47# l-80 28 - 6247 28 - 6098.45 6870 4760 Liner 2615 7" 26# l-80 6079 - 8694 5942.39 - 8515.69 7240 5410 Liner 1699 4-1/2" 12.6# 13CR80 8528 - 10227 8351.58 - 9032.63 8440 7500 Perforation depth: Measured depth: 9325 - 9350 True Vertical depth: 9032.21 - 9039.77 9750 - 10100 9036.91 - 9033.46 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 27 - 8527 Packers and SSSV (type and measured depth) 7" Baker ZXP Packer 4-1/2" Baker S-3 Packer 4-1/2" Baker ZXP Packer 6085 8461 8528 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft JUN 2 1 2006 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN 27569 0 0 1247 15. Well Class after proposed work: Exploratory Development [;'1 Service 16. Well Status after proposed work: Oil [;'1 Gas D WAG WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations 1121 x Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Signa~~~~ ?L~ Form 10-404 Revised 04/2004 0 RIG I r~ p\ L Title Data Mgmt Engr Phone 564-4424 Date 6/14/2006 Submit Original Only . . D-19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 50 Meth 311 2% KCL 30 Diesel 391 TOTAL I ACTIVITYDA TE I SWlv1MARY0: 4/19/2006 MIRU CTU #5. MU BHA w. CTC, Stinger, 3" JS Nozzle. Drift tubing. Knock WHP down to RIH. Drifted to bottom tagged TD two times at 10,140' CTM, RIH w. MCNL Log. Job in progress. ***Continue on 4-20-06 WSR*** 4/20/2006 ***Job continued from 4-19-06 WSR.*** Continue to RIH to flag. Log per procedure. 2 up passes from flag to 8560' at 60 fpm. POOH. RIH w. 25' TCP to flag, correct to top shoot. PUH to firing depth. Add Perfs 9325'-9350' 6spf, random orientation, 60 deg Phasing. POOH and load well w. diesel. OOH all shots fired on gun. *** Job Complete*** e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc Permit to Drill 20t1120 MD 10230 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 101312003 Well Name/No. PRUDHOE BAY UNIT D-19B Operator BP EXPLORATION (ALASKA) INC 9033 _ Completion Date 9/20/2001 -'~ Completion Status 1-OIL Current Status 1-OIL APl No. 50-029-20707-02-00 UIC N _ REQUIRED INFORMATION Mud Log N_9 Samples N._~o Directional Survey N__~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Typ~.~MedlFrmt Number Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Directional Survey 1 6204 10176 Open 9/13/2002 FINAL Open 10/11/2001 Directional Survey Paper Copy FINAL Open 10/11/2001 Directional Survey Paper Copy 1 6204 10176 Open 9/13/2002 FINAL Open 10/11/2001 Directional Survey Digital Data 1 6206 10230 Case 2/11/2003 Digital Well Logging Data FINAL Open 10/11/2001 Directional Survey digital Data Well Cores/Samples Information: Name Start Interval Stop Sent Sample Set Received Number Comments ADDITIONAL INFORMATION Cored? Y ~) Well Chips Received? ~ Analysis ~ Received? Daily History Received? {~ N Formation Tops ~ N Comments: Permit to Drill 2011120 DATA SUBMITTAL COMPLIANCE REPORT 101312003 Well Name/No. PRUDHOE BAY UNIT D-19B Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20707-02-00 MD 10230 'I-VD 9033 Compliance Reviewed By: Completion Date 9/20/2001 Completion Status 1-OIL Current Status 1-OIL Date: UIC N To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs · D-19B, February 10, 2003 AK-MM-II149 D-19B: Digital Log Images 50-029-20207-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED FEB 1 1 2.003 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs D-19B, September 11, 2002 AK-MM-II149 1 LDWG formatted Disc with verification listing. API#: 50-029-20~07-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING, AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical '.Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-112 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20707-02 4. Location of well at surface ' . ~ 9. Unit or Lease Name 1880' SNL, 1692' WEL, SEC. 23, T11N, R13E, UM ]1 ¥ffii[l~l~ I Prudhoe Bay Unit At top of productive interval '. ~. ZD..cs. i 1580' SNL, 2564' WEL, SEC. 23, T11 N, R13E, UM ·~t~~ ~t , 10. Well Number At total depth .... :,.~ ~~ D-19B 1147' SNL, 3414' WEL, SEC. 23, T11N, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 76.42' ADL 028285 12. Date Spudded9,9,2001 [ 13' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'9,16,2001 9,20,2001 115' Water; depth' if °ffsh°re./A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 10230 9033 ETI 10182 9033 EtI []Yes [] NoI (Nipple) 2132' MD] 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DEN, NEU 23. CASINGr LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD ... AMOUNT PULLED 20" X 30" Insulated Conductor Surface 110' 36" 3 cu yds Concrete 13-3/8" 72# L-80 Surface 2702' 17-1/2" 3549 cu ft Permafrost II 9-5/8" 47# L-80 Surface 6231' 12-1/4" 1177 cu ft Class 'G'~ 130 cu ft PF 'C' 7" 26# L-80 6079' 8694' 8-1/2" ~30 cu ft Class 'G' 4-1/2" 12.6# 13Cr80 8528' 10227' 6-1/8" _~70 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8531' 8465' MD TVD MD TVD 9750' - 10100' 9037' - 9033' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 160 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 1, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO 10/4/2001 2 TEST PERIOD 3099 4035 144 55.03I 1302 ~Iow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HouR RATE 25.9 · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch,PSREcE V D NOV 057 001 Alaska 0,, & Gas Cons. C0mmiss,o~ _.. Anchorage, Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers !30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 8687' 8509' Shublik A 8714' 8535' Shublik B 8748' 8569' Shublik C 8764' 8585' Sadlerochit / Zone 4B 8782' 8603' Zone 4A 8871' 8689' Zone 3 8978' 8790' Zone 2C 9055' 8859' Zone 2B 9126' 8916' Zone 2A 9267' .0o., RECEIVED HOT 9350' 9040' NOV 0 5 200! Alaska Oil & Gas Cons. Commissior., Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary, Post-Rig Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~"~~ ~ Title TechnicalAssistant Date D- 19B 201-112 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ' ' ". '.'...'. ".' : ........ :" "" :'.'i':Leak fl: 10 t Su ~ ~ · .":."~....:i':' ...::.....':........ 'O :' ~ . mmary Legal Name: D-19 Common Name: D-19B Test Date.. TeSt'¥~Pe ' .' 'Test.' Depth.:(TMg) .... =.. .:... Test. Dep.th. (3'VD) . .... AMW Leak Off Pressure (BHP) EMW 9/8/2001 FIT 6,270.0 (ft) 6,108.0 (ft) 9.60 (ppg) 770 (psi) 3,816 (psi) 12.03 (ppg) Printed: 9/24/2001 5:02:48 PM BP EXPLORATION Page 1 of 6 Operations Summa Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYEN Rig Release: 9/20/2001 Rig Name: DOYEN 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/2/2001 00:00 - 00:00 24.00 MOB P PRE Rig down floor. Skid floor. Move rig off of S-110i. Install booster wheels. RD windwalls. PJSM. Prepare derrick bridle. LD derrick. Moved camp, utility module, and shop to D-Pad and complete rig up of same. Pull inside cuttings conveyor. Complete installation of Super G Derrick shakers. Clean location. PJSM Move rig off S-Pad. 9/3/2001 00:00 - 15:30 15.50 MOB PRE Move rig from S-Pad to D-Pad. 15:30 - 22:00 6.50 RIGU PRE Spot rig near Do19. Raise A legs. Raise derrick and windwalls. Set windwall "C" Section. Unhook bridle lines and tie back. Hang braces for rails. Hang lights. 22:00 - 23:00 1.00 RIGU PRE Lay down old drilling line spool. Set new spool in place. 23:00 - 00:00 1.00 RIGU PRE Pick up top drive & rig up. Set new cuttings conveyor in place. Rigging up floor. 9/4/2001 00:00 - 10:00 10.00 RIGU P PRE RU top drive and rig floor. Install conveyor. Install BOP in sub-base. Spot rig over well. Skid floor. 10:00 - 16:00 6.00 RIGU P PRE Accept rig at 10:00. Continue to RU floor. Take on sea water. Check well pressure. RU lines to tree and annulus and test to 3,500 psi. 16:00- 17:00 1.00 RIGU P PRE RU DSM lubricator and pull BPV. 17:00 - 20:00 3.00 RIGU P PRE RU circulating lines. Displace diesel freeze protection by pumping 64 bbls of sea water down IA and obtain clean returns. Switch and pump 188 bbls of sea water down tubing and obtain clean returns. Flow check. Well static. 20:00 - 20:30 0.50 RIGU P PRE Set TWC and test to 1000 psi. 20:30 - 21:30 1.00 RIGU P PRE ND tree. LD tree. Make dummy run with XO for tubing hanger. 21:30 - 22:30 1.00 RIGU P PRE Work on well head. Grind off tip of one lock down screw. 22:30 - 00:00 1.50 RIGU P PRE NU BOPE. 9/5/2001 00:00 - 04:00 4.00 RIGU P PRE Continue to NU BOPE. Install secondary annulus valve. 04:00 - 04:30 0.50 RIGU P PRE Body test BOP to 2000 psi. Can't test higher due to leaking tubing hanger seals. 04:30 - 05:30 1.00 RIGU P PRE RU DSM and pull TWC with lubricator. 05:30 - 07:00 1.50 RIGU P PRE RU and pull tubing to rig floor. P/U 155K. S/O 145K. 07:00 - 07:30 0.50 RIGU P PRE Circulate one hole volume at 10 bpm at 210 psi. 07:30 - 08:30 1.00 RIGU P PRE Crimp control lines and cut. LD tubing hanger. MU test plug and land tubing and test plug. 08:30 - 09:00 0.50 RIGU P PRE RU to test BOP. 09:00 - 14:30 5.50 RIGU P PRE Test BOPE to 250 psi Iow, 3,500 psi high as per AOGCC regs and BP policy. Test annular to 2,500 psi. BOP test witness waived by John Crisp of AOGCC. 14:30 - 15:30 1.00 RIGU P PRE RD test equipment and P/U Halliburton spooling unit. MU 5" DP to pull plug and tubing. 15:30 - 16:30 1.00 PULL P DECOMP Pull tubing to floor. LD landing equipment. 16:30 - 17:30 1.00 PULL P DECOMP RU to LD tubing. 17:30 - 18:00 0.50 PULL P DECOMP Fluid out of balance. Pump dry job. 18:00 - 22:00 4.00 PULL P DECOMP Pull 5 1/2" tubing and spool encapsulated control lines. Connections tight and threads hanging up. Retrieved 25 control line protectors and 5 SS bands. 22:00 - 22:30 0.50 PULL P DECOMP RD control line equipment. 22:30 - 00:00 1.50 PULL P DECOMP POOH LD 5 1/2" tubing. 9/6/2001 00:00 - 03:30 3.50 PULL P DECOMP Continue to LID 5 1/2" tubing. Recovered 150 joints and 25.80' cut joint, 3 GLMs, SSSV landing nipple, 25 control line protectors, 5 SS bands, and control line. Good jet cut. 03:30 - 04:30 1.00 PULL P DECOMP Clear rig floor of tubing handling equipment. Printed: 9/24/2001 4:59:15 PM BP EXPLORATION Page 2 of Operations Summa Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYON Rig Release: 9/20/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/6/2001 04:30 - 05:30 1.00 BOPSUR P DECOMP Change top pipe rams to 2 7/8" x 5" variable rams. 05:30 - 06:00 0.50 BOPSUR P DECOMP Service rig. 06:00 - 06:30 0.50 BOPSUR P DECOMP RU and test top pipe rams to 250 psi / 3,500 psi. 06:30 - 07:00 0.50 WHSUR P DECOMP Install wear ring. 07:00 - 10:00 3.00 CLEAN P DECOMP P/U milling tools and MU milling assembly with mule shoe and water melon mill. 10:00 - 17:00 7.00 CLEAN P DECOMP RIH P/U drill pipe from shed. 17:00 - 17:30 0.50 CLEAN P DECOMP Tag top of tubing stub at 6,305'. Prepare pits for mud displacement. 17:30 - 18:30 1.00 CLEAN P DECOMP Displace sea water in hole with 9.6 ppg LSND drilling fluid at 12 bpm and 1250 psi. Obtain base line torqe: 4,000 fi*lb at 50 RPM. 18:30 - 22:00 3.50 CLEAN P DECOMP Slip drilling line, 1,780'. Change to new spool of line. 22:00 - 22:30 0.50 CLEAN P DECOMP Service top drive. 22:30 - 00:00 1.50 CLEAN P DECOMP POH standing back drill pipe to 2,400'. 9/7/2001 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to POH to 2,420'. 01:00 - 03:00 2.00 CLEAN N RREP DECOMP Drilling line back lashed. Slip and cut damaged line. 03:00- 03:30 0.50 CLEAN P DECOMP POH to BHA. 03:30 - 04:30 1.00 CLEAN P DECOMP Stand back drill collars and L/D milling assembly. 04:30 - 05:00 0.50 CLEAN P DECOMP PJSM. RU eline. 05:00 - 07:30 2.50 CLEAN P DECOMP RIH and set bridge plug at 6,257' wireline depth. POH and RD eline. 07:30 - 08:00 0.50 CLEAN P DECOMP Pull wear ring. 08:00 - 09:30 1.50 WHSUR P DECOMP RU to pull 9 5~8" pack off. Bleed pressure off of OA. 09:30 - 14:00 4.50 WHSUR P DECOMP Attempt to pull pack off. Unable to unseat pack off using heat and fluid movement through seal area. Also used heat on outside of spool. Pull max weight on J lug pulling tool. 14:00 - 16:30 2.50 WHSUR P DECOMP ND BOP and tubing spool. 16:30 - 17:00 0.50 WHSUR P DECOMP Install 9 5~8" pack off. 17:00 - 19:30 2.50 WHSUR P DECOMP NU BOP and condition B tubing spool. 19:30 - 20:00 0.50 WHSUR P DECOMP Install wear ring and test pack off to 5000 psi for 15 minutes. 20:00 - 21:00 1.00 CASE P DECOMP Pressure test 9 5~8" casing and BOP flanges to 300 psi for 5 minutes and 3500 psi for 30 minutes. 21:00 - 23:00 2.00 STWHIP P WEXlT MU whipstock assembly and orient MWD. 23:00 - 00:00 1.00 STWHIP P WEXlT Upload MWD. 9/8/2001 00:00 - 01:30 1.50 STWHIP P WEXlT RIH w/BHA. Surface test MWD. 01:30 - 04:00 2.50 STWHIP P WEXlT RIH to 6,200' 04:00 - 04:30 0.50 STWHIP P WEXlT Orient whipstock to 86? right of high side and set BP at 6,254'. 04:30 - 14:30 10.00 STWHIP P WEXlT Mill window from 6,231' to 6,247' and drill formation to 6,270'. 14:30 - 15:00 0.50 STVVHIP P WEXlT Perform FIT test to 12.0 ppg EMW. 15:00 - 19:30 4.50 STWHIP P WEXlT Flow check. Well static. POOH and log for geology tie in from 6,004' to 5,624'. Continue POOH. 19:30 - 21:30 2.00 STWHIP P WEXlT LD BHA. Down load MWD. Upper string mill in gage. 21:30 - 22:30 1.00 STWHIP P WEXlT Flush stack and clear rig floor of milling tools. 