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Home My WebLink About193-110 RECEIVED • STATE OF ALASKA • DEC 3 12012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO6OGCC la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class 20AAC 25.105 20AAC 25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 12/7/2012. • 193 -110 I / 3/Z - 288 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 9/5/1993' 50- 029 - 22046 - 01-00' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 9/13/1993 PBU Z -07A' . 974' FNL, 1287' FWL, Sec 19, T11N, R12E, UM 8. KB MSL b ft above MSL): 15. Field /Pool Pool(s) of Productive Horizon: KB ( ft 88'62 ( ) 2609' FSL, 811' FEL, Sec 14, T11N, R11 E, UM GL (ft above MSL): 54.02' Prudhoe Bay / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD) 2766' FSL, 1122' FEL, Sec 14, T11N, R11 E, UM '12703' 8859' 4b. Location of Well (State Base Plane Coordinates, NAD : 10. Total Depth (MD +TVD) 16. Property Designation: , Surface: - x- 599010 y- 5959100 Zone- ASP4 ' 13174' 9118' ADL 028262 & 028245 TPI: x- 591587 y - 5962590 Zone ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x - 591274 Y 5962742 Zone ASP4 None' 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (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: DLL / BHCS / GR / SP, CNL / GR ' 10286' 7511' 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" Insulated Conductor Surface 110' Surface 110' 30' 280 cu ft Arcticset (Approx.) 13 -3/8" 68# L -80 Surface 2740' Surface 2645' 17 -1/2" 3806 cu ft Permfrost 9 -5/8" 47# NT80 -S Surface •10286' Surface 7511' 12 -1/4" 365 cu ft Class "G" 7" 29# L -80 10133' :1 3174' 7409' 9118' 8 -1/2" 209 cu ft Class "G" 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SET ET (MD +TVD of Top & Bottom; Perforation Size and Number): S IZE (MD) PACKER SET ( MD / TVD) 4 12.6 #, 13Cr80 12069' 12009' / 8487' %&W MAR 18 2013 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 12703' Set Whipstock 12720' 20 Bbls Class 'G' 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 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 ►_i 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 RBDMS JAN 0 21013 0 Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE S mit Original Only 29. GEOLOGIC MARKERS (List all formations alaarkers encounter 30. FORMATION TESTS NAME MIND 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 12441' 8720' None Shublik 12495' 8749' Eileen 12696' 8855' Sadierochit / Zone 4 12757' 8888' Zone 3 13057' 9053' 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- 85 Email: David.Johhston2 @bp.com Printed N D rilling Technologt Phone 564 Date: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 • • Z -07A, Well History (Pre Rig Sidetrack) Date Summary 08/26/12 INITIAL T /I /O = 600/1650/200. RIGGED UP ELINE TOOLS W/ WELLTEC STROKER /MILL. MILLED XN NIPPLE @ 12056' MD. CURRENTLY PULLING OUT OF HOLE FOR L &K & SET WHIPSTOCK. 08/27/12 POOH WITH WELLTEC MILLING TOOL (XN MILLED TO 3.80 "). RIH WITH BAKER 4 -1/2" x 7" WHIPSTOCK - COULD NOT GET THROUGH GLM#4 @ 3418' POOH. DRIFTED WITH HEAD /ERS /SWIVEU4 X WEIGHT BARS THROUGH GLM#4 AT 40 FPM NO PROBLEMS. SET BAKER 4 -1/2" x 7" WHIPSTOCK - TOP OF WHIPST AT: 12703' (30DEG LOHS1 TWO PIP TAGS IN WHIPSTOCK @ 12713' 12715.5' (OAL = 16.63' / MAX O.D. = 3.625 "). CORRELATED TO ATLAS 1,Jive WIRELINE SERVICES GR /CCL DATED 26 -SEPT -1993. WELL LEFT SI ON DEPARTURE - NOTIFIED PAD OP OF WELL STATUS. FINAL T /I /O = 130 / 1650 / 725. 08/27/12 T /I /O = 499/1640/220 Temp = S/I (Assist E -Line with TBG load). Pumped 3 bbls Neat Methanol followed by 290 bbls 110* 1% KCL down TBG to load. Pumnped 40 bbls Diesel down TBG for freeze protect. E- Line in controle of well notified pad op upon departure. FWHP = 456/1724/789 S/W /SSV /M = E -Line. IA /OA = OTG. 08/31/12 T /I /O = 170/1530/150. Temp = SI. T & IA FL (Coil Request). AL SI @ casing valve, ALP = 1660 psi. T FL near surface & IA FL @ 108' (6 bbls). SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 23:55. 09/06/12 CTU # 9 w / 1.75" ct : Job objective Cement P &A thru whipstock RIH w / 2.5" BDN / Pumped 20 bbls of 15.8# cement Sgeezed 12 bbls below whipstock.Held 2000 psi for 30 mins cleaned out to whipstock tray. POOH washing jewelry. Freeze protected from 2500' w/ 50/50 methanol. 2 HRS NPT. 09/14/12 T /I /0= 100/1615/157 Temp= S!_MIT_ -T to 2400 psi FAILED (CTD) Pumped 2.3 bbls 40* diesel down TBG to reach 2400 psi for MIT TBG 1st test lost 588 psi in 5 min RE -psi w /.7 bbl IAP didnt rise threw out job 2nd 1 " test lost 601 psi in 5 min leak of rate 5.8 gallons per min. RE -psi w/1.1 bbls 3rd test 902 psi in 10 min leak '" of rate 9.2 gallons per min. RE -•si w /.9 bbl 4th test lost 102. . i a • - - • - • o • - V? 0 min. Attempt LLR LLR to small for big pump Bleed TP down bleed back aprox.1 bbl Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp's= 144/1587/159. 09/24/12 T /I /0 = 0/ 1650/250 Conduct PJSM. Barriers= SV & SSV. Verified by applying 300 & 3500 psi against SV through tree cap. LTT Passed and Recorded as Tested valve for CTD; R/U Lubricator with setting tool and 4- 1/16" CIW "H" TWC #286 to tree cap flange and test to 300 and 3500 psi for 5 min. LTT Passed; Open barriers and set TWC using Gray Lubricator and 1 -1' ext, tagged at 108 "; S/I Barriers and C/0 setting tool for pulling tool; Test against SV to 300 and 3500 psi for 5 min. LTT passed; Open barriers and bleed tree to 0 psi; Torque tree to API specs using truck and equipment #32 -024; No Movement on any studs; Pull TWC, S/I barriers, RDMO, install tree cap and test to 500 psi for 5 min. LTT Passed. 09/26/12 T /I /0 = 0 +/1680/160. Temp = SI. Bleed WHPs to 0 psi (pre CTD). AL SI @ casing valve, ALP = 1650 psi. IA FL @ 550'. Bled IAP to 290 psi in 3 hrs (all gas). Monitored for 30 min. IAP increased 70 psi. Job incomplete. Final WHPs = 0 +/360/160. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 0430. 