22:30 - 00:00 1.50 DRILL P INT1 MU 8 1/2" drilling BHA. 9/9/2001 00:00 ~ 01:30 1.50 DRILL P INT1 Continue to MU BHA. Surface test MWD. 01:30 - 04:30 3.00 DRILL P INT1 TIH picking up 72 singles. RIH to 6,135'. Orient through window. 04:30 - 05:00 0.50 DRILL P INT1 Wash from 6,255' to 6,270'. 05:00 - 00:00 19.00 DRILL P INT1 Drill from 6,270' to 7,096'. Flow rate 550 gpm. AST=9.79. ART=4.3. 9/10/2001 00:00 - 00:00 24.00 DRILL P INT1 Drill from 7,096' to 8,570'. ART=10.21. AST--6.68. Hole in good shape. Printed: 9/24/2001 4:59:'15 PM BP EXPLORATION Page 3 of 6 Operations Summa Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYON Rig Release: 9/20/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/11/2001 00:00 - 03:00 3.00 DRILL P INT1 Drill from 8,570' to 7" casing point at 8,694'. AST=I. ART=I 03:00 - 05:00 2.00 DRILL P INT1 Pump sweep and circulate hole clean at 500 gpm and 3200 psi. 05:00 - 07:00 2.00 DRILL P INT1 Monitor well. Well static. POOH to window. Hole in good condition. No excess drag. 07:00 - 08:30 1.50 DRILL P INT1 RIH and precautionary wash the last 60' to bottom. No fill on bottom. 08:30 - 10:00 1.50 DRILL P INT1 Pump sweep and circulate hole clean. 10:00 - 11:00 1.00 DRILL P INT1 Spot 100 bbl liner running pill. 11:00 - 16:00 5.00 DRILL P INT1 Monitor well. Well static. POOH. Drop 2" rabbit with wire line tail. SLM (no correction made). 16:00 - 16:30 0.50 DRILL P INT1 LD HWDP. 16:30 - 19:00 2.50 DRILL P INT1 LD BHA. Down load MWD. 19:00 - 19:30 0.50 DRILL P INT1 Clear rig floor. 19:30 - 20:00 0.50 CASE P LNR1 RU to run 7" liner. 20:00 - 00:00 4.00 CASE P LNR1 PU float joints. Baker lock first 3 connections. Fill pipe and drain. RIH and check floats. Run 7" liner to 1,968'. 9/12/2001 00:00 - 02:00 2.00 CASE P LNR1 Finish running 64 joints of 7" liner. 02:00 - 03:00 1.00 CASE P LNR1 MU Baker liner hanger and liner top packer. Circulate liner volume of 100 bbls at 6 bpm and 270 psi. 03:00 - 06:00 3.00 CASE P LNR1 TIH with liner on 4" DP. 06:00 - 06:30 0.50 CASE P LNR1 MU cement head and on single and place on pipe skate. 06:30 - 07:30 1.00 CASE P LNR1 CBU above window at 6,200' at 6 bpm and 520 psi. 07:30 - 10:30 3.00 CASE P LNR1 Run liner into open hole on DP. PU cement head. Stage pump rate up to 3 bpm. Wash last 17' to bottom. No losses while running casing. Hole in good shape. Ran into small ledge ? 20' off bottom. 10:30 - 11:30 1.00 CASE P LNR1 Bring circulaiton rate up to 6 bpm with pipe on bottom at 8,694'. PJSM for cement job. 11:30 - 12:30 1.00 CASE P LNR1 Test lines and cement liner with 39 bbls of 15.8 ppg cement. Displace cement with rig pumps at 6 bpm. Full returns during cement job. Bump plug. Floats held. 12:30 - 13:00 0.50 CASE P LNR1 Pressure up to 3500 psi to set liner hanger. Release from liner and pick up with 1000 psi. Rotate and set liner top packer. 13:00- 13:30 0.50 CASE P LNR1 CBU. 13:30 - 14:30 1.00 CASE P LNR1 Stand back 5 stands. LD cement head. 14:30 - 15:30 1.00 CASE P LNR1 Slip and cut drilling line. 15:30 - 18:00 2.50 CASE P LNR1 POOH and stand back DP. 18:00 - 18:30 0.50 CASE P LNR1 Lay down liner running tool. 18:30 - 19:00 0.50 CASE P LNR1 Pull wear bushing. 19:00 - 20:00 1.00 CASE P LNR1 Rig up to test BOPE. 20:00 - 23:00 3.00 CASE P LNR1 Test BOPE as per BP policy and AOGCC regulations. Witness of test waived by Jeff Jones of ^OGCC. 23:00 - 23:30 0.50 DRILL P PROD1 Install wear bushing. 23:30 - 00:00 0.50 DRILL P PROD1 Prepare to MU BHA. 9/13/2001 00:00 - 03:00 3.00 DRILL P PROD1 MU 6 1/8" directional BHA. Orient 1.57 adjustable bent housing motor with 5.85" OD offset pad. PJSM. Load radio active sources in MWD. 03:00 - 03:30 0.50 DRILL P PROD1 Surface test mud motor and MWD. 03:30 - 05:30 2.00 DRILL P PROD1 Pick up 63 joints of 4" DP and RIH. 05:30 - 09:00 3.50 DRILL P PROD1 TIH with stands and tag cement at 8,601' (9' above landing collar). 09:00 - 10:00 1.00 DRILL P PROD1 RU and test liner and casing to 3,500 psi for 30 minutes. Printed: 9/2412001 4:59:'15 PM BP EXPLORATION Page 4 of 6 Operations Summa Report i Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYON Rig Release: 9/20/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/13/2001 ,10:00 - 12:00 2.00 DRILL P PROD1 Drill cement and float equipment from 8,601' to 8,694'. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 20' of new formation to 8,714' with 9.8 ppg LSND mud. Monitor well. Well Static. FIT requirement of 9.8 ppg achieved. Drill ahead and displace LSND mud with 8.4 ppg QuickDril on the fly. Continue drilling to 9,000' while building angle. AST=7.1. ART=2.4. 9/14/2001 00:00 - 06:30 6.50 DRILL P PROD1 Drill from 9,000' to 9,223'. Not achieving necessary BUR with bit and motor. 06:30 - 08:00 1.50 DRILL P PROD1 Circulate bottoms up and monitor well. Well static. 08:00 - 12:30 4.50 DRILL P PROD1 POOH. Monitor well at 7" shoe. 12:30 - 14:30 2.00 DRILL P PROD1 Stand back BHA. Down load MWD in derrick while adjusting bend on mud motor to 1.837. 14:30 - 15:30 1.00 DRILL P PROD1 Upload to MWD. Load radio active sources. 15:30 - 19:30 4.00 DRILL P PROD1 TIH to 9,223'. Hole in good shape. Drill ahead building angle to 9,373'. 19:30 - 00:00 4.50 DRILL P PROD1 Drill ahead from 9,223 to 9,373. No adverse hole conditions on connections. Control cuttings beds with sweeps. 9/15/2001 00:00 - 12:00 12.00 DRILL P PROD1 Drill from 9,373' to 9,932'. Unable to drill. Erratic torque. Less weight required to get differential pressure. ART=5.06. AST=3. 12:00 - 12:30 0.50 DRILL P PROD1 Circulate hole clean. 12:30 - 16:30 4.00 DRILL P PROD1 Monitor well. Well static. POOH. 16:30 - 18:00 1.50 DRILL P PROD1 Remove RA sources. LD mud motor and bit. 18:00 - 19:30 1.50 DRILL P PROD1 PU 1.157 adjustable bent housing motor. MU BHA. 19:30 - 22:30 3.00 DRILL P PROD1 TIH to 8,385'. 22:30 - 23:30 1.00 DRILL P PROD1 Slip and cut drilling line. 23:30 - 00:00 0.50 DRILL P PROD1 TIH to 9,135'. 9/16/2001 00:00 - 00:30 0.50 DRILL P PROD1 RIH from 8,900' to 9,250'. Started taking weight. 00:30 - 02:00 1.50 DRILL P PROD1 Ream from 9,250' to 9,932'. WOB ranged from 0 to 5K. 02:00 - 08:00 6.00 DRILL P PROD1 Drill from 9,932' to 10,230'. AST=0.75. ART=3.31. 08:00 - 09:00 1.00 DRILL P PROD1 Circulate at 59 spm, 1,710 psi. Flow check. Well static. 09:00 - 10:30 1.50 DRILL P PROD1 Short trip to 7" liner shoe at 8,694'. Hole in good shape. 10:30 - 12:30 2.00 DRILL P PROD1 Pump sweep at 6 bpm and circulate hole clean. Spot liner running pill. 12:30 - 17:00 4.50 DRILL P PROD1 Flow check. Well static. POOH. SLM. No correction made. 17:00 - 19:00 2.00 DRILL P PROD1 LD BHA. Remove radio active sources. Down load MWD. 19:00 - 19:30 0.50 DRILL P PROD1 Clear rig floor. 19:30 - 21:00 1.50 CASE P PROD1 RU to run 4 1/2", 13Cr, 12.6#, Vain Ace production liner. 21:00 - 00:00 3.00 CASE P PROD1 Make up float equipment. Fill pipe and check floats. Floats OK. Run liner to 600'. 9/17/2001 00:00 - 02:00 2.00 CASE P COMP Run 4 1/2", 12.6#, 13Cr, Vam Ace liner from 600' to 1,675'. 02:00 - 03:00 1.00 CASE P COMP RD liner running tools. Change bails and elevators. 03:00 - 04:00 1.00 CASE P COMP PU and MU Baker HMC liner hanger and ZXP liner top packer. 04:00 - 04:30 0.50 CASE P COMP Circulate liner volume at 4 bpm, 110 psi. Liner weight 7OK. 04:30 - 09:30 5.00 CASE P COMP RIH with liner on 4" DP to 8,675'. 09:30 - 11:00 1.50 CASE P COMP CBU. stage up rate to 6 bpm, 630 psi. MU cement head. 11:00- 12:30 1.50 CASE P COMP TIH to 10,213'. 12:30 - 13:00 0.50 CASE P COMP PU cement head and wash to 10,230'. 13:00 - 15:00 2.00 CASE P COMP Stage pumps up to 60 spm once on bottom. Circulate hole clean while reciprocating liner. PJSM. 15:00 - 16:00 1.00 CASE P COMP Test lines to 4,000 psi. Pump 21 bbl CW 100, 25 bbls 12 ppg mud push spacer, 48 bbls 15.8 ppg class G cement. Displace with 43 bbls perf pill followed by sea water. Bump plug on ,, Printed: 9/24/2001 4:59:'15 PM BP EXPLORATION Page 5 of Operations Summa Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYON Rig Release: 9/20/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/17/2001 15:00 - 16:00 1.00 CASE ~ COMP calculated strokes. CIP 15:55. 16:00 - 16:30 0.50 CASE ~ COMP Set liner hanger and release from liner. Hold 1,000 psi on DP and pick up to circulate. Circulate cement up hole. Slack off and set liner top packer. 16:30 - 18:00 1.50 CASE 3 COMP Displace well from top of the liner at 8,527' with sea water. Saw CW-100, spacer, and some contaminated cement at surface. 18:00 - 18:30 0.50 CASE P COMP POOH to 6,991'. 18:30 - i9:00 0.50 CASE P COMP LD cement head. 19:00 - 21:30 2.50 CASE P COMP POOH. 21:30 - 22:30 1.00 CASE P COMP RU to test 4 1/2" liner. RU to PU perf guns and 2 7/8" DP. ,22:30 - 23:00 0.50 CASE P COMP Pressure test 4 1/2" liner to 3500 psi for 30 minutes. 23:00 - 00:00 1.00 PERF P COMP PU 350' of Halliburton 2 1/2" perf guns and RIH. 9/18/2001 00:00 02:00 2.00 PERF P COMP PU 2 7/8" Drill pipe from pipe shed 02:00-03:00 1.00 PERF P COMP Change elevators, Pu Mu below packer, safety it, 03:00-06:30 3.50 PERF P COMP Change elevators, PU MU 4" Drill pipe to 6,235 ft 06:30-07:00 0.50 PERF P COMP Insure fas fill valve closed by closing Hydril, apply 300 psi on annulus 07:00-08:00 1.00 PERF P COMP PU MU 4" Drill pipe to 10,134 ft 08:00-09:00 1.00 PERF P COMP PJSM, Pull up to 10,101 ft, set packer, PT surface lines to 3,500 psi, fire guns, wi 2,600 psi on annulus 09:00-10:00 1.00 PERF ~P COMP Reverse out 2 drill pipe volumes at 210 psi at 3 bpm. No signs of gas at bottoms up. I 10:00 - 10:30 0.50 PERF ,~P COMP Unset packer, monitor wellbore. No losses or gains. Well static. 10:30-12:30 2.00 PERF P COMP Circulate BU down DP, 390 psi, 4.5 bpm, at 10,101 ft 12:30 - 13:30 1.00 PERF P COMP POOH. ( Rack back 50 stands in derrick in preparation for rig move) .Hole taking proper fill. 13:30-14:30 1.00 PERF P COMP Slip and cut at 7,172 fi 14:30 - 18:00 3.50 PERF P COMP Lay down excess 4" DP 18:00-19:00 1.00 PERF P COMP Lay down fas fill valve, jars, packer at 1,700 fi 19:00-21:00 2.00 PERF P COMP Lay down 27/8" DP 21:00 - 22:00 1.00 PERF P COMP PJSM, Lay down guns. Confirm 100% of guns did fire. 22:00 - 22:30 0.50 RUNCOr P COMP Pull wear bushing 22:30-00:00 1.50 RUNCOrP :COMP Rig up to run 4 1/2" completion tubing 9/19/2001 00:00-00:30 0.50 RUNCO~/P COMP Rig up to run 4 1/2" production string 00:30-12:30 12.00 RUNCO~ COMP Run 4 1/2" production string as per program. No rejected connections on tubing. One space out pup required changing out. Swap out with new pup. 12:30-15:00 2.50 RUNCO~ F' :COMP Space out 4 1/2" production string 15:00 - 16:00 1.00 RUNCO~ F' COMP Land tubing and RILDS/torque to man. specs. 16:00-18:00 2.00 RUNCOr~ :COMP Pump inhibitor down tubing, displace w/ sea water to annulus 18:00-19:00 1.00 RUNCO~ P COMP Drop ball w/ rod, set packer, test tubing at 3500 psi for 30 minutes 19:00-20:00 1.00 RUNCO~/P COMP Bleed tubing to 1500 psi, test annulus 3500 psi for 30 minutes 20:00-20:30 0.50 RUNCO~ I:) COMP Install TVVC, pressure test to 2500 psi from below 20:30-21:30 1.00 BOPSUF P COMP Change top pipe rams to 4 1/2" x 7" in preparation for pulling tubing on next well. 21:30-22:30 1.00 BOPSUF N RREP COMP Change out annular preventer Printed: 9/24/2001 4:59:15 PM BP EXPLORATION page 6 of 6 Operations Summa Report Legal Well Name: D-19 Common Well Name: D-19B Spud Date: 4/24/1982 Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/20/2001 Contractor Name: DOYON Rig Release: 9/20/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/19/2001 22:30- 00:00 1.50 BOPSUF 3 COMP Nipple down BOP stack 9/20/2001 00:00-01:00 1.00 BOPSUFP COMP ND BOP stack 01:00- 03:30 2.50 WHSUR 3 I COMP NU adapter flange and tree, test flange and tree to 5000 3si for 10 minutes 03:30- 04:30 1.00 WHSUR 3 COMP PU DSM lubricator and pull TWC 04:30- 05:00 0.50 WHSUR ~ COMP Spot and RU Hot Oil '05:00- 07:00 2.00 WHSUR 3 COMP PJSM test lines to 3000 psi, reverse circulate fdiesel at 2.5 bpm at 1100 psi, 160 bbls 07:00 - 08:30 1.50 WHSUR P COMP U - tube diesel into tubing, freeze protecting to 2,200 ft. 08:30-10:00 1.50 WHSUR P COMP RD circulating equipment in cellar, secure wellhead, Rig Release Printed: 9/24/2001 4:59:'15 PM 10-O ct-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well D-19B Dear Dear Sir/Madam' o~0 )- Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,197.72' MD 6,231.00' MD 10,230.