09/29/12 T /I /0 = 110/1610/180. Temp = SI. Bleed WHPs to 0 psi (pre CTD). AL SI @ casing valve, ALP = 0 psi. T & IA FL near surface. Bled IAP to 340 psi in 1 hr through Z -06 production. Held open bleed for 1 hr. Bled IAP to 220 psi in 3 hrs through slop tank (all gas). During bleed TP decreased 20 psi. Monitored for 30 min. IAP increased 10 psi. Job incomplete. Final WHPs = 90/230/180. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 0400. Page 1 of 3 • Z -07A, Well History (Pre Rig Sidetrack) Date Summary 10/05/12 T /I /O = 50/450/120. Temp =SI. Bleed WHPs to 0 psi, get T & IA FLs(CTD Prep). No AL, WH, or FL. TBG, IA, & OA FLs are near surface. Bled TP from 50 psi to 0 psi in 20 min, gas. Monitor TP for duration of job. Bled IAP from 450 psi to 220 psi in 20 min, fluid to surface. Bled OAP from 120 psi to 80 psi in 30 min, fluid to surface. Swap to IA, IAP =220 psi. Bled IAP from 220 psi to 200 psi, fluid /gas, in 2 1/2 hrs. During IA bleed OAP increased 70 psi to 150 psi. Re -bled OAP to 70 psi in 2 min, fluid to surface. Monitor for 30 min. TP unchanged, IAP increased 20 psi, OAP increased 80 psi. Job incomplete. Final WHPs = 0/220/150. SV,WV,SSV= Closed. MV =Open. IA,OA =OTG. NOVP. (0430 hrs). 11/25/12 T/I/0 = 10/440/190. Temp = SI. MIT -T to 2400 psi Failed, LLR if fails. (CTD prep). No wellhouse, flowline or AL. Tubing FL @ —70' (1 bbl). Pumped a volume of 3.2 bbls diesel to pressure up tubing from 14 psi to 2400 psi. Tubing lost 700 psi during the 1st 15 minutes. Moved on to LLR -T. Pumped a volume of 1.24 diesel establishing a 0.04 bpm (1.74 gpm) liquid leak rate @ 2400 psi. Bled tubing pressure to 5 psi. Job complete. Final WHPs = 5/420/190. SV, WV, SSV = C. MV = O. IA & OA = OTG. NOVP. 03:45. 12/01/12 T/I/0 = 12/460/160. Temp = SI. Bleed WHPs to 0 psi. (CTD Prep). No wellhouse, flowline or AL line. Tubing FL @ surface. IA FL @ surface. OA FL near surface. Tubing pressure increased —7 psi, IAP increased 40 psi & OAP decreased 30 psi since 11- 25 -12. Bled tubing pressure from 12 psi to 0+ psi in 10 min. Bled IAP from 460 psi to 190 psi in 3 hrs (gas /fluid mix, —3 bbls). Bled OAP from 160 psi to 140 psi in 45 min (FTS, gas /fluid mix). During IA bleed tubing went on Vac & OAP increased 10 psi. Monitored for 30 min. IAP increased 10 psi. Job incomplete. Final WHPs = Vac/200 /150. SV, WV = C. SSV, MV = O. IA & OA = OTG. NOVP. 04:00. 12/01/12 T/I/0 = vac /200/150. Temp = SI. Bleed WHPs to 0 psi (CTD prep). No wellhouse, flowline or AL line. IA FL near surface, OA FL near surface. Bled IAP from 200 psi to 26 psi in 7 hrs (gas /fluid mix. -9 bbls). Bled OAP from 150 psi to 140 psi in 30 min (FTS, gas /fluid mix). Monitored for 30 min. IAP increased 20 psi. Job incomplete. Final WHPs = Vac/46/140. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1630. 12/02/12 LTSI >6 MTHS. 23 1/2 TURNS. LTT PASS. 12/02/12 T/I/0 = Vac/63/140. Temp = SI. Bleed WHPs to 0 psi. (CTD Prep). No wellhouse, flowline or AL line. IA FL near surface. OA FL near surface. IAP increased 17 psi & OAP unchanged since day shift ( -6 1/2 hrs). Bled IAP from 63 psi to 8 psi in 4 hrs 15 min. Monitored for 30 min. IAP increased 13 psi. Job incomplete. Final WHPs = Vac /19/140. SV, WV = C. SSV, MV = O. IA & OA = OTG. NOVP. 04:00. 12/02/12 T/I/0 = Vac/23/140. Temp = SI. Bleed WHPs to 0 psi (CTD Prep). No wellhouse, flowline or AL line. IA FL near surface, OA FL near surface. IAP increased 4 psi, OAP unchanged since night shift ( -5 1/2 hrs). Bled IAP from 23 psi to 0 psi in 4 hrs (gas). Bled OAP from 140 psi to 41 psi in 3 hrs (gas /fluid -1 bbls). Monitored for 30 min. IAP increased 6 psi. Job incomplete. Final WHPs = Vac/6 /41. SV, WV = C. SSV, MV = C. IA, OA = OTG. NOVP. 1630. 12/03/12 /1 /0 = 2/8/63. Temp = SI. Bleed WHPs to 0 psi. (CTD Prep). No wellhouse, flowline or AL line. Tubing FL near surface. IA FL near surface. OA FL near surface. Tubing pressure increased 2 psi, IAP increased 2 psi & OAP increased 22 psi since day shift ( -5.5 hrs). Bled tubing pressure from 2 psi to 0 psi in < 1 minute. Bled OAP from 63 psi to 10 psi in 3 hrs. Bled IAP & OAP in tandem from 8/10 psi to 2 psi in 1.5 hrs. Monitored for 30 minutes. IAP increased 1 psi & OAP increased 6 psi. Job incomplete. Final WHPs = 0/3/8. SV, WV = C. SSV, MV = O. IA & OA = OTG. NOVP. 04:00. Page 2 of 3 • • Z -07A, Well History (Pre Rig Sidetrack) Date Summary 12/03/12 T /I /O = 0/7/16. Temp = SI. Bleed WHPs to 0 psi. (CTD Prep). No wellhouse, flowline or AL line. Tubing FL near surface. IA FL near surface, OA FL near surface. IAP increased 4 psi, OAP increased 8 psi since night shift ( -4.5 hrs.). Bled IAP & OAP in tandem from 7/16 psi to 0/0 psi in 7 hrs.(gas). Monitored 30 min. IAP increased 1 psi, OAP increased 1 psi. Final WHPs = 0/1/1. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1600. 12/04/12 T /I /O =0/0/0 Conducted PJSM. Barriers = SSV & Master (WSL approved) Start barriers list. PT'd thru tree cap against top side of Master 500 psi. /5 min. Pass. Opened master, shut SSV. PT'd against top side of SSV 500 psi. /5 min. Pass. With both the SSV & Master shut, evacuated fluid from tree. Removed Tapped blind flange on comp. side and installed untapped blind flange. Torqued all nuts to API specs. With same barriers in place, removed tree cap & attached lubricator. PT'd against top of SSV 250 /Iow..3500 /high..5 min. each..pass. Set 4" CIW "H" TWC #289 THRU TREE using 1 -1' ext. Tagged @ 109" Removed lubricator, installed tree cap. Shell tested tree thru tree cap against TWC 250 /Iow..3500 /high..5000 /high..5 min. each..PASS. Page 3 of 3 • • i , Common Well Name: Z -07 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/5/2012 End Date: 12/12/2012 X3-0121J-C:DRILL (2,527,095.10 ) Project: Prudhoe Bay Site: PB Z Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/16/1990 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: Z -07A ©88.62ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/5/2012 21:00 - 21:30 0.50 MOB P PRE BEGIN RON EVENT WITH NORDIC 2 CTD RIG - AT 21:00 HRS ON 12/05/12. 21:30 - 22:00 0.50 MOB P PRE PJSM FOR MOVING OFF WELL W -02. 