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED OCT 2001 Alaska Oil & Gas Cons. Commissiop ~chorage . Alask~ Drillingi~& Wells PBU_WOA O Pad, Slot O. 19 D-19B Job No. A~fff49, Su~eyed: 18 September, 2001 DEFINITIVE SURVEY REPORT '10 October, 200f Your Ref: APl 500292020702 Surface Coordinates: 5959108.00 N, 653467.00 E (70° 17'42.8233" N, 148° 45' 26.2998" W) Kelly Bushing: 76.42ft above Mean Sea Level dRILLING SERVicES S.rvey Ref: svy10965 A Halliburton Company North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth Vertical Depth (ft) 6197.72 21.730 263.780 5976.22 6052.64 6231.00 21.530 263,830 6007.15 6083.57 6268.29 21.030 267.510 6041.90 6118.32 6299.62 18.500 270,590 6071.39 6147,81 6333.65 16.600 273.950 6103.83 6180.25 6364.32 14,530 276,970 6133,38 6209.80 6395.89 13.620 280.080 6164.00 6240.42 6427,55 12,580 283.200 6194,83 6271.25 6460.22 10.600 289.250 6226,84 6303.26 6493.26 8.790 298.250 6259,41 6335.83 6525,63 7.640 305.800 6291.44 6367.86 6557.75 6.040 320.980 6323.34 6399.76 6589,03 5.170 337,890 6354.47 6430.89 6620.36 5.700 349.780 6385.66 6462.08 6652.82 7.230 5.860 6417.91 6494.33 6684.25 8.800 15,420 6449.04 6525.46 6747.29 8,710 24.770 6511.35 6587.77 6844.10 8,210 31.760 6607.11 6683,53 6939.94 7,500 31,360 6702.05 6778,47 7036.66 6,980 30.970 6797.99 6874,41 7133.11 6.560 28.660 6893.77 6970.19 7226.39 5.920 27.780 6986.50 7062.92 7321,26 5.150 24.250 7080.93 7157.35 7419.55 4.190 19.720 7178,89 7255.31 7515.88 3.930 20.250 7274.98 7351.40 7611.93 6,380 28.930 7370.63 7447.05 7707.83 7.050 32.980 7465.87 7542.29 7804.68 9.680 35.720 7561.69 7638.11 7900.20 9.980 34.000 7655.80 7732.22 7995.88 9.410 33.590 7750.12 7826.54 Sperry-Sun Drilling Services Survey Report for D-19B Your Ref: AP1 500292020702 Job No. AK, ZZ11149, Surveyed: 18 September, 200~ Local Coordinates Global Coordinates Northings Easflngs Northings Eastings (ft) (ft) (ft) (ft) 113.47 S 753.38W 5958979.17 N 652716.09 E 114.79 S 765.58W 5958977.60 N 652703.93 E 115.82 S 779.07W 5958976.30 N 652690.46 E 116.01S 789.65W 5958975.89 N 652679.88 E 115.62 S 799.90W 5958976,07 N 652669.62 E 114.85 S 808.09W 5958976.67 N 652661.42 E 113,72 S 815.69W 5958977.65 N 652653.81 E 112.28 S 822.71W 5958978.94 N 652646.75 E 110.48 S 829.01W 5958980.62 N 652640,41 E 108.28 S 834,11W 5958982.71 N 652635.28 E 105.85 S 838.03W 5958985.06 N 652631.30 E 103.29 S 840.83W 5958987.56 N 652628,46 E 100.71S 842.39W 5958990.11N 652626.84 E 97.87 S 843.20W 5958992.94 N 652625.97 E 94.25 S 843.28W 5958996.55 N 652625.82 E 89.96 S 842.44W 5959000,85 N 652626.57 E 80.98 S 839.16W 5959009.90N 652629.67 E 68.45 S 832.45W 5959022,57 N 652636.13 E 57.29 S 825.59W 5959033.87 N 652642.75 E 46.86 S 819.28W 5959044.42 N 652648.85 E 37.00 S 813.62W 5959054.40 N 652654.30 E 28.07 S 808,82W 5959063.42 N 652658.92 E 19.86 S 804.79W 5959071.72 N 652662.78 E 12.45 S 801.77W 5959079.18 N 652665.65 E 6.04 S 799.44W 5959085,63 N 652667.85 E 1.72 N 795.72W 5959093.47 N 652671.41 E 11.32 N 789.94W 5959103.18 N 652676.99 E 22.91N 781,95W 5959114.94N 652684.75 E 36.30 N 772.63W 5959128.51N 652693.79 E 49.69 N 763.67W 5959142.08 N 652702.48 E DEFINITIVE Alaska Drilling & Wells PBU_WOA D Pad Dogleg Vertical Rate Section (°/'tOOft) 500.09 O.604 508.51 3.824 518.12 8.730 526.06 6.325 534.11 Comment Tie On Point AK-6 BP_IFR-AK Window Point 7.246 540.85 3,747 547.36 3.971 553.65 7.104 559.61 7.130 564.92 4.864 569.48 7.476 573.27 5.937 576.14 3.963 578.59 7.259 581.00 6.537 583,13 2.26O 586.46 1.180 589.47 0.743 591.49 0,540 593.44 0.519 595.53 0.694 597.66 0.887 599.92 1.046 602.42 0.273 604.80 2.670 606.99 0.855 608.81 2.746 610.25 0.439 611.83 0.600 613.68 10 October, 2001- 13:29 Page 2of5 DrillQuest 2. 00. 08, 005 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) {ft) 8093.22 8.190 32.780 7846.31 7922.73 8188.01 10.660 36.790 7939.81 8016.23 8284.60 10.650 37.400 8034.74 8111.16 8380.17 9.150 37.400 8128.88 8205.30 8476.86 7.510 38.630 8224.55 8300.97 8572.88 8.910 35.770 8319.58 8396.00 8635.83 8.870 35.470 8381.78 8458.20 8701.00 7.970 34.790 8446.24 8522.66 8732.83 9.100 17.050 8477.73 8554.15 8763.13 10.410 0.010 8507.59 8584.01 8795.43 12.430 342.830 8539.26 8615.68 8826.67 14.000 335.310 8569.68 8846.10 8858.46 14.030 332.530 8600.52 8676.94 8890.63 16.260 323.940 8631.57 8707.99 8926.40 19.070 318.330 8665.66 8742.08 8959.15 21.330 312.470 8696.39 8772.81 8990.35 24.250 311.170 8725.16 8801.58 9023.32 28.110 308.070 8754.74 8831.16 9054.94 31.760 305.910 8782.14 8858.56 9086.86 35.350 304.340 8808.73 8885.15 9120.80 39.180 303.110 8835.74 9152.43 43.180 301.430 8859.54 9183.33 47.170 300.550 8881.32 9215.84 51.380 299.950 8902.53 9247.47 56.860 299.540 8921.06 8912.16 8935.96 8957.74 8978.95 8997.48 Sperry-Sun Drilling .Services Survey Report forD-19B Your Ref: APl1500292020702 Job No. AKZZI f149, Surveyed~ '18 sePtember, 2001 9279.25 61.850 300.880 8937.25 9013.67 9310.71 67.590 300.410 8950.68 9027.10 9343.67 73.470 299.800 8961.66 9038.08 9374.76 79.610 298.860 8968.90 9045.32 9406.41 85.200 298.000 8973.08 9049.50 Local Coordinates Northings Eastings Northings (ft) (ft) (ft) Global Coordinates Eastings (ft) 62.14 N 755.51W 5959154.71 N 652710.38 E 74.84N 746.60W 5959167.58N 652719.02 E 89.09 N 735.83W 5959182.05 N 652729.50 E 102.14 N 725.85W 5959195.30 N 652739.21 E 113.19 N 717.24W 5959206.52 N 652747.60 E 124,12 N 708.97W 5959217.62 N 652755.64 E 132.03 N 703.31W 5959225.84N 652761.14 E 139.83 N 697.81W 5959233.55 N 652766.48 E 144.05 N 695.82W 5959237.81 N 652768.39 E 149.08 N 695.11W 5959242.86 N 652768.99 E 155.32 N 696.14W 5959249.08 N 652767.83 E 161.97 N 698.71W 5959255.67 N 652765.13 E 168.88 N 702,09W 5959262.51 N 652761.60 E 175.98 N 706.55W 5959269.52 N 652757.01 E 184.40 N 713.38W 5959277.80 N 652750.00 E 192.42 N 721,33W 5959285.65 N 652741.89 E 200.47 N 730.34W 5959293.52 N 652732.72 E 209.72 N 741.56W 5959302.54N 652721.31E 219.20 N 754.I7W 5959311.76 N 652708.51E 229.34 N 768;60W 5959321.60 N 652693.88 E 240.74 N 785.70W 5959332.65 N 652676,55 E 251.84N 803.31W 5959343.39 N 652658.72 E 263.12 N 822.09W 5959354.28 N 652639.71 E 275.53 N 843.37W 5959366.25 N 652618.18 E 288.23 N 865.62W 5959378.50 N 652595.68 E 301.99 N 889.23W 5959391.77 N 652571.79 E 316.49 N 913;70W 5959405.76 N 652547.03 E 332.06 N 940.57W 5959420.79 N 652519.84E 346.86 N ' 966.92W 5959435.05 N 652493.20 E 361.79 N 994.50W 5959449.41N 652465.32 E Dogleg Rate (°/lOOft) 1.260 2.695 0.117 1.570 1.706 1.518 0.097 1.389 8.955 10.413 12.181 7.443 2.120 9.817 9.176 9.255 9.497 12.417 12.034 11.570 11.496 13.120 13.069 13.025 17.357 16.115 18.295 17.925 19.967 17.866 Alaska Drilling & Wells PBU WOAD Pad Vertical Section Comment 615.55 617.00 618.03 618.90 619.50 620.29 621.10 621.98 623.19 625.92 630.75 637.01 644.07 652.06 662.72 673.98 686.06 700.59 716.34 733.90 754.31 774.92 796.53 820.78 845.95 872.85 900.88 931.44 961.09 991.77 10 October, 2001 - 13:29 Page 3 of 5 DrillQuest 2.00.08.005 Sperry. Sun Drilling Services Survey Report for D-19B Your Ref: AP1 500292020702 Job No. AKZZff149, Surveyed: 18 September, 2001 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9437.04 89.320 298.590 8974.54 9050.96 376.29 N 1021.43 W 5959463.36 N 652438.10 E 9469.55 91.660 299.230 8974.26 9050.68 392.01 N 1049.89 W 5959478.49 N 652409.33 E 9566.07 95.170 298.580 8968.51 9044.93 438.57 N 1134.22 W 5959523.32 N 652324.06 E 9661.56 91.600 297.480 8962.88 9039.30 483.36 N 1218.35 W 5959566.38 N 652239.04 E 9758.31 91.410 293.670 8960.33 9036.75 525.10 N 1305.57 W 5959606.33 N 652150.98 E 9853.89 92.150 293.790 8957.37 9033.79 563.55 N 1393.03W 5959642.99 N 652062.76 E 9949.80 88.770 296.770 8956.60 9033.02 604.49 N 1479.73W 5959682.15 N 651975.24 E 10046.75 90.250 296.520 8957.42 9033.84 647.97 N 1566.38W 5959723.85 N 651887.72 E 10137.04 90.620 296.240 8956.74 9033.16 688.08 N 1647.26W 5959762.31 N 651806.03 E 10164.04 90.250 296.480 8956.53 9032.95 700.07 N 1671.45W 5959773.80 N 651781.60 E 10230.00 90.250 296.480 8956.25 9032.67 729.48 N 1730.49W 5959802.00 N 651721.97 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.498° (10-Oct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vedical Section is from Well Reference and calculated along an Azimuth of 310.410° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10230,00ft., The Bottom Hole Displacement is 1877.96ft., in the Direction of 292,858° (True). Dogleg Rate (°/'lOOft) 13.588 7.462 3.698 3.911 3.942 0.784 4.698 1.548 0.514 1.633 0.000 Alaska Drilling & Wells PBU WOAD Pad Vertical Section Comment 1021.68 1053.53 1147.93 1241.02 1334.49 1426.01 1518.57 1612.72 1700.32 1726.51 1790.53 Projected Survey 10 October, 2001 - 13:29 Page 4 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for D.19B Your Ref: AP1 500292020702 Job No. AKZZl l'I49, Surveyed: '18 September, 2001 North Slope Alaska Alaska Drilling & Wells PBU WOAD Pad Comments Measured Depth {ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6197.72 6052.64 113.47 S 753.38W 6231.00 6083.57 114.79 S 765,58W 10230.00 9032.67 729.48 N 1730.49W Comment Tie On Point Window Point Projected Survey Survey tool program for D-f9B From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 6197.72 6052.64 6197.72 6052.64 10230.00 9032.67 Survey Tool DesCription AK-1 BP_HG - BP High Accuracy Gyro (D-19) AK-6 BP_IFR-AK (D-19B) 10 October, 2001 - 13:29 Page 5of$ DrillQ~mst 2.00.08.005 10-O ct-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well D-19B MWD c~o(-l~z Dear Dear Sir/Madam' Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,197.72' MD 6,231.00' MD 10,230.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, Carl D. Ulrich Survey Manager Attachment(s) RECEIVED OCT 1i 200t Alaska Oil & Gas Cons,, Commission ~orage Alaska Drilling & Wells PBU_WOA D Pad, Slot D. 19 D-19B MWD Job No. AKMMflf49, Surveyed: ~8 October, 200~ S UR VEY REPORT 10 October, 2001 Your Ref: AP1500292020702 Surface Coordinates: 5959108.00 N, 653467.00 E (70° 17'42.8233" N, 148° 45' 26.2998" W) Kelly Bushing: 76.42ft above Mean Sea Level DRILLING SI~RV, ICEs A Halliburlon Company Survey Ref: $vy10966 Sperry-Sun Drilling Services Survey Report for D.19B MWD Your Reft API 500292020702 Job No. AKMMIff49, Surveyed: 18-October, 2001 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6197.72 21.730 263.780 5976.22 6052.64 6231.00 21,530 263.830 6007.15 6083.57 6268.29 21.030 267.510 6041.90 6118.32 6299.62 18,500 270.590 6071.39 6147.81 6333.65 16.600 273.950 6103.83 6180.25 6364.32 14.530 276.970 6133.38 6209.80 6395,89 13.620 280.080 6164.00 6240.42 6427.55 12.580 283.200 6194.83 6271.25 6460.22 10.600 289.360 6226.84 6303.26 6493.26 8.790 298.500 6259.41 6335.83 6525.63 7.640 305.930 6291.44 6367.86 6557.75 6.040 321,130 6323.34 6399.76 6589.03 5.170 338.020 6354.47 6430.89 6620.36 5.700 350.050 6385.66 6462.08 6652.82 7.230 6,000 6417.91 6494.33 6684.25 8.800 15.570 6449.04 6525.46 6747.29 8.710 24.920 6511.35 6587.77 6844.10 8.210 31.910 6607.11 6683.53 6939.94 7.500 31.510 6702.05 6778.47 7036.66 6.980 31.070 6797.99 6874.41 7133.11 6.560 28.740 6893.77 6970.19 7226.39 5.920 27.850 6986.50 7062.92 7321.26 5.150 24.420 7080.93 7157.35 7419.55 4.190 19.780 7178.89 7255.31 7515.88 3.930 20.310 7274.98 7351.40 7611.93 6.380 28,880 7370.63 7447.05 7707.83 7.050 32.870 7465,87 7542.29 7804.68 9.680 35.760 7561.69 7638.11 7900.20 9.980 34.150 7655.80 7732.22 7995.88 9.410 33,900 7750.12 7826,54 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 113.47 S 753.38W 5958979.17 N 652716.09 E 114.79 S 765.58W 5958977.60 N 652703.93 E 115.82 S 779.07W 5958976.30 N 652690.46 E 116.01S 789.65W 5958975.89 N 652679.88 E 115.62 S 799.90W 5958976.07 N 652669.62 E 114.85 S 808.09W 5958976.67 N 652661.42 E 113.72 S 815.69W 5958977.65 N 652653.81 E 112.28 S 822.7tW 5958978.94 N 652646.75 E 110.48 S 829.01W 5958980.62 N 652640.42 E 108.26 S 834.10W 5958982.73 N 652635.29 E 105.82 S 838.01W 5958985.09 N 652631.32 E 103.25 S 840.80W 5958987.60 N 652628.48 E 100.66 S 842.36W 5958990,16 N 652626.87 E 97.82 S 843.16W. 5958992.98 N 652626,01 E 94.20 S 843.23W 5958996.60 N 652625.87 E 89.92 S 842.37W 5959000.90 N 652626.64 E 80.94 S 839.07W 5959009.94 N 652629.76 E 68.43 S 832.33W 5959022.59 N 652636.24 E 57.29 S 825.44W 5959033.87 N 652642.90 E 46.87 S 819.11W 5959044.41 N 652649.02 E 37.02 S 813.43W 5959054.38 N 652654.49 E 28.10 S 808,63W 5959063.40 N 652659.12 E 19.89 S 804.58W 5959071.68 N 652662,99 E 12.50 S 801.54W 5959079.14 N 652665.88 E 6.09 S 799.20W 5959085.59 N 652668.09 E 1.67 N 795.48W 5959093.43 N 652671.65 E 11.28 N 789.72W 5959103.15 N 652677.22 E 22.88 N 781.73W 5959114.92 N 652684.97 E 36.25 N 772.39W 5959128.47 N 652694.03 E 49.60 N 763.37W 5959142.01N 652702.77 E Dogleg Rate (°/lOOft) 0.604 3.824 8.730 6.325 7.246 3.747 3.971 7.139 7.175 4.828 7.481 5.932 4.001 7.226 6.539 2.260 1.180 0.743 0.541 0.520 0.694 0.883 1.049 0.273 2.667 0.851 2.749 0.426 0.597 Alaska Drilling & Wells PBU WOAD Pad Vertical Section Comment 500.09 508.51 518.12 526.06 534.11 540.85 547.36 553.65 559.61 564.92 569.49 573.28 576.14 578.59 580.99 583.12 586.42 589.40 591.38 593.31 595.37 597.49 599.73 602.21 604.59 606.78 608.62 610.06 611.62 613.41 Tie On Point MWD Magnetic Window Point 10 October, 2001 - 13:27 Page 2 of 5 DrillQt/est 2.00.08,005 Sperry-Sun Drilling Services Survey Report for D"19B MWD Your Reft AP1 500292020702 Job No. AKMM11149, Surveyed: 18 October, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8093.22 8.190 33.040 7846.31 7922.73 8188.01 10.660 36.960 7939.81 8016.23 8284.60 10.650 37.580 8034.74 8111.16 8380.17 9.150 37.520 8128.88 8205.30 8476.86 7.510 38.710 8224.55 8300.97 8572.88 8.910 35.850 8319.58 8396.00 8635.83 8.870 35.470 8381.78 8458.20 8701.00 7.970 34.910 8446.24 8522.66 8732.83 9.100 17.230 8477.73 8554.15 8763.13 10.410 0.190 8507.59 8584.01 8795.43 12.430 343.120 8539.26 8615.68 8826.67 14.000 335.350 8569.68 8646.10 8858.46 14.030 332.660 8600.52 8676.94 8890.63 16.260 324.100 8631.57 8707.99 8926.40 19.070 318.590 8665.66 8742.08 8959.15 21.330 312.730 8696.39 8772.81 8990.35 24.250 311.370 8725.15 8801.57 9023.32 28.110 308.200 8754.74 8831.16 9054.94 31.760 306.020 8782.14 8858.56 9086.86 35.350 304.470 8808.73 8885.15 9120.80 39.180 303.190 8835.74 ' 8912.16 9152.43 43.180 301.510 8859.54 8935.96 9183.33 47.170 300.990 8881.32 8957.74 9215.84. 51.380 300.630 8902.53 8978.95 9247.47 56.860 300.430 8921.06 8997.48 9279.25 61.850 301.850 8937.25 9013.67 9310.71 67.590 301.290 8950.68 9027.10 9343.67 73.470 300.260 8961.66 9038.08 9374.76 79.610 299.600 8968.89 9045.31 9406.41 85.200 296.280 8973.08 9049.50 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 62.02 N 755.15W 5959154.59 N 652710.74 E 74.69 N 746.20W 5959167.44 N 652719.43 E 88.90 N 735.39W 5959181.87 N 652729.95 E 101.93 N 725.37W 5959195.09 N 652739.70 E 112.95 N 716.74W 5959206.30 N 652748.11 E 123.88 N 708.46W 5959217.39 N 652756.16 E 131.78 N 702.79W 5959225.41N 652761.67 E 139.58 N 697.29W 5959233.31N 652767.01 E 143.79 N 695.28W 5959237.57 N 652768.93 E 148.82 N 694.56W 5959242.61N 652769.55 E 155.07 N 695.56W 5959248.83 N 652768.42 E 161.72 N 698.11W 5959255.43 N 652765.73 E 168.64 N 70t.48W 5959262.28 N 652762.22 E 175.75 N 705.92W 5959269.30 N 652757.64 E 184.19 N 712.72W 5959277.60-N 652750.67 E 192.25 N 720.64W 5959285.50 N 652742.59 E 200.34 N 729.61W 5959293.40 N 652733.45 E 209.62 N 740.80W 5959302.45 N 652722.07 E 219.12 N 753.39W 5959311.69 N 652709.29 E 229.29 N 767.81W 5959321.57 N 652694.67 E 240.72 N 784.88W 5959332.65 N 652677.37 E 251.85 N 802.47W 5959343.42 N 652659.55 E 263.22 N 821.21W 5959354.40 N 652640.59 E 275.83 N 842.37W 5959366.58 N 652619.18 E 288.84 N 864.43W 5959379.13 N 652596.85 E 302.99 N 887.82W 5959392.80 N 652573.18 E 317.87 N 912.05W 5959407.18 N 652548.65 E 333.76 N 938.74W 5959422.52 N 652521.64 E 348.84N 964.93W 5959437.06N 652495.15 E 363.52 N 992.64W 5959451.18 N 652467.15 E Dogleg Rate (°/~OOft) 1.261 2.691 0.119 1.570 1.705 1.518 0.113 1.387 8.930 10.413 12.124 7.578 2.051 9.800 9.133 9.255 9.509 12.449 12.043 11.562 11.513 13.120 12.968 12.977 17.333 16.165 18.316 18.081 19.857 20.493 Alaska Drilling & Wells PBU WOAD Pad Vertical Section Comment 615.20 616.59 617.57 618.39 618.96 619.74 620.55 621.41 622.62 625.33 630.14 636.39 643.45 651.44 662.09 673.34 685.42 699.95 715.70 733.27 753.68 774.29 795.92 820.21 845.45 872.42 900.52 931.14 960.86 991.47 10 October, 200I. 13:27 Page 3 of 5 DrillQue s t 2.00. 08.005 Sperry-Sun' Drilling 'Services Survey Report for' D. f9B MWD Your Ref: APl 500292020702 Job No. AKMM11149, Surveyed: 18 October, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 9437.04 89.320 293.860 8974.54 9050.96 376.48 N 1020.34W 5959463.57 N 652439.19 E 9469.55 91.660 301.050 8974.26 9050.68 391.46 N 1049.17W 5959477.95 N 652410.06 E 9566.07 95.170 297.650 8968.51 9044.93 438.67 N 1133.12W 5959523.45 N 652325.16 E 9661.56 91.600 296.310 8962.88 9039.30 481.91N 1218.05W 5959564.94 N 652239.36 E 9758.31 91.410 297.230 8960.33 9036.75 525.47 N 1304.40W 5959606.73 N 652152.14 E 9853.89 92.150 289.810 8957.36 9033.78 563.57 N 1391.94W 5959643,03 N 652063.84E 9949.80 88.770 297,150 8956.59 9033.01 601.75 N 1479.83W 5959679.41 N 651975.19 E 10046.75 90.250 296,510 8957.42 9033.84 645.51N 1566,34W 5959721.39 N 651887.81 E 10137.04 90.620 296,340 8956.73 9033.15 685.69 N 1647,19W 5959759.91 N 651806.15 E 10164.04 90.250 297.000 8956.53 9032.95 697.81 N 1671.32W 5959771.53 N 651781.78 E 10230.00 90.250 297.000 8956.24 9032.66 727.75 N 1730.09W 5959800.27 N 651722.41 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.498° (10-Oct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 310.410° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10230.00ft., The Bottom Hole Displacement is 1876.92fl., in the Direction of 292.814° (True). Dogleg Rate (°/100ft) 15.594 23.256 5.058 3.992 0.971 7.798 8.424 1.663 0,451 2.802 0.000 Alaska Drilling & Wells PBU WOAD Pad Vertical Section Comment 1020.97 1052.63 1147.16 1239.86 1333.84 1425.19 1516.87 1611.10 1698.71 1724.94 1789.10 Projected Survey 10 October, 2001 - 13:27 Page 4 of 5 DrillQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for D.'IgB MWD Your Ref: APl 500292020702 Job No. AKMMl f149, ,Surveyed: '18 October, 200'1 North Slope Alaska Alaska Drilling & Wells PBU WOAD Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6197.72 6052.64 113.47 S 753.38W 6231.00 6083.57 114.79 S 765.58W 10230.00 9032.66 727.75 N 1730.09W Comment Tie On Point Window Point Projected Survey Survey tool program for D-'19B MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 6197.72 6052.64 6197.72 6052.64 10230.00 9032.66 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (D-19) MWD Magnetic (D-19B MWD) 10 October, 2001 - 13:27 Page 5 of 5 DrillQ~est 2.00.08.005 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit D-19B BP Exploration (Alaska) Inc. Permit No: 201-112 Sur Loc: 1880' SNL, 1692' WEL, SEC. 23, TllN, R13E, UM Btmhole Loc. 4126' NSL, 3443' WEL, SEC. 23, T11N, R13E, UM Dear Mr. Stone: Enclosed is the approved applicatiOn for permit to redrill the above referenced well. The permit to redrill dOes not exemPt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling oPerations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit t° Drill application for Prudhoe Bay Unit D-19B. BlOWout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount. Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ! ~ day of June, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~, STATE OF ALASKA~r. b\ " ALASKA OI1~..,~lO GAS CONSERVATION COMMIS~' PERMIT TO DRILL 20 AAC 25.005 I n Exploratory [] Stratigraphic Test Iii Development Oil la. Type of work B Ddll [] Redfill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 71.5' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or Property Name 11. Type Bored (See 20 AAC 25.025) 1880' SNL, 1692' WEL, SEC. 23, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3816' NSL, 2789' WEL, SEC. 23, T11N, R13E, UM D-19B Number 2S100302630-277 At total depth 9. Approximate spud date 4126' NSL, 3443' WEL, SEC. 23, T11N, R13E, UM 07/16/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028284, 1836' MDI No Close Approach 2560 10225' MD / 8960' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6250' MD Maximum Hole Angle 90 ° Maximum surface 2418 paiD, At total depth (TVD) 8800' / 3298 paiD, 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 8-1/2" 7" 26# L-80 BTC-M '25-7e~ 6100' 5960' ~ '90Sa' 190 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr80 Vim Ace 1710' 8518' 8340' 10225' 9033' 275 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10565 feet Plugs (measured) See Diagram. true vertical 9008 feet Effective depth: measured 6834 feet Junk (measured) Top of Fish at 6834' (03/96) See Diagram. true vertical 6647 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 8 cu yds Concrete 110' 110' Surface 2702' 13-3/8" 3549 cu ft Permafrost II 2702' 2702' Intermediate 8758' 9-5/8" 1177 cu ft Class 'G', 130 cu ft PF 'C' 8758' Production Liner 1337' 7" 424 cu ft Class 'G' i'".~ !.~i'"" ,:.~"~' 828.,1', -...~8.94~. 7999' - 8552' Perforation depth: measured None true vertical None 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements "Contact Engineer Name/Number: Walter Quay, 584-4178 Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that tl~e foregoing is true and correct to the best Of 'my knowledge .......... Signed Dan Stone ~.,,._ -.~-~. ~ Title Senior Drilling Engineer Date '. ~....., ".' ~, ,I .~ ~.' · · ...'.., ; ".,,~ ,'~:...,~ .... ',. .- .," ' · ..... ' ', ',. '". ,'= '.' '~ .""',",:1,, ,,~,.~ ' ..'.. ', , :~.. ,.:'~:.:.'..,.',..... ',','~. '.... ;' ,'=~ ~;~.' .... · .~,,,.,,'.:,., ~,, ',..,~,~,=.~ :: ', ;.~.:..'.,:.: ...... , , ' ' , ~, ' ,. ' .;,~.',,~::,;,~ h. ,., '. ",., ~.:,,',; ,,::..=;" ,~,..,'~,,',, ,:..'.. ,.'.,'~...; ;I'i:..!'.,' :..,.,.~".., ,:..,: , ..i"i' ":' ~;'.~' Permit Number I APl Number ~ &llp(~ I~ I;)ate I See cover letter ...~_c::>/"- ~'~ 2__ 150-029-20707-02 ~ . L~ I-I~i i/~_j ~. . I for other requirements .... Conditions of Approval: Samples Required [] Yes [] No Mud Log:Re(; Jired [] Yes ~1 No Hydrogen Sulfide Measures ,~ Yes [] No Directional S~irvey Required ~ Yes [] No Required Working Pressure for ROPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K I[~'~K psi~ Other: ORIGINAL SIGNED BYD Taylor Seamount byorderof Commissioner the commission Date ,Approved By r-~ ~, ~ ,..-.... , Form 10-401 Rev. 12-01-85 Triplicate I Well Name: [ D-19B I Drill and Complete Summary I Type of Redrill (producer or injector): I Producer Surface Location: x = 653,466.52 / Y = 5,959,108.56 3400' FSL 1692' FEL S23 T11N R13E Umiat Target Start Location: x = 652,360 / Y = 5,959,503. 3816' FSL 2789' FEL S23 T11N R13E Umiat Target Intermediate x = 652,200 / Y = 5,959,575 Location: 3891' FSL 2948' FEL S23T11N R13E Umiat Bottom Hole Location: x = 651,700 / Y = 5,959,800 4126' FSL 3443' FEL S23 T11N R13E Umiat I AFL Number: 1 4P1719 I Estimated Start Date: I 07/16/01 I D: 0,225'1 I TVD:I 960' I Rig: I Nabors 7ES I Operating days to complete: I 17.5 I Cellar Elevation: 1 41.45'I I RKB: 171.5' I Well Design (conventional, slimhole, etc.): I Conventional Big Bore - 9-5/8" Sidetrack I Objective: I Complete well as Zone 2A Producer to replace original wellbore. Formation Markers Formation Tops MD TVDSS Comments Top Colville Mdstn (CM3) 5823 KOP in Colville Mudstone Kick Off Point 6250' 6030' Kick Off Point MW @ 9.6 ppg CMl 7068' 6832 THRZ 7458' 7218 BHRZ 7589' 7348 LCU 7602' 7361 Kingak 7762' 7519 MW @ 9.8 ppg. Need 9.7+ from chart & offsets. Top Kingak D (THE) 7879' 7635 Top Kingak D (TJD) 8190' 7943 Top Kingak D (TJC) 8360' 8112 Sag River Ss (TSGR) 8667' 8416 Top Sublik (TSHB) 8735' 8483 Top Sadleerochit (TSAD) 8773' 8521 Top Zone 4A (TZ4A) 8901' 8645 Top Zone 3 (TZ3) 8985' 8721 Top Zone 2C (TZ2C) 9051' 8777 Top Zone 2B (TZ2B) 9152' 8851 3298 psi (7.2 ppg EMW) reservoir pressure Top Zone 2A (TZ2A) 9329' 8941 TD 10,225' 8961 TD Criteria: D-19B Permit To Drill 6/5/2001 Page I Casing/Tubing Program Hole ~ize Csg/- Wt/Ft Grade Conn Length Top Btm mb~l O.D. ~,,q¢,~, MD/TVD MD/I'VD 8-1/2" 7" 26# L-80 BTC-Mod -,3r~13' 6100' / 5960' 6-1/8" 4-1/2" 12.6# 13Cr-80 Vam Ace -1710' 8518'/8340' 10,225'/9033' Tubing 4-1/2" 12.6# 12Cr-80 Vam Ace -8600' GL 8518'/8340' Directional KOP: I 6250' MD Maximum Hole Angle: Close Approach Well: Survey Program: -24° In original wellbore at 5300' MD -90° In tangent interval and through Reservoir section All wells pass BP Close Approach guidelines pass under Major Risk rules. Standard MWD Surveys from kick-off to TD. Mud Program Window Millin~l Mud Properties: LSND Density (ppg) I Viscosity I PV 9.6 I 40 - 60I 10 - 15 Whipstock Window in 9-5/8" I Yield Point tau0 3O - 35 4 - 8 pH I HTHP (cc's/3o min) I 8.5 - 9.5 <10 Intermediate Mud Properties: LSND I 8-1/2" hole section From sidetrack depth to top of Kingak at 7600' MD / 7432' TVD. Density (ppg) Viscosity I PV I Yield Point tau0 9.8 40 - 55I 10 - 18 I 20 - 27 3 - 7 pH 8.5 - 9.5 HTHP (cc's/30 min) I <10 I Production Mud Properties: Quickdril 16-1/8" hole section Density (ppg)I ViscosityI LSRV PV I YP 8.4 - 8.5+ I 45 - 60 < 12,000 cP 5 - 8 20 - 25 MBT <3 APl FI pH N/C 8.5-9.0 Logging Program 8 1/2" Intermediate: Drilling: MWD/GR/Res / PWD - Realtime over entire interval. Sample catchers as per on-site Geologist. Open Hole: No open hole logs are planned. Cased Hole: No cased hole logs are planned. 6-1/8" Production: Drilling: MWD/GR/Res / PWD - Realtime over entire interval. Den / Neu - Recorded over entire interval. Sample catchers as per on-site Geologist. Open Hole: No open hole logs are planned. Cased Hole: No cased hole Io~ls are planned. D-19B Permit To Drill 6/5/2001 Page 2 Cement Program Casing Size I 7" Drilling Liner Basis: Lead: None Tail: Based on 1000' of open hole Tail TOC: -7670' MD 7500' TVD Fluid Sequence & Volumes: Pre Flush Spacer Tail with 30% excess and 82' of 7" shoe joint. None 35 bbls NSCI Viscosified Spacer weighted to 12.8 ppg 34 bbl / 190 ft3 / 166 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk, BHST 217° / BHCT 150° (use actual circulating temps recorded by MWD at TD), TT = Batch Mix + 4 to 4.5 hrs *See Attached Halliburton Cement Program for Details on Cement Formulation* ICasing Size I 4-1/2" Production Liner Basis: Lead: None Tail: Based on 82' of 4-1/2" shoe track, 1557' of open hole with 50% excess, 150' of 7" x 4Y2" liner lap, and 250' of 7"x 4" DP annulus volume. Tail TOC: -8518' MD 8340' TVD'..- Liner top. Fluid Sequence & Volumes: Pre Flush Spacer 15 bbls Fresh water at 8.3 ppg 30 bbls NSCI Viscosified Spacer weighted to 12.0 ppg Lead None Tail 49 bbl / 275 ft3 / 239 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk, BHST 225° / BHCT 155° (use actual circulating temps recorded by MWD at TD), TT =- Batch Mix + 4 to 4.5 hrs *See Attached Halliburton Cement Program for Details on Cement Formulation* D-19B Permit To Drill 6/5/2001 Page 3 Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 3298 psi @ 8800' TVDss - Ivishak · Maximum surface pressure: 2418 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 8.6 ppg seawater / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. D-19B Permit To Drill 6/5/2001 Page 4 Sidetrack and Complete Procedure Summary Ri_q 1. 2. * Notify the field AOGCC representative with intent to re-enter the well * Liquid pack 9 5/8" x 5 Y=" annulus and the 5 Y=" tubing to surface. Pressure test the tubing and cement P&A plug to 3000 psi for 30 minutes. Pressure test the 9-5/8" x 5-1/2" annulus to 3000 psi for 30 minutes. Rig up E-line. Run a continuous gyro (Gyrodata) from surface to the TOC tag in 5Y=" tubing (6315'). Cut the 5Y=" L-80 tubing at -6300' MD (this is -15' above the WL tag up on 5/17/01 and 16' into the fourth joint below the GLM assembly at 6122' MD, as per Tubing Summary dated 5/10/82). This cut will not be fished, so the use of a jet or chemical cutter is at the discretion of the Wells Group Representative. Displace the well to clean seawater by circulating down tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel by circulating diesel down tubing and then reversing to fill the annulus with diesel to 2200' Pressure test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. If the pressure test fails, the pack-off will need to be changed out. Therefore, it is critical that the Iockdowns are functioned prior to rig arrival, and any Iockdowns repaired as needed. Set a BPV in the tubing hanger and secure the well. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. OI3erations: MIRU Nabors 9ES. Circulate out freeze protection and displace well to kill weight hrin~_,_lnr~ ..... *,~ tn m~;-*~;- ~, ....... pressure behind 9-5/8" casing). Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 5-1/2" tubing from E-line cut and above. 5. MU 9-5/8" whipstock window milling assembly and RIH to top of tubing stub. POOH. 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as desired and set on BP. Mill window in 9-5/8" casing at -6250' MD. Prior to POOH, pedorm FIT to 12.0 ppg EMW. POOH. 7. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag ~ ~8670 MD (8488' TVD). 8. Run and cement 7", 26¢ intermediate drilling liner to -150' back into window. POH. 9. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/DEN/NEU) to the liner landing collar. Test 7" liner from the landing collar to sudace to 3000 psi for 30 minutes. Drill out shoe and 20' of new formation. Pedorm FIT to 9.8 ppg EMW. 10. Drill 6-1/8" production section as per directional plan to an estimated TD of 10,225' MD (9033' TVD). 11. Run and cement a 4 Y~", 12.6¢ 13Cr-80 solid production liner throughout the 6-1/8" wellbore. Displace well to clean seawater above liner top. POOH SB DP. 12. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to sudace to 3000 psi for 30 min. 13. Pick up peal guns on 2-3/8" X 4-1/2" DP and RIH to pedorate - 400' of selective inte~als. Perforate well with -200 psi underbalance to the rese~oir. POOH LD DP. 14. Run 4-1/2" 12.6~ 12Cr-80 New Vam completion tying into the 4-1/2" liner top. 15. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 16. Freeze protect the well to -2200' and secure the well. 17. Rig down and move off. Post-Ric~ Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below production packer. Install gas lift valves. 2. Perforate 10' to 20' of Zone 2 with E-line conveyed guns. D-19B Permit To Drill 6/5/2001 Page 5 Job 1: MIRU Hazards and Contingencies :> No wells will require shut-in for the rig move to D-19 The two adjacent wells (D-18A and D-20 are both approximately 110' from the D-19 wellhead. Establish a minimum distance of 5' from the D-18A and D-20 wellhouse. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. If it appears the 5' distance will be crossed, the move should be stopped, the rig backed up, and the move re-attempted. D Pad is not designated as an H2S site, however Standard Operating Procedures for HaS precautions should be followed at all times. Recent H2S data from the pad is as follows: D-18 ~ 10 ppm June 1996 (well was shut-in August of 1996) Adjacent producers at Surface: D-17 10 ppm Nov 01, 00 D-19 8 ppm lQ 96 (well was shut-in March of 1996) D-20 10 ppm Mar 17, 01 Adjacent producers at TD: All as above: D-17, 19 D-10 10 ppm Jan 17, 01 The maximum recorded level of H2S on the pad was 15 ppm from D-17 on Nov 15, 1998. Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. .............. . ........ . Job 2: Decomplete Well Hazards and Contingencies ~ The perforations and bottom section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the Pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 5: Drill 8~" Intermediate Hole Hazards and Contingencies ~. On prior D Pad wells, lost circulation in the intermediate section has been experienced while drilling shallow sandstone intervals and when crossing faults in the Kingak shales. Most of these problems were encountered with MW > 10.2 ppg. No fault crossings are planned in the drilling of D-19B. The original well was drilled to Top Sag with 9.7 ppg and no losses. Several incidents of lost circulation have been seen when the Sag River formation was inadvertently penetrated. Extreme care should be taken when picking the 7" casing point. ~ The well will kick-off in the Colville (CM3) Mudstone drill through the HRZ, into the Kingak shale with the intermediate shoe in the Sag River formation. D Pad has a limited history of wellbore stability problems within the Kingak shales and of the problems encountered, minor incidents of tight hole and packing off have been the main problems. Most D Pad wells drilled the Kingak with 9.7 or 9.8 ppg. No stuck pipe incidents are noted on the pad data sheet. Most situations have been handled with additional washing and reaming followed by increased mud weights to stabilize the shale. Problems have been encountered in both high and Iow angle wells, however high angle wells have been most problematic. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. D-19B Permit To Drill 6/5/2001 Page 6 ~ The kick tolerance for the 8Y2" open hole section would be 125 bbls assuming a kick from the Sag River at ,~ -8670' MD. This is a worst case scenario based on an 8 ppg pore pressure gradient, a fracture gradient ~,\ of 11.2 ppg at the 13-3/8" shoe (leak in 9-5/8" casing), and 9.7 ppg mud in the hole. ~ ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is D-1 lA which is -475' well-to-well at 6007' MD and passes under Major Risk rules. Job 6: Install 7" Intermediate Liner Hazards and Contingencies > Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies No fault crossings are planned in the drilling of D-19B, however there is a minor east-west trending fault located about 160' north of the wellpath near its planned TD. Therefore, the given north side of the target polygon is hard. D Pad has a history of lost circulation events while drilling in the reservoir section. Losses have ranged from minor to severe (-150 bph). All cases of severe losses have been fault related and were managed by pumping fiberous LCM pills. As noted above, no fault crossings are planned in the drilling of D-19B, however be prepared for losses by establishing a contingency plan. ~ The kick tolerance for the 6-1/8" open hole section would be an infinite influx assuming a kick from the Ivishak at -10,225' MD. This is a worst case scenario based on an 7.8 ppg pore pressure gradient, a fracture gradient of 9.5 ppg at the 7" shoe, and 8.5 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is D-1 lA which is -475' well-to-well at 6007' MD and passes under Major Risk rules. Job 9: Install 4~,~'' Production Liner Hazards and Contingencies ~. Differential sticking could be a problem. The 8.5 ppg Quickdril will be -600 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release Riq Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. D-19B Permit To Drill 6/5/2001 Page 7 TREE: 6' ClW WELLHEAD: McEVOY ACTUATOR: OTIS 13 3/8". 72~W~t, I L-80, BTRS 2702' KOP: 4000' 24- @ 53o0' 17' @ 8900' 66' @ 93~2' 5 1/2", 17#~/Tt, L-80, AB BTRS TUBING '0PC) CAPACITY: .0232 BBL/FT 7" LINER 8281' 95/o-.47#~,I 8758' I' ' ' L-80, BTRS PERFORATION SUMMARY REF. LOG: SWS- BHCS- 5-7-82 TIE-IN LOG: SWS - CBL 5-10-82 2 7/0"1 4 I 9240- 9250' SQZD/4-30-88 31/8"I 4 [ 9300-9310' SQZD/4-30-88 2 7/8" ! 4 [ 9327- 9353' SQZD/8-30-91 2 7/8"1 4 I 9366- 9368' SQZD/8-30-91 D KB. ELEV =78.65' BF. F_LEV = 42.95' SSSV LANDING NIPPLE ( OTIS ) (4.~2.' ID) I Zl U4' GAS LIFT MANDRELS ' (OTIS LBD Wl RA "1 MD(BKB) i ~2 I ~000' I "11~' I '0I 5~' I Sl~' I 7 I 6763' I 6 I 7125' I 5 I 7279' I 4I 760~ I 3 I w5~ I 2 I 790~ I I I oo~3' I 5 1~" SLIDING SLEEK I (O~S ~ (4.~2"1D) I LATCH) TVDss 2921'" 4751' 5759' 5903° 6355' 6502' 6838' 6983' 7287' 7432' 7568' 7718' 8135' BOT SBR I 8201' 9 5/8- PACKER 8221' t ( BOT ) (4.750"1D) 4 1/2", 12.6~/ft, L-80 TAILPIPE 4 1/2" "X" NIPPLE (OTIS) (3.813" ID) 8284' 4 1/2" "XN" NIPPLE (OTIS) (3.725" ID) 8315'= 4 1/2" TBG TAIL [ 8357' ( BOT )(SOS) (ELMD- REF BHCS 5-7-82) I 8348' BAKER WHIPSTOCK I 8936' W, NOOW FROM 8941'-8~47' 3.75" HOLE TO 10564' BIT STUCK AT 10360' HOL~:~ ' , , FISH IN 2-3/8" coiled tubing, top at 6834'. 5/8" umbilical inside coil, top at 6844'. 2 Kinley cutters inside coil. Camco BHA #3, 3.375" OD, 25.08' Radius UBHO, monel, 3.125" OD, 16.8' Drilex tandem 2.875" motor, 12.88' Hycalog, HS-38HG bit, 3.75" OD, .42' , , , , .... Cement plug set 2/25/96 Top @ 9166'. PBTD I 9580' I 7", 26~ft, L-80,1J4S { 9618'I DATE 5-12-82 1-21-92 2-1~-94 gl;~-94 3-31-96 REV. BY I COMMENTS ! iNiTiAL COMPLETION A. TEEL I REVISED " MELVAN I cTU CMT sQz ICT SIOET~CK:.F,~" LOST 4-22-86 - BOWSPRING CENTRALIZER ARM, 2' L x 1/2" W x 1/8" T. FISH IS AT OR BELOW 9460' WLM. PRUDHOE BAY UNIT II W~(2-2--23'-~'~-13! I~ BP Exploration (Alaska} I! TREE = 6" ClVV WELLHEAD= MCEVOY A GrUA TO R= OTIS 'i~i3'i'"~"":- 78.65 '~3~i'"~"'~ ................................................ 42.95 "k6i~'; 4000 'Datum MD = 9206 Datum TVDss= 8800' D-I ' Planned Pre-R'3 13-3/8" CSG, 72#, L80, ID=12.347 Id 2702' ~ 5-112" Tubing Cut @ +-6300' J 8135' H5-1/2,, OTIS 'XA' SLIDING SLV, ID:4.562 I I 5-1/2" TBG, 17#, L80, .0232 bpf, ID=4.892 8222' I TOP OF 7" LNR 8281' I 4-1/2" TAILPIPE, 12.6#,L80, .0152 bpf,ID=3.958 I"-~ 8357' 9-5/8" CSG, 47#, L80, ID=8.681 Id 8758' 25FISH IN HOLE 2-3~8" coiled tubing, top at 6834' /8" umbilical inside coil, top at 6844' Kinley cutters inside coil. 8201' Id 5-1/2" BOT SaR [ 8221' H9 5/8" x 5-1/2" BOT PKR, ID=4.75 I 8222' H5-1/2,,x4-1/2. XO I 8284' 8315' 8357' Id4-1/2" OTIS 'X' NIP, ID=3.813 I Id4-1/2" OTIS 'XN' NIP, ID=3.725" I Id4-1/2" TBG TAIL, ID=3.958 I 8348' I-t I PERFORATION SUMMARY REF LOG: SWS-BHCS, 5/7/82 ANGLE AT TOP PERF: 143 @ 9240 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 7/8' 4 9240-9250 S 04/30/88 3 1/8' 4 9300-9310 S 04/30/88 2 7/8' 4 9327-9353 S 08/30/91 2 7/8' 4 9366-9368 S 08/30/91 3 3/8' 4 9368-9388 S 02/10/94 3 3/8' 6 9366-9406 S 02/25/96 MILLOUTWINDOW 8941'-8947' I 10360' FISH - CAMCO BI-IA #3, RADIUS BIT UBHO MONEL, DRILEX TANDEM 2.875" MOTOR. HYCALOG HS-38HG 10360' I 18936' Id BKR WHIPSTOCK I I-I 958o' I 7" LNR, 26#, L80, .0383 bpf, ID=6.276 H 96'18' DATE REV BY COMMENTS 05/12/82 ORIGINAL COMPLETION 06/11/96 PAB SIDETRACK COMPLETION 02/20/01 SlS-SLT CONVERTED TO CANVAS 03/08/01 SlS-LG FINAL 05/24/01 WDQ Pre-Rig PRUDHOE BAY UNIT WELL: D-19B PERMIT No: APl No: 50-029-20707-02 Sec. 23, T11 N, R13E BP Exploration (Alaska) CANVAS UPDATE: 03/08/01 13-3/8", 72 #/fi, L80, I 2702' BTC Top of 7" Liner at +/-6100' MD Window Milled from Whipstock Top of Window Bddge Plug set at +~-6274' MD Cut and Pul Tubing@ +-6300' Tag TOC with WL @ 6315' MD 5/17/01 FISH IN HOLE 2-3~8" coiled tubing, top at 6834' 5/8" umbilical inside coil, top at 6844' 2 Kinley cutters inside coil. 9-5/8", 47 #/ft, L-80, BTC D-19B Proposed Completion 4-1/2" 'X' Landing Nipple with 3.813' seal bore. Cellar Elevation = 43.50' Base Flange = 44.68' Nabors 9ES RKB = 73.5' 4-1/2" 12.6# 13Cr-80 Vam Ace Tubing with GLM's BAKER 7" x 9-5/8" Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger GAS LIFT MANDRELS TVD Size TBD 1-1/2" TBD 1-1/2" TBD 1" TBD 1" TBD 1" RP Shear Dummy Dummy Dummy Dummy 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +1-8,518' I BAKER5"x7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger I +/-8668' ] 7", 26 #/ft, L-80, BTC-Mod 4-1/2" 12.6 #/ft, 13Cr-80 Vam Ace · . . Zone 2A Sands J+1-10,225' 7", 29 #/ft, L-80, ~ BTC Date Rev By Comments 05/18/01 WDQ Proposed Completion PRUDHOE BAY UNIT WELL: D-t9B APl NO' 50-029-20707-02 Shared Services Drilling Sl::)lar~-sunI North Slope Alaska ~"~'"~~?~I Alaska Drilling & Wells PBU_WOA D Pad D-19B WPS WP03 ] DrillQuest' ROW 1:: o Z 600- Total Depth :, 10224.34ftM D,9032.97ftTVD ! <, End Dir, Start Sail @ 89.960°: 9701.60ftMD,9032.60ftTVD .] D-19~ BHL I Begin Dir @ 6.00°ll0Oft : 9629.70ft MD, 9035.26ft TV[ ..... ~052.95' TVD~ I End Dir Start Sail @ 94 280° · 9553 70ftMD 9040 9 e lrz" uner I _ [ i t · · · , · 10224 34' MD/727'93 N, 1752,>0 W ~ j / Decr in D~r Rate @ 8.00°/10Oft: 95DO.21ff MD 91 ,o.~,_;7, wo/ . !t ] / ' ~-. ~ ~"'~*z~,.';:'~",-~ / / ........ I I I -1800 -1200 -600 0 6300 - 6900 - ~ 7500 - n o .-- 8100 - 8700 - 9300 - 300 Scale: linch = 600ft ~,~ ~;.~,; Scale: 1 inch = 600ft ........ ~~ CM3 ~895.9~' TVD ~ /ST Exit @ 10.00°/100ft, 85.00 RT TF: 6250.00ft MD, 6101.00ft TVD \~6~0.:.;;egln ,Ir @ 6.00o1100,,: 6280.00,t MD, 6128.95,, TV, ~/' Eastings Reference is True North Plan \ Current Well Properties Well. D-19B WP03 Horizontal Coordinates: Ref. Global Coordinates: 5959108.00 N, 653467.00 E Ref. Structure Reference: 3490.45 N, 1374.24 E Ref. Geographical Coordinates:700 17' 42.8233" N, 2110 14' 33.7002" E 72.95ft above Mean Sea Level 72.95ft above Structure Reference RKB Elevation: 75O0.00 ' ~ .: 4 North Reference: True North ~, [.CU~i<k,~k 7~;~..,~.~' TV~ Units: Feet (US) ................................... ~. ~,-:~' .:~ ..~ ................................. oo.oo ........................................................................................................................................................................................................................................................... .ro.o., ,o, ~' X~ ~ Horizontal Origin: Well Noffh Rofore~e: Tree Noah . 310.410~ [,,.,. o* q. e~ ~.x ....... :~': Weft 0.00 N,O.O0 E X ~ ~ ~ ~ ~ WD..TCG[~Z3 870~ SS' TVD / 6719.887.9t0:H.950 655S.~3 83.275 843.20W 58S. i0 .................. x .......... ,---,.--~---, .... ~- ................. ~b:~;.-;~;~;};:;~W-, ~,,~.,, ,.~o ~,.~so~,:.~ ~.~N ~.~ ~.<~ ............................................. a .................................. ... ~ - ~" ,.~.*, ,~- - 9676 ............. 91 5~ 295 3~ ~ ~2 }3 492 78 N 257 28 W1276.806.(X), ~~5 ' ~ ' ~ . ·, ,~ ........................... [ 102~.3489.~) 295.3~)~)32.97 727.89 N 1752.64 W8 ~ ~) (),~ ~ ~ ,,,~ ~19B WP03 ~ 4 112" Lnor .......................................................................................................................................................................................................................................... .," .... / ~¢, ~ ,/X ~0~2.~7' TVD N, 1098,70 W ,,' D-I*~B BHL~ ~.~.~ ~ T~ ~o3~:~S'"rw~ 903~,95' TVD 727,93 N, 1752.56 W 4~2.77 N. 1257,20 W Total ~pth: 10224.34ftMD,9032.97ffTVD I I 900 1500 2100 Ve~ical Section Section Azimuth: 310.410° (True No~h) DrillQuest 2.00.09.001 OSAL REPORT ~ .. 5 June, 2001 :."::. !::'~: ...... Su~e Coordinates: 5959108.00 N, 653467.00 E (70° 17' 42.8233'N, 211° 14' 33.7002' E) Kel¥ Bushing: 7£.95fl above Mean Sea Level OR i!_t-- I N (~ SERVICES A Halliburton Company Proposal Ref: pro 10831 Sperry-Sun Drilling Services Proposal Report for D-19B WPS North Slope Alaska Measured Depth Incl. (ft) D-19B reca Sub-Sea Vertical Depth Depth (ft) (ft) 0.00 0.000 0.000 -72.95 0.00 100.00 0.394 129.751 27.05 100.00 200.00 0,300 134.782 127.05 200.00 300.00 0.295 135.882 227.05 300.00 400.00 0.340 185.044 327.04 399.99 500.00 0.192 169.440 600.00 0.388 186.419 700.00 0.227 158.541 800.00 0.342 148.595 900.00 0.306 104.781 80.325 85.091 91.703 ~iii.i-:i';iiii;:i;:i'~:l 70.990 .... 83.106 :~/::;': .t..327~02 %% 1399.97 90.955 ~.~:;:..:;:::1427.02 1499.97 54.820 1527.02 1599.97 134.704 1627.02 1699.97 139.428 1727.02 1799.97 1~.055 1827.02 1899.97 1000.00 0.446 1100.00 0.391 1200.00 0.556 1300.00 0.356 1400.00 0.454 1500.00 0.202 1600.00 0.285 1700.00 0.251 1800.00 0,265 1900.00 0.289 Local Coordinates Northings Eastings (ft) (ft) 427.04 499.99 527.04 599.99 627.04 699.99 ....... :. :.:!.:.!.:-2;96:S ..... 727.04 799.99 ...... ~,,~.:::::::.!? ~::i?i.:'~. 3.42:i~ 827.04 899,99~. ':;'::.i::.!:;:i?, '?.':' ~,~4S 927.04 ..~:~..~;..~ ...... 999.99 ?!? ':'~' 3.73 S . ..: ... :.. :..: ~ ~ .:.-...~:: 1027.O37':': %:;:.:~0 99~9877' 3.64 S 3.63 S 3.53 S 3.39 S 2000.00 0.447 152.966 1927.02 1999.97 2100.00 0.768 173.734 2027.01 2099.96 2200.00 0.787 191.801 2127.00 2199.95 2300.00 0.893 193.933 2226.99 2299.94 2400.00 0.796 207.273 2326.98 2399.93 2500.00 0.713 207.308 2426.97 2499.92 2600.00 0.483 226.975 2526.97 2599.92 2700.00 0.754 246.890 2626.96 2699.91 2800.00 0.809 243.910 2726.95 2799.90 2900.00 0.725 272.085 2826.94 2899.89 0.00 N 0.00 E 0.23 S 0.28 E '~':::i?i'iii:", 595910~ N 0.64 S 0.73.~i!;~i?:i i?:i'!ii!i'ii~:959107'ii~ N .... 1.00 S .... 1.11;';:'E-. '5959107.02 N 1.50 S .:,i .i'.:~:~:: 1~:~25'E::i:~:~:::~: ~ ~9106.53 N 1.94'iS~. !:iii":!i:- 5950106.09 ~ 2;46giii:'i':'i:.!~?i:~ '::~":'i"~i~4 I= 5050105.57 ~ 1.28 F: 5959'105.06 N 1.50 E 5959104.61 N 1.92 E 5959104.30 N Global Coordinates Dogleg Northings Rate (fi) ..... (fi) (°/100fi) 5959I~0ON ~'3467.00 E 653467.29 E 0.394 653467.74 E 0.099 653468.13 E 0.007 653468.28 E 0.267 Vertical Section 0.00 -0.37 -0.97 -1.49 -1.92 2.57 E 5959104.32 N 3.28 E 5959104.43 N 4.12 E 5959104.45 N 4.89 E 5959104.57 N 5.59 E 5959104.73 N 653468.30 E 0.163 -2.21 653468.29 E 0.212 -2.54 653468.34 E 0.215 -2.89 653468.57 E 0.125 -3.36 653468.99 E 0.244 -3.88 3.35 S 3.19S 3.21 S 3.54 S 3.92 S 6.15 E 5959104.77 N 6.53 E 5959104.95 N 6.89 E 5959104.93 N 7.19 E 5959104.60 N 7.49 E 5959104.24 N 653469.64 E 0.210 -4.37 653470.35 E 0.065 -4.85 653471.20 E 0.173 -5.49 653471.96 E 0.256 -6.01 653472.66 E 0.129 -6.45 4.46 S 5.49 S 6.82 S 8.26 S 9.63 S 7.82 E 5959103.70 N 8.08 E 5959102.68 N 8.00 E 5959101.34 N 7.68 E 5959099.89 N 7.16 E 5959098.52 N 653473.21 E 0.256 -6.85 653473.59 E 0.170 -7.04 653473.95 E 0.345 -7.33 653474.26 E 0.026 -7.77 653474.57 E 0.032 -8.24 10.82 S 11.64 S 12.18 S 12.78 S 13.02 S 6.56 E 5959097.32 N 5.98 E 5959096.48 N 5.05 E 5959095.92 N 3.81 E 5959095.30 N 2.55 E 5959095.03 N 653474.91E 0.168 -8.84 653475.19 E 0.384 -9.71 653475.14 E 0.245 -10.51 653474.85 E 0.110 -11.20 653474.36 E 0.218 -11.70 653473.78 E 0.082 -12.01 653473.22 E 0.305 -12.10 653472.30 E 0.342 -11.75 653471.07 E 0.068 -11.19 653469.81E 0.382 -10.38 Alaska Drilling & Wells PBU_WOA D Pad Comment 5 June, 2001 - 13:04 Page 2 of 9 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for D-19B WPS North Slope Alaska Measured Depth Incl. (ft) Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 3000.00 0,756 237.885 2926.93 3100.00 0.367 230.979 3026.93 3200.00 0.330 246.069 3126.93 3300.00 0.330 262.923 3226.93 3400.00 0,505 267,489 3326.92 3500.00 0.587 256.456 3426.92 3600.00 0.362 258,020 3526.91 3700,00 0,226 260.800 3626.91 3800,00 0.178 243.817 3726.91 3900.00 0.682 194.522 3826.91 4000.00 2.344 4100.00 5,727 4200.00 9.263 4300.00 11.924 4400.00 13.311 4500.00 16.550 4600.00 19.559 4700.00 23.777 4800.00 24,240 4900.00 23.768 5000.00 24.066 5100.00 24.322 5200.00 24.357 5300.00 24.438 5400.00 23.924 5500.00 23.816 5600.00 23.710 5700.00 23.079 5800.00 23.199 5900.00 22.830 2999.88 13.38 S 1.34 E 3099.88 13.93 S 0.55 E 3199.88 14.25 S 0.04 E 5959~3.76..N- 3299.88 14.40 S 0.50 W :~; .:~:~.:.. 5959093!.6ON 3399.87 14.44 S 1.23 W ' ~i ..?,:: 5959093~4 N ...... 3499.87 14.59 S .2.19 ~:. '5959093.37 N 3599.86 14.78 S -:: ~:,-.':2~99~.W':i::.!:: ~ ~,,:. i5959093.17 N 3699.86 14.87 S ~ii~i::".: :::: ::~:'~"5959093.06 N 3799.86 14.94:.~S.-~:. ..... ~;::.:i:.. :~i:':::';i:3~8~i.W 5959092.98 N . 3899.86 ..... t5;56 S:"::~!'!%.:i :::.::i~ '::::~'i:~5 W 5959092.36 N 218.069 3926.87 3999.82 .....~-:~i:,i:!-i::~ ?.i.'i.:;:~17.7~!S :~:~ ~ ~.~ .:~ · ~ :~ .:~:.'~:.~ ....... 238.348 4026.62 4099.,57:.. 243.529 4125.74 4.!98"~69:.::.:":'.?.~ '~:':.% 28.17 S 243.570 4224.01 ..... -..:..:.-....::.4~96..96 "..':;i:;:.i:i'i:i ~:'~'?'~' 36.57 S 259.808 . 4321.64';:~;':':;::'::-':'~:~-~::~;~39~:~59:::::...:? 43.15 S 267.552 :?:':~:.~ ~g.25'::'.':~:.L:,'.'.'.':¥"4~91.20'.:" 45.67 S 265.687 ~:;~;;~':.~...45~3:~34 :";:'::~:./;;;~-::~.~."4586.29 47.61 S 267.736 ::~.~:;~:.~;~-?~606;18 ::"':::.'."4679.13 49.54 S 263.425 :~¥~697.52 4770.47 52.79 S 263.841 4788.89 4861.84 57.30 S Global Coordinates Dogleg Northings Easting~::?:i??iiii~i~i!!i:i~::;i~:i,~:., Rate ... 5959994iO~?~,' ~:!;i.?!ii:!!~5 ~.~i~i:: E 0.394 :~i;iii~3467:;33 E 0.099 "~:~i~3466.79 E 0.097 653466.06 E 0.178 5.36W 5959090.15 N 10.86W 5959085.80 N 22.37W 5959079.38 N 38.83W 5959070.65 N 59.36W 5959063.65 N Vertical Section -9.69 -9.45 -9.26 -8.95 -8.42 653465.11 E 0.133 -7.79 653464.31 E 0.225 -7.30 653463.82 E 0.136 -6.98 653463.48 E 0.076 -6.78 653463.26 E 0.582 -7.00 84.96W 5959060.61N 115.81W 5959058.04 N 152.85W 5959055.35 N 193.43W 5959051.27 N 233.82W 5959045.94 N 653462.01 E 1.740 -7.43 653456.59 E 3.620 -5.98 653445.21E 3.596 -1.23 653428.93 E 2.661 5.86 653408.53 E 3.793 17.23 264.287 4880.30 4953.25 61.47 S 263.930 4971.51 5044.46 65.70 S 264.389 5062.63 5135.58 69.88 S 264.225 5153.68 5226.63 73.99 S 264.599 5244.92 5317.87 77.97 S 274.14W 5959040.94 N 314.92W 5959035.88 N 355.92W 5959030.87 N 397.05W 5959025.92 N 437.80W 5959021.11 N 653382.99 E 3.798 35.09 653352.18 E 3.064 57.32 653315.19 E 4.284 84.27 653274.69 E 1.814 113.06 653234.40 E 0.501 140.89 264.378 5336.36 5409.31 81.85 S 264.028 5427.87 5500.82 85.94 S 264.311 5519.67 5592.62 89.96 S 264.271 5611.62 5684.57 93.86 S 263.611 5703.65 5776.60 98.00 S 478.07W 5959016.41N 518.19W 5959011.50 N 557.65W 5959006.67 N 596.78W 5959001.98 N 635.67W 5958997.04 N 653194.17 E 0.349 168.89 653153.49 E 0.295 197.20 653112.59 E 0.192 225.70 653071.55 E 0.106 254.36 653030.89 E 0.537 282.81 652990.70 E 0.140 310.96 652950.68 E 0.176 338.85 652911.30 E 0.641 366.29 652872.26 E 0.122 393.56 652833.47 E 0.451 420.49 Alaska Drilling & Wells PBU_WOA D Pad Comment 5 June, 2001 - 13:04 Page 3 of 9 DrillQuest 2,00.09.001 Sperry-Sun Drilling Services Proposal Report for D-19B WPS North Slope Alaska Measured Depth Incl. (ft) Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 6000.00 22.187 263.652 5796.05 5869.00 6029.11 22.222 263.857 5823.00 5895.95 6100.00 22.247 264.283 5888.60 5961.55 6200.00 21.372 263.822 5981.45 6054.40 6250.00 21.132 263.922 6028.05 6101.00 D-19B WP03 6280.00 21.590 6300.00 20.436 6400.00 14.775 6500.00 9.524 6600.00 5.907 272.060 6056.00 6128.95 272.982 6074.67 6147.62 279.640 6169.95 6242.90 293,802 6267.70 331.122 6366.84 ...,...... 6~'9.79 25.037 ~!?::.'i::'i~.~:6466.28..:.., .6539i'23 31.950 ':=:?.i~565:3~- ':.::::..' 6638.29 31.950 ?;;'ii:6664.39 6737.34 ~[.: .... 31.950 6763.44 6836.39 6700.00 7.131 6719.88 7.910 6800.00 7.910 6900,00 7.910 7000.00 7.910 7068.21 7.910 31.950 6831.00 6903.95 7100.00 7.910 31,950 6862.49 6935.44 7200.00 7,910 31,950 6961.54 7034.49 7300.00 7,910 31.950 7060.59 7133.54 7400.00 7.910 31.950 7159.63 7232.58 7500.00 7,910 31,950 7258.68 7331,63 7600.00 7.910 31.950 7357.73 7430.68 7602.29 7.910 31,950 7360.00 7432.95 7700.00 7.910 31.950 7456.78 7529.73 7800.00 7.910 31.950 7555.83 7628.78 Local Coordinates Northings Eastings (ft) (ft) 102.25 S 673.68 W 103.45 S 684.61 W 106.21 S 711.32 W 110.07 S 112.00 S Global Coordinates Dogleg Northings Easting~, (fi) (fi) 0.643 5958990i59..:N 652784;64 E 0.291 5958987.29:N : 652757'~99 E 0.230 ~: .',.~ ':~,..~-.~ ,~;~ ~ !':! 2.06:$ 784.34 W ' ~.09;O2'S 814.37 W 103.54 S 834.53 W 95.69 S 844.59 W :652721.15 E 0.892 652703.17 E 0.485 5958979.78 N 652692.28 E 9.991 5958979.95 N 652685.11E 6.000 5958982.38 N 652655.03 E 6.000 5958987.44 N 652634.76 E 6.000 5958995.09 N 652624.54 E 6.000 85.55 S 844.45W 83.27 S 843,20W 73.91 S 837.37W 62.24 S 830.09W 50.56 S 822.81W 5959005.23 N 652624.47 E 6,000 5959007.53 N 652625.67 E 6.000 5959017.00 N 652631.31 E 0.000 5959028.83 N 652638.36 E 0.000 5959040.65 N 652645.40 E 0.000 42.59 S 817.84W 38.88 S 815.52W 27.21S 808.24W 15.53 S 800.96W 3,85 S 793.68W 5959048.72 N 652650.20 E 0,000 5959052.47 N 652652.44 E 0.000 5959064.30 N 652659.48 E 0.000 5959076.12 N 652666.53 E 0.000 5959087.94 N 652673.57 E 0.000 7.83 N 786,39 W 19.50 N 779.11 W 19.77 N 778.94 W 31.18 N 771.83 W 42.86 N 764.55 W 5959099.77 N 652680.61E 0.000 5959111.59 N 652687.65 E 0.000 5959111.86 N 652687.81E 0.000 5959123.41 N 652694.70 E 0.000 5959135.24 N 652701.74 E 0.000 Vertical Section 446.67 454.22 472.77 498.39 510.86 518.91 524.57 549.41 568.31 581.07 587.53 588.06 589.68 591.70 593.73 595.11 595.75 597.78 599.80 601.83 603.85 605.88 605,92 6O7.9O 609.93 Alaska Drilling & Wells PBU_WOA D Pad Comment CM3 ST Exit @ 10.00°/100ft, 85.00 RT TF 6250.00ft MD, 6101.00ft TVD Begin Dir @ 6.00°/100ft · 6280.00ft MD, 6128.95ft TVD End Dir, Start Sail @ 7.910° · 6719.88ftMD,6558.93ftTVD C M 1/K5 LCU/Kingak 5 June, 2001 - 13:04 Page 4 of 9 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for D-19B WPS North Slope Alaska Measured Depth Incl. (ft) Sub-Sea Depth (ft) 7900.00 7.910 31.950 7654.88 8000.00 7.910 31.950 7753.93 8100.00 7.910 31.950 7852.97 8189.88 7.910 31.950 7942.00 8200.00 7.910 31.950 7952.02 Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) 7727.83 54.53 N 7826.88 66.21 N 7925.92 77.89 N 8014.95 88.38 N 8024.97 89.56 N 8300.00 7.910 31.950 8051.07 8124.02 8400.00 7.910 31.950 8150.12 8223.07 8500.00 7.910 31.950 8249.17 8322.12 8600.00 7.910 31.950 8348.22 8421.17 8667.03 7.910 31.950 8414.61 8487.56 8667.43 7.910 8697.71 7.910 8700.00 7.910 8742.71 7.910 8773.44 8.335 8800.00 9.860 8900.00 19.565 8984.63 29.121 9000.00 30.895 9051.45 36.878 31.950 8415.00 8487.95 31.950 8445.00 8517,95,:. '~'.:'!i.:::.'.;!:. 31.950 8447.26 852~2'~1i.:';:':::.~,~. "~'?.i".:.~. 147.95 N '~:'~.-~. ii~ : ~:~ ~:~ ~; s~::~. 31.950 8489.57 ..,.:::~::~..~.~.,,85~.52 ?.% :'~:' .... 152.94 N 5.795 =';.;;:i:.:!?i8520.~6;i~.:..: 347.962 :':iii:i:::i:;:i:...8~6!g~ "'~!i!i:i!:i.".:~:, a6~ 9.~ a 318.244 ~'~':;;.:;8642:g6 :~?~'~: 8715.91 309.736 ?: ;~7.8720.00 8792.95 308.727 8733.31 8806.26 305.992 8776.00 8848.95 9100.00 42.569 304.032 8813.33 8886.28 9139.05 47.166 302.742 8841.00 8913.95 9200.00 54.365 301.069 8879.53 8952.48 9204.27 54.870 300.963 8882.00 8954.95 9300.00 66.214 298.878 8929.00 9001.95 9329.30 69.691 298.318 8940.00 9012.95 9400.00 78.089 297.058 8959.60 9032.55 9500.00 89.975 295.393 8969.98 9042.93 9500.16 89.994 295.391 8969.98 9042.93 9500.21 90.000 295.390 8969,98 9042.93 101.24 N 112.92 N 124.60 N 136.27:.:~.N ~. 144,'~.0'~: .::.:~}:~4. ! 5.i;N 757.26 W 749.98 W 595~i.58i88;:~. 742.70 W 5959.~!~.7!~i.~': .. 736.15 W ,::~.i:.'-.. 59591ff~;33'N -: :: ~. ::. -.~..~ 735.42 W ~i ~.i;i.! 5959182;53 N 7¢8~.3 ~:~.~ '~!59~9194.35 N ~-720;85;~..~ii:ii;':: ~,~:.~ .. 5959206.18 N ;~.?:~-.13.[:57~ '::~:; ~:'~ :~' 5959218.00 N :'7~29~W 5959229.82 N 7~:.~1 W 5959237.75 N Global Coordinates Dogleg Northings Easting~:~iiii!;i!!,?iii!iiiii~ii~i~i,~?:~ Rate 5959147,06. Niii!~iii)iii~.:: 6~2'70~i~8 ~i:!i;!ii;i!i!:i::: 0.000 '652729.20 E 0.000 652729.91E 0.000 Vertical Section 611.95 613.98 616.00 617.82 618.02 652736.95 E 0.000 620.05 652743.99 E 0.000 622.07 652751.04 E 0.000 624.10 652758.08 E 0.000 626.12 652762.80 E 0.000 627.48 701.38W 5959237.79 N 652762.83 E 0.000 699.17W 5959241.38 N 652764.96 E 0.000 699.00W 5959241.65 N 652765.12 E 0.000 695.89W 5959246.70 N 652768.13 E 0.000 156.95 N 694.55W 5959250.73 N 652769.39 E 12.000 161.09 N 694.83W 5959254.87 N 652769.03 E 12.000 182.03 N 707.81W 5959275.54 N 652755.62 E 12.000 205.83 N 733.15W 5959298.81N 652729.80 E 12.000 210.69 N 739.11W 5959303.55 N 652723.75 E 12.000 228.04 N 761.92W 5959320.43 N 652700.58 E 12.000 245.81 N 787.34W 5959337.68 N 652674.80 E 12.000 260.95 N 810.34W 5959352.35 N 652651.50 E 12.000 285.85 N 850,41VV 5959376.43 N 652610.93 E 12.000 287.65 N 853.40W 5959378.16 N 652607.91 E 12.000 329.08 N 925.56W 5959418.11N 652534.92 E 12.000 342.07 N 949.40W 5959430.62 N 652510.82 E 12.000 373.59 N 1009.50W 5959460.90 N 652450.09 E 12.000 417.45 N 1098.56W 5959502.93 N 652360.14 E 12.000 417.52 N 1098.70W 5959503.00 N 652360.00 E 12.000 417.54 N 1098.75W 5959503.02 N 652359.95 E 12.000 627.49 628.10 628.15 629.01 630.59 633.49 656.95 691.67 699.35 727.97 758.85 786.18 832.83 836.27 918.07 944.65 1010.84 1107.09 1107.24 1107.29 Alaska Drilling & Wells PBU_WOA D Pad Comment TJD/Top Kingak D 7" Casing Sag River Ss WD-TSHU/Shublik Begin Dir @ 12.00°/100ft · 8742.71ft MD, 8562.52ft TVD WD-TSAD/TZ4B WD-TCGL/TZ3 WD-BCGUTZ2C WD-23SB WD-22TS WD-21TS Target - D-19B T1, Drillers Decrease in Dir Rate @ 8.00°/100ft · 9500.21ft MD, 9042.93ft TVD 5 June, 2001 - 13:04 Page 5 of 9 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for D-19B WPS North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9553.70 94.280 295.390 8967.98 9040.93 Local Coordinates Northings Eastings (ft) (ft) 440.46 N 1147.03 W 9600.00 94.280 295.390 8964.53 9037.48 460.25 N 9629.70 94.280 295.390 8962.31 9035.26 472.95 N 9675.94 91.504 295.390 8959.98 9032.93 492.75 N 9676.01 91.500 295.390 8959.98 9032.93 492.78 N 9700.00 90.056 295.390 8959.65 9032.60 9701.60 89.960 295.390 8959.65 9032.60 9800.00 89.960 295.390 8959.72 9032.67 9900.00 89.960 295.390 8959.79 9032.74 10000.00 89.960 295.390 8959.86 9032,.83.:. · :: ;:...:,::; :.:'.'" ' '"' 188.74 W 595~5~.8.~.'::~..- 215.50 W .,~ ~i-.,. 59595~;~ 257.21 W i. ;.' ii':i:;.:'15959574~::~8· N .-. ?~ .;~:: :: ~ ~ ~. 257.28-~;. '~.~59575.01 N .;! ;:i? :"<.:;: i;:-;, ": :::::,.i:':- :.,:~,,:?::'; ..... 1~28~,~9.-W 5959585.50 N 5O3.O7 N 503.75~N~. 1549.97W 10100.00 89.960 295.390 1640.31 W 10200.00 89.960 295.390 1730.65 W 10224.34 89.960 295.390 '.:'.'.:. }':'."8960.(~2..i::; '.9032i97 727.89 N 1752.64 W .. All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northi~igs and Eastings are relative to Well. 8959.93 ....:............ 9032.88 '.:::"'i:;ii: ~--;;~ 674.58 N 8960,00'?"'"='="..?:.'.9032:95 '"':=::~' 717.46 N .... ~.... .... .. :: .::.. .... ::...:....... .... Global Coordinates Dogleg Northings Eastings::~:;:;!?;!?iii?ii!:~ Rate 5959524.94. N:"?~: 6523..~ili1~i!22 Ei:?: 8.001 ..... :~:?.!:!~2269:11 E 0.000 :652242.10 E 0.000 Vertical Section 1158.90 1203.50 1232.10 652199.99 E 6.003 1276.70 652199.92 E 6.003 1276.77 652178.05 E 6.018 1299.94 652176.59 E 6.018 1301.48 5959625.87 N 652086.85 E 0.000 5959666.90 N 651995.65 E 0.000 5959707.92 N 651904.46 E 0.000 Magnetic Declination at Surface is -146.870° (04-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 310.410° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10224.34ft., The Bottom Hole Displacement is 1897.78ft., in the Direction of 292.554° (True). 5959748.94 N 651813.26 E 0.000 5959789.97 N 651722.06 E 0.000 5959799.95 N 651699.86 E 0.000 1396.52 1493.10 1589.69 1686.27 1782.85 1806.36 Alaska Drilling & Wells PBU_WOA D Pad Comment End Dir, Start Sail @ 94.280° · 9553.70ftM D,9040.93ftTVD Begin Dir @ 6.00°/100ft · 9629.70ft MD, 9035.26ft TVD Target - D-19B T2, Drillers End Dir, Start Sail @ 89.960° · 9701.60ftMD,9032.60ftTVD Total Depth · 10224.34ft M D ,9032.97ftTV D 4 1/2" Liner 5 June, 2001 - 13:04 Page 6 of 9 DrillQuest 2.00.09.001 Sperry-Sun Anticollision Report Date: 06/05/2001 Time: 07:48:40 Co-ordinate(NE) Reference: Well: D-19, True North Vertical (TVD) Reference: Plan D-19B 72.95' 72.9 Page: Company: BP Amoco Field: Prudhoe Bay Reference Site: PB D Pad Reference Well: D-19 Reference Wellpath: Plan D-19B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are l~[i~ltaim~s in this I~a~l~ipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 6250.00 to 10224.34 ft Scan Method: Trav Cylinder North Maximum Radius: 1219.19 ff Error Surface: Ellipse + Casing Survey Program for Defmitive Wellpath Date: 05/15/2001 Validated: No Version: 7 Planned From To Survey Toolcode Tool Name ff ff 94.15 6250.00 Sperry-Sun BOSS Gyro (0) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6250.00 10224.35 Planned: D-19B wp03 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points Summary <-=-= ..... =-~ ....~-- Offset Wellpath :'---'-~ ............. > · Reference Offset Ctr-Ctr' ' NO-Go ' AllOwable. ' · · :' .Site ... · ' · ' ":wellll ' .. WellPath '. · ~ iMD'.~' :' MD .Distance Area.. Deviation "Warning ' ' '.' ". , : . ' " ft ' 'ft' ft': ft ft' . .' , : .. :.' PB D Pad D-06A D-06A V3 PB D Pad D-06APBI D-06APBt V5 PB D Pad D-06 D-06 V1 PB D Pad D-11A D-11A V1 PB D Pad D-11 D-11 V1 PB D Pad D-19 D~19 V3 PB D Pad D-19 D-19A V1 PB D Pad D-26A D-26A V1 PB D Pad D-26 D-26 V1 PB D Pad D-27 D-27 V1 PB D Pad D-31A D-31A V1 P B D Pad Delete Me D-19A D-19A V1 7559.23 7500.00 869.13 249.71 625.36 Pass: Major Risk 7583,17 7525.00 869.91 250.63 625.13 Pass: Major Risk 7655.09 7600.00 873.07 253,45 623.80 Pass: Major Risk 6250.00 6650.00 514.17 160.19 433.45 Pass: Major Risk 6250.00 6650.00 514,17 160.19 433.45 Pass: Major Risk 6299.94 6300.00 1.84 126.20 -124.36 FAIL: Major Risk 6299.94 6300.00 1.84 126.20 -124.36 FAIL: Major Risk 6289.59 6425.00 1210.38 368.65 1005.89 Pass: Major Risk 6289.59 6425.00 1210.38 368.65 1005.89 Pass: Major Risk Out of range 8900.00 11150.00 995.65 145.41 869.48 Pass: Major Risk 6299.94 6300.00 1.84 214.76 -212.92 FAIL: Major Risk Site: PB D Pad Well: D-06A Rule Assigned: Major Risk Wellpath: D-06A V3 Inter-Site Error: 0,00 !': .... "Reference :. '.' '. '::' :.'.:..Offset" ' '.. ' 'Semi,Major Axis ~/. :' ~:~..' "'i,' ' ' ' '" "' ' · ' Ctr-Ctr ' NO-Go AllOWable.:' ' '..' · .. .. ..... ~:D'""' . T? .. '. i~D.. · T .' = f .... '.Offset..TI~O+AZI.TFO~HS casing· ' Distance.' Area 'Deviation'= Warning ~' " ..'..'.:i':.:: .: .:.' · : .... · ............ .... .:.'.:.: :ft.:..i..deg :. :.:' deg;:., in:. '; ft..., ft;'. .'.:..:ft........... ...... · 6253.16 6103.95 6575.00 6405.85 29.58 37.84 60.78 156.00 6427.10 6269.19 6600.00 6429.44 29.50 39.43 61.47 139.10 6723.89 6562.91 6625.00 6453.05 29.43 39.83 61.99 30.04 6747.81 6586.60 6650.00 6476.68 29.43 40.15 61.58 29.63 6771.74 6610.31 6675.00 6500.32 29.43 40.48 61.17 29.22 6795.69 6634.02 6700.00 6523.97 29.43 40.80 60.76 28.81 6819.63 6657.74 6725.00 6547.63 29.43 41.14 60.36 28.41 6843.57 6681.45 6750.00 6571.26 29.43 41.48 59.94 27.99 6867.49 6705.14 6775.00 6594.87 29.43 41.83 59.51 27.56 6891.40 6728.83 6800.00 6618.45 29.43 42.17 59.08 27.13 6915.29 6752.49 6825.00 6642.01 29.43 42.54 58.65 26.70 6939.17 6776.14 6850.00 6665.54 29.43 42.91 58.20 26.25 6963.03 6799.77 6875.00 6689.04 29.43 43.28 57.75 25.80 6986.86 6823.38 6900.00 6712.52 29.43 43.65 57.29 25,34 7010.68 6846.97 6925.00 6735.97 29.43 44.04 56.82 24.87 7034.49 6870.56 6950.00 6759.40 29.43 44.42 56.35 24.40 7058.29 6894.13 6975.00 6782.81 29.43 44.81 55.87 23.92 7082.08 6917.69 7000.00 6806.21 29.43 45.19 55.39 23.44 7105.87 6941.25 7025.00 6829.59 29.43 45.59 54.90 22.95 7129.66 6964.81 7050.00 6852.97 29.43 45.98 54.42 22.47 915.49 211.49 734.13 Pass 922.31 214.92 737.07 Pass 922.07 215.58 737.26 Pass 918.90 216.45 732.46 Pass 915.77 217.31 727.71 Pass 912.69 218.16 723.02 Pass 909.67 219.07 718.33 Pass 906.75 219.99 713.73 Pass 903.94 220.90 709.24 Pass 901.24 221.81 704.86 Pass 898.64 222.79 700.49 Pass 896.12 223.79 696.19 Pass 893.69 224.77 691.98 Pass 891.34 225.76 687.86 Pass 889.10 226.78 683.79 Pass 886.95 227.81 679.82 Pass 884.92 228.83 675.97 Pass 883.00 229.84 672.25 Pass 881.18 230.87 668.60 Pass 879.47 231.91 665.08 Pass WELL DETAILS Name +N/-S +E/-W NortMng I~s ting[Latitude Longiiude Sbt D-19 3~q}0.85 1372.95 5959108XO 653467.C0 70~IT4Z823N 148'45'26.3{]OW 19 --0 ANTLCOLLISION SETIINGS Interpolation Method:MD Interval: 25.00 Depth Range From: 62511.00 To: 10224.,t4. Maximum Range: 1219.19 Reference: Plan: D-19B wp03 COMPANY [YETAILS / SURVEY PROGRAM BP.~o [~Fnt ~To S~y/P~ T~,I Cakuh~n ~fl~: M~um C~al~ ~.~ I~.~ P~: I)-19B ~3 VI MWI~iFR+MS ~r Sys~ ISCWSA Sm ~: Troy Cy~d~ ~ ~or S~ ~t~l+ C~g Wm~g ~g~: R~ ~ From Cokmr To MD From Colour To MD 0 6250 0 6250 6250 · · 7~ 6250 ~ 7~ 7~ 8~ 8~ 9~1 90~ 1 {~) I'anm[ W¢llpalh: Tie on MD: WI.] J J)ATI4 DET:'d I_~ I'hn I)- I).19 6250.00 Rig: Roi. Damnz I'hn D-IgB 72.95' 72.gSfl ::':'::- :::':~}~;,~i;- l~ lO {1~ 19~. -- IM~I(IMgAI. ~)ERRORg Travelling Cylinder Azimuth (TFO4-AZI) [deg] vs Centre to Centre Separation [200fi/in] 70.28 78.70 14881 175.53 5 &56. 24 D-19B TI 9553.70 94,28 21)5.39 9040.95 440.26 -I 1,17.13 8.00-O.(fi 7~]~.49 7 962~9.70 94.28 295.39 9035.28 472.75 -1215.60 0.~00.1]07,~I2.60 8 9676.01 91.50 ~)5.39 9O32.95 492.58 -1257.38 6.OO 179.92827.82 I)-IgB T2 9 9701.60 89.96 295.9) 9032.62 503.55 -1280.51 6.(,0 -179. h~ 852.85 10 10224.34 89.96 295.39 9(B2.95 727.(zq - 1752.76 0.150 O.0O I.~[02 D-loB T3 0 9000 lOOOO · ' ~ ~ 11~26A(IJ~26A). ,Vb~,rRi~k ' ~ ri ....... I).~0~0. ~),r R~k .. - /~ - ' . I 33~' . - ' / ~0 ~ 'h~ ~' 9~ / -... · .... -. --::""-,_" 'N I /' b.-'<:..::~'t'" ~:~"-, . ~,~ ...... -... . ....... . ...-.... ,,, :...:.:-. ~/..-.::./ .- _ - / ...' . ...... -, ~-~ -'.. '. ~,-'~ ~ Ii~..::'/:/.'-..-'.;-I:~ ,"'x.~ - - " / . -' ' :/ ~ · .:- X ' "~ / [ ~~ '- ~ : ~ ' 19o / / :-- . / . - . . ,,-.. .:.: x ~: : :~[.~,, ...,' . /' ./ -~ ~ - .. , X ' / . : : I .' ' ~" ~,, ' /. ' ~: / . .1 ~67 ~ -. ' - ~- 'x .... /~' ' / -' 1 180~' ~ .. -....... % .: .... ~ .-' ~/ ~./ ,...:.-: ' - xx - ' ' . I . · ' ' I - ' . · , . .. >. ' .,..,~ ~".:- "-': .. "" "i" ' ./.' / ~ " ' ' ' "'1 .... ..'". :' , / --~ - ~ .... .... ~ . . .- .~ ..... ~~ .... ~ ..... 2 6~.~ 21.~ 2~.~ 6128.95 -I 12.45 -7~.24 10.~ 85.~ H 189915 i os/l ol lOOker, is VENDOR ........ AL~)~AU i LA UU DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 051401 CKOS14OIH 100.00 100.00 PYMT (OMMENTS: Peen it to D~ill Fee HANDL]NO !NST: S/H- Tee*pie Hubble X4628 , 'HE ATt'ACHED CHECK IS mN PAYMENT FOR ITEMS DESCRIBED ABOVE. I (o]m ~r!~ ~ ] 100. O0 100. O0 BP EXPLORATION, (ALASKA)INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 No, H ~899~5 CONSOLIDATED COMMERCIAL ACCOUNT 00189~15 PAY To Th e ORDER O,~ ONE'~. HUNDRED & 00/100.~'~-~*~-~'~*~'~*~"~'~"~'~'~*~'~.'~'~~ US DOLLAR · :'::: ::'.".:=:6ATE:'~;:. ,MOUNT I 05:/1';'~ / O 1 ALASKA OIL AND OAS NOT~::VALID CONSERVATION COMMISSION 333 ,WEST 7TH aVENUE .S~i::TE ANCHORAOE TRA~'SMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAM~ CHECK 1 CHECK WHAT APPLIES STANDARD LETTER "CLUE" DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS The permit is for a new weilbore segment of existing well , Permit No, ~ APl No. ~. Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and APl number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be apprOved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... ( ) YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name)will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY 'Z~,~ FIELD & POOL ~:~ .~/_~'~-~ INIT C~ASS WELL NAME/~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .'~'~{~) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY PROGRAM: exp ~ dev ..~ redrll 74~ serv ~ wellbore seg ann. disposal para req ~ Y Y Y ,L AREA ~".~4D' UNIT# //~'~"0 ON/OFF SHORE N N N N Y N 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpressure zones ....... Y~" 32. Seismic analysis of shallow gas zones. Y/N 33. Seabed condition survey (if off-shore) .... ......... /Y N 34. Contact name/phone for weekly progress reports [exploratory o~Y]Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . ; . . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY:, ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: O Z O c:\msoffice\wordian\diana\checklist (rev. 11/01//00) 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 APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. ' Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Sep 11 07:44:49 2002 Reel Header Service name ............. LISTPE Date ..................... 02/09/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/09/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-ii149 J. MARTIN L. VAUGHAN D-19B 500292020702 BP Exploration (Alaska), Inc. Sperry Sun ll-SEP-02 MWD RUN 3 MWD RUN 4 AK-MM-ii149 AK-MM-ii149 J. MARTIN J. MARTIN A. MADSEN A. MADSEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 5 AK-MM-ii149 J. MARTIN A. MADSEN 23 11 13 1880 1692 .00 76.42 41.45 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 6231.0 2ND STRING 8.500 7.000 8694.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL CASING AND IS NOT PRESENTED. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. MWD RUNS 3 - 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (SLD). 5. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 6206' MD, 6060' TVD TO 6231' MD, 6084' TVD. 6. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 8629' MD, 8451' TVD TO 8694' MD, 8516' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 8621' MD, 8444' TVD TO 8694' MD, 8516' TVD. 7. DIGITAL DATA AND LOG DATA ARE TIED INTO THE PARENT WELL GR DIL LOG OF 05/07/82 WITH KBE = 78.07' A.M.S.L. AT THE KICK OFF POINT. THIS WELL KICKS OFF FROM D-19 AT 6231' MD, 6084' TVD (TOP OF WHIPSTOCK). ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 5 REPRESENT WELL D-19B WITH API 50-029-20707-02. THIS WELL REACHED A TOTAL DEPTH OF 10230' MD, 9033' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED MEDIUM SPACING ) SEDP = SMOOTHED DEEP SPACING ) SFXE = SMOOTHED SBD2 = SMOOTHED SCO2 = SMOOTHED BIN) SNP2 = ABSORPTION TNPS = (SANDSTONE CTNA = RATE CTFA = RATE PHASE SHIFT DERIVED RESISTIVITY ( PHASE SHIFT DERIVED RESISTIVITY ( FORMATION EXPOSURE TIME BULK DENSITY (LOW-COUNT BIN) STANDOFF CORRECTION (LOW-COUNT SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC FACTOR (LOW-COUNT BIN) SMOOTHED THERMAL NEUTRON POROSITY MATRIX, FIXED HOLE SIZE) SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: PPG 8.50 MUD FILTRATE SALINITY: CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: G/CC MATRIX DENSITY: G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 230 - 350 PPM 10,994 PPM CHLORIDES 1.00 2.65 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 6204.5 RPX 6219.0 RPS 6219.0 RPM 6219.0 RPD 6219.0 FET 6219.0 ROP 6269.5 NCNT 8683.0 FCNT 8683.0 RHOB 8683.0 DRHO 8683.0 PEF 8683.0 NPHI 8683.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 6207.5 6208.5 6219.0 6221.0 6229.0 6230.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 $ REMARKS: MERGED MAIN PASS. $ STOP DEPTH 10176.5 10184.0 10184.0 10184.0 10184.0 10184.0 10229.0 10139 5 10139 5 10155 0 10155 0 10155 0 10139 5 EQUIVALENT UNSHIFTED DEPTH MERGE TOP MERGE BASE 6205.5 8694.0 8694.5 9223.0 9223.5 9932.0 9932.5 10230.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CP30 4 1 68 NCNT MWD CP30 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD B/E 4 1 68 0 4 8 12 16 20 24 28 32 36 40 44 48 52 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 6204.5 10229 ROP MWD FT/H 0.36 337.76 GR MWD API 13.6 580.04 RPX MWD OHMM 0.14 1864.46 RPS MWD OHMM 0.13 1712.65 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.1 2000 FET MWD HR 0.32 60.71 NPHI MWD PU-S 5.63 66.03 FCNT MWD CP30 121.4 3004.07 NCNT MWD CP30 15271.3 49866.5 RHOB MWD G/CM 1.11 3.79 DRHO MWD G/CM -1.14 1.44 PEF MWD B/E 1.34 15.78 Mean 8216.75 95.795 96.6761 8.09237 8.9663 42.3769 25.745 2.94578 23.3773 668.985 29201.5 2.36333 0.0826689 3.13568 First Reading For Entire File .......... 6204.5 Last Reading For Entire File ........... 10229 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Nsam 8050 7920 7945 7931 7931 7931 7931 7931 2914 2914 2914 2945 2945 2945 First Reading 6204.5 6269.5 6204.5 6219 6219 6219 6219 6219 8683 8683 8683 8683 8683 8683 Last Reading 10229 10229 10176.5 10184 10184 10184 10184 10184 10139.5 10139.5 10139.5 10155 10155 10155 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6205.5 RPX 6221.0 RPS 6221.0 RPD 6221.0 FET 6221.0 STOP DEPTH 8628.5 8621.0 8621.0 8621.0 8621.0 RPM 6221.0 ROP 6270.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 8621.0 8694.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM} AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order ll-SEP-01 Insite 4.05.5 66.16 Memory 8694.0 3.9 21.0 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 8.500 8694.0 LSND 9.60 40.0 8.9 1000 7.8 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 1.800 64.0 .782 156.2 1.800 64.0 2.000 64.0 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 6205.5 8694 ROP MWD020 FT/H 0.36 337.76 GR MWD020 API 40.25 341.74 RPX MWD020 OHMM 0.85 1864.46 RPS MWD020 OHMM 0.82 1712.65 RPM MWD020 OHMM 0.81 1897.52 RPD MWD020 OHMM 0.1 2000 FET MWD020 HR 0.32 25.47 Mean 7449.75 111.59 135.248 3.00558 2.93233 3.39457 7.09921 1.80527 First Reading For Entire File .......... 6205.5 Last Reading For Entire File ........... 8694 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Nsam 4978 4848 4847 4801 4801 4801 4801 4801 First Reading 6205.5 6270.5 6205.5 6221 6221 6221 6221 6221 Last Reading 8694 8694 8628.5 8621 8621 8621 8621 8621 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 .5000, DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR NCNT PEF DRHO FCNT NPHI RHOB ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 8621 5 8621 5 8621 5 8621 5 8621 5 8629 0 8684 0 8684 0 8684 0 8684 0 8684 0 8684 0 8694 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER {FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9178 0 9178 0 9178 0 9178 0 9178 0 9170 5 9133 5 9149.0 9149.0 9133.5 9133.5 9149.0 9223.0 14-SEP-01 Insite 4.05.5 66.16 Memory 9223.0 8.0 43.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAiViMA RAY PB02153HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB02153HAGR4 CTN COMP THERMAL NEUTRON PB02155NL4 SLD STABILIZED LITHO DEN PB02155NL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.125 BOREHOLE CONDITIONS MUD TYPE: QUIKDRL-N MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 44.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 28.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.600 MUD AT MAX CIRCULATING TERMPERATURE: 1.552 MUD FILTRATE AT MT: 4.500 MUD CAKE AT MT: 3.000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CP30 4 1 68 36 10 NCNT MWD030 CP30 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 B/E 4 1 68 52 14 72.0 176.0 72.0 72.0 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM Min 8621.5 2 09 15 82 0 14 0 13 0 06 0 11 Max Mean Nsam 9223 8922.25 1204 225.5 51.9175 1058 580.04 56.6005 1084 631.14 29.031 1114 1476.45 35.1936 1114 2000 268.829 1114 2000 132.42 1114 First Reading 8621.5 8694.5 8629 8621.5 8621.5 8621.5 8621.5 Last Reading 9223 9223 9170.5 9178 9178 9178 9178 FET MWD030 HR 0.72 60.71 NPHI MWD030 PU-S 5.63 66.03 FCNT MWD030 CP30 121.4 3004.07 NCNT MWD030 CP30 15271.3 49866.5 RHOB MWD030 G/CM 1.11 3.79 DRHO MWD030 G/CM -1.14 1.44 PEF MWD030 B/E 1.79 15.78 9.07849 20.1684 852.634 30974.3 2.38311 0.0505371 3.58752 First Reading For Entire File .......... 8621.5 Last Reading For Entire File ........... 9223 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 1114 900 900 900 931 931 931 8621.5 8684 8684 8684 8684 8684 8684 9178 9133.5 9133.5 9133.5 9149 9149 9149 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF DRHO RHOB GR RPD RPX RPS RPM FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 9134.0 9134 0 9134 0 9149 5 9149 5 9149 5 9171 0 9178 5 9178 5 9178 5 9178 5 9178 5 9223.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9842.5 9842 5 9842 5 9858 0 9858 0 9858 0 9879 5 9887 0 9887.0 9887.0 9887.0 9887.0 9932.0 15-SEP-01 Insite 4.05.5 66.16 Memory 9932.0 47.2 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 CTN SLD $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S}: MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 ?B02153HAGR4 PB02153HAGR4 PB02155NL4 PB02155NL4 6.125 QUIKDRL-N 8.50 40.0 8.9 35O 10.9 3.600 1.864 4.500 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 72.0 145.4 72.0 72.0 Name Service Unit Min Max Mean Nsam DEPT FT 9134 9932 9533 1597 ROP MWD040 FT/H 1.81 260.1 82.1539 1418 GR MWD040 API 13.6 141.43 22.9494 1418 RPX MWD040 OHMM 3.18 28.25 7.44391 1418 RPS MWD040 OHMM 3.17 29.95 7.57889 1418 RPM MWD040 OHMM 3.2 44.53 8.55941 1418 RPD MWD040 OHMM 3.29 44.06 8.79508 1418 FET MWD040 HR 0.44 15.16 1.84566 1418 NPHI MWD040 PU-S 16.88 33.91 25.0973 1418 FCNT MWD040 CP30 375.74 931.41 573.997 1418 First Reading 9134 9223.5 9171 9178.5 9178.5 9178.5 9178.5 9178.5 9134 9134 Last Reading 9932 9932 9879.5 9887 9887 9887 9887 9887 9842.5 9842.5 NCNT MWD040 CP30 22583.5 34463.2 RHOB MWD040 G/CM 2.19 3.07 DRHO MWD040 G/CM -0.05 0.55 PEF MWD040 B/E 1.34 5.28 28137.4 2.35023 0.0957616 2.93512 First Reading For Entire File .......... 9134 Last Reading For Entire File ........... 9932 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 1418 1418 1418 1418 9134 9149.5 9149.5 9149.5 9842.5 9858 9858 9858 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 9843.0 9843 0 9843 0 9858 5 9858 5 9858 5 9880 0 9887 5 9887 5 9887 5 9887 5 9887 5 9932 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10140.5 10140 5 10140 5 10156 0 10156 0 10156 0 10177 5 10185 0 10185 0 10185 0 10185 0 10185 0 10230.0 16-SEP-01 Insite 4.05.5 66.16 Memory 10230.0 88.8 90.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02153HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB02153HAGR4 CTN COMP THERMAL NEUTRON PB02155NL4 SLD STABILIZED LITHO DEN PB02155NL4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.125 BOREHOLE CONDITIONS MUD TYPE: QUIKDRL-N MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 40.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3): 10.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.500 MUD AT MAX CIRCULATING TERMPERATURE: 1.709 MUD FILTRATE AT MT: 3.900 MUD CAKE AT MT: 2.700 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type.. Service Order Units FT MWD050 FT/H MWD050 API MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 HR MWD050 PU-S MWD050 CP30 MWD050 CP30 MWD050 G/CM MWD050 G/CM MWD050 B/E Size Nsam Rep Code Offset Channel 4 1 68 0 1 4 1 68 4 2 4 1 68 8 3 4 1 68 12 4 4 1 68 16 5 4 1 68 20 6 4 1 68 24 7 4 1 68 28 8 4 1 68 32 9 4 1 68 36 10 4 1 68 40 11 4 1 68 44 12 4 1 68 48 13 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF 64.0 179.6 63.0 64.0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO Service Unit FT MWD050 FT/H MWD050 API MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 HR MWD050 PU-S MWD050 CP30 MWD050 CP30 MWD050 G/CM MWD050 G/CM Min 9843 0 86 18 99 2 58 2 78 2 85 3 O2 0 49 20 94 431 51 24701.8 2.22 0.01 Max 10230 226.66 81 98 14 77 15 78 17 14 14 83 16 77 30 54 742 78 31399.4 2.66 0.31 Mean Nsam 10036.5 775 77.6574 596 31.2594 596 8.88743 596 9.20117 596 10.5207 596 10.4291 596 3.2132 596 24.1309 596 617.655 596 29056.2 596 2.36361 596 0.101711 596 First Reading 9843 9932.5 9880 9887.5 9887.5 9887.5 9887.5 9887.5 9843 9843 9843 9858.5 9858.5 Last Reading 10230 10230 10177.5 10185 10185 10185 10185 10185 10140.5 10140.5 10140.5 10156 10156 PEF MWD050 B/E 1.99 3.94 First Reading For Entire File .......... 9843 Last Reading For Entire File ........... 10230 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 2.90703 596 9858.5 10156 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/09/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/09/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File