22:00 - 22:45 0.75 MOB P PRE BACK OFF W -02 AND SPOT ON W PAD. 22:45 - 00:00 1.25 MOB P ■- PRE CLEAR RIG MATS FROM AROUND WELL. COMPLETE WWT PERMIT WITH PAD OPERATOR AND W -02 12/6/2012 00:00 - 02:30 2.50 MOB P PRE MOVE RIG OFF OF W PAD, DOWN ACCESS ROAD, ON TO SPINE ROAD TO Z PAD ACCESS ROAD. 02:30 - 04:00 1.50 MOB P PRE MOVE TO Z PAD FROM ACCESS ROAD. 04:00 - 10:00 6.00 MOB P - PRE SPOT RIG MATS AROUND WELL, PREP TO MOVE TIG OVER Z PAD, 10:00 - 12:00 2.00 MOB P - PRE PJSM, THEN PULL OVER WELL. ACCEPT RIG ON Z -07B AT 10:00. 12:00 - 13:00 1.00 RIGU P PRE PJSM THEN PICK UP 2 -3/8" E -COIL. 13:00 - 14:00 1.00 BOPSUR P PRE LEAK TIGHT TEST 14:00 - 16:00 2.00 BOPSUR P PRE REMOVE TREE CAP NU BOPS 16:00 - 17:00 1.00 BOPSUR P PRE FILL BOPE FOR SHELL TEST 17:00 - 22:00 5.00 BOPSUR P PRE SHFI I TFST BOPE TO 250/3500 PSI. TEST BOPS. TEST CHOKE VALVES, CHOKE AND KILL HCR, INSIDE MANUAL VALVES ON CHOKE AND KILL LINE, BOP RAMS AND ANNULAR �( PREVENTER IN' TEST 2 TIW VALVES. TEST ANNULAR AND PIPE RAMS WITH 2 -3/8" TEST JOINT. TEST VBRS WITH 2 -3/8" AND 3 -1/2" TEST JOINTS. EACH TEST TO 250/3500 PSI FOR 5 CHARTED MIN. ACCUMULATOR DRAWDOWN TEST TEST WITNESSED BY TOOLPUSHER, NORDIC SUPT, WSL, AND AOGCC CHUCK SCHIEVE - SEE ATTACHED CHARTS AND TEST REPORT 22:00 - 23:15 1.25 BOPSUR P -_ PRE RIG UP INJECTOR AND STUFFING BOX, INSTALL NEW PACK -OFF AND BRASS. 23:15 00:00 0.75 BOPSUR P ■- PRE S FOR PULLING COIL ACROSS. REMOVE SHIPPING BAR, PULL TEST GRAPPLE. PULL COIL ACROSS STAB INTO INJECTOR 12/7/2012 14:30 - 15:30 1.00 STWHIP P ._ WEXIT PICKUP BHA #1 - WINDOW MILL WITH 2 JTS PH6, 3" COILTRAK. 00:00 - 01:30 1.50 BOPSUR P -_ PRE FILL COIL WITH 10 BBLS MEOH FOLLOWED BY FRESH WATER AT 1 BPM. 01:30 - 02:15 0.75 BOPSUR P -_ PRE REVERSE CIRCULATE TO PREP FOR INNER REEL VALVE TEST. 02:15 - 02:45 0.50 BOPSUR P PRE CLOSE INNER REEL VALVE AND PRESSURE TEST INNER REEL VALVE AND PACK -OFF TO 250/3500 PSI. GOOD TEST. Printed 12/17/2012 2:05:12PM W Common Well Name: Z -07 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/5/2012 End Date: 12/12/2012 X3- 0121J- C:DRILL (2,527,095.10 ) Project: Prudhoe Bay Site: PB Z Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/16/1990 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: Z -07A @88.62ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:45 - 04:45 2.00 BOPSUR P PRE PUMP SLACK BACK TEST E -LINE INSTALL CUT 3' OF COIL INSTALL COIL CONNECTOR, PULL TEST TO 38K HEAD UP BHI. TEST E -LINE 04:45 - 05:15 0.50 BOPSUR P PRE H2S /RIG EVAC DRILL. ALL PERSONNEL MUSTERED, REVIEWED PROCEDURES AND HELD AAR. 05:15 - 06:00 0.75 BOPSUR P PRE TEST BAKER CHECKS TO 250/3500 PSI. TEST CONNECTOR TO 250/3500 PSI. 06:00 - 09:00 3.00 BOPSUR P PRE LOAD BIT MOTOR AND MILLS TO RIG FLOOR. CONDUCT RIG EVAC DRILL WITH AAR. PREP TO PULL TWC. 09:00 - 10:00 1.00 BOPSUR P PRE LIFT LUBRICATOR TO RIG FLOOR. MAKE UP 5 FT EXTENSION BARS AND GET ON WELL. 10:00 - 10:30 0.50 BOPSUR P PRE PRESSURE TEST LUBRICATOR AGAINST CLOSED SWAB AND SSV. 10:30 - 11:25 0.92 BOPSUR P PRE OPEN SWAB, SSV AND MASTER VALVE. PULL TWC. WHP = 25 PSI. RETRACT SETTING TOOL, CLOSE MASTER, SWAB AND SSV TO RE- ESTABLISH BARRIERS. OFFLOAD LUBRICATOR AND PULLING TOOLS. 11:25 - 13:00 1.58 BOPSUR P PRE OPEN WELL UP AND MONITOR. BLOW OUT STACK TO TIGER TANK. PJSM FOR PUMPING SLACK FORWARDS AND PICKING UP BHA. 13:00 - 14:30 1.50 BOPSUR P PRE GET ON WELL, PUMP SLACK FORWARDS. CABLE ISN'T HEARD MOVING. USE FRESH WATER AND PUMP 1 REEL VOLUME. 15:30 - 16:30 1.00 STWHIP P WEXIT PRESSURE TEST QTS THEN RIH. PUMP 0.45 BPM 9 PPG BRINE THROUGH OPEN EDC. �� TAKE RETURNS TO TIGER TANK. 16:30 - 18:30 2.00 STWHIP P WEXIT RIH. LOG TIE -IN AT SAG RIVER, ( -10)' CORRECTION. TAG 12,711'. 3Vair 1 8:30 - 20 1.50 STWHIP P WEXIT START MILLING WINDOW FROM TAG AT 12,709'. START 9.0 PPG MUD DOWN COIL, D1€j UNABLE TO MILL UNTIL MUD AROUND THE BACKSIDE (CHROME TUBING AND NO LUBES �uJ IN KCL). P -(p 20:00 - 00:00 4.00 STWHIP P WEXIT 2950 PSI FREESPIN AT 2.6 BPM IN/OUT. MILL 1 FPH WITH 2.6K# DHWOB MILL TO 12713.8' Printed 12/17/2012 2:05:12PM Common Well Name: Z -07 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/5/2012 End Date: 12/12/2012 X3 0121 J C:DRILL (2,527,095.10 ) Project: Prudhoe Bay Site: PB Z Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 5/16/1990 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: Z -07A @88.62ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/8/2012 00:00 - 00:30 0.50 STWHIP P WEXIT PICK UP FOR FLOW CHECK, 4 BBLS GAIN IN PVT (344 TO 348 BBLS). FLOW CHECK 10 MIN, NO FLOW. CHECK PITS AND SENSORS, MANUAL STRAP SHOWS SAME GAIN. COME UP WITH PUMP, IN DENSITY 8.97 PPG, OUT DENSITY 8.87 PPG. OBTAIN SPRS 12703' PUMP #1: 0.5 BPM = 1410 PSI, 1.0 BPM = 1644 PSI, 2.6 BPM = 2860 PSI PUMP #2: 0.5 BPM = 1400 PSI, 1.0 BPM = 1622 PSI, 2.6 BPM = 2830 PSI 00:30 - 04:00 3.50 STWHIP P WEXIT GO MAKE TO MILLING FROM 12,713.8', TIME MIL 1 FPH, 120 PSI MOTOR WORK, 0.5 TO 2k# DHWOH WITH 2.64 BPM IN/OUT. 04:00 - 06:30 2.50 STWHIP P WEXIT MILL WINDOW FROM 12717'. SAMPLE FROM 12715 SHOWED 15% FORMATION. PUMP 2.64 BPM IN/OUT AT 2960 PSI, 1.0K# DHWOB. 06:30 - 07:00 0.50 STWHIP P WEXIT CONTINUE MILLING RATHOLE DOWN TO 12727 FT. PVT = 350 BBLS. 07:00 - 08:50 1.83 STWHIP P WEXIT REAM WINDOW 3 TIMES UP DOWN. NO MOTOR WORK OR SETDOWNS SEEN ON ANY OF THE PASSES. 08:50 - 09:30 0.67 STWHIP P WEXIT PICK UP ABOVE WINDOW AND SHUT OFF PUMP. DRY DRIFT THROUGH WINDOW. TAG TD OF RATHOLE AT 12726 FT. CLEAN PASS THROUGH WINDOW. PICK UP ABOVE WINDOW AND SHUT OFF PUMP. CAN'T OPEN EDC HERE, PRESSURE DIFFERENCE IS ABOUT 150 PSI. PULL UP ANOTHER 100 FT AND SHUT OFF PUMP. BOTTOMS UP SAMPLE IS 50% CEMENT, 35% EILEEN SAND, 5% PIPE SCALE, 5% SHALE. 09:30 - 12:00 2.50 STWHIP P WEXIT FLOW CHECK ABOVE WINDOW IS GOOD. POOH, PUMP 2.5 BPM THROUGH MOTOR, DIFFERENTIAL ACROSS TOOL IS 125 PSI AFTER 10 MIN, STILL CAN'T OPEN EDC (MAX IS 100 PSI). STOP AT 10000 FT AND OPEN EDC. CONTINUE POOH PUMP 3.4 BPM. 12:00 - 12:45 0.75 STWHIP P WEXIT PJSM WHILE POOH, NEAR SURFACE. TRIP SHEET IS EVEN TO THIS POINT. STOP AT 500 FT AND FLOWCHECK. FLOWCHECK IS GOOD. 12:45 - 13:30 0.75 STWHIP P WEXIT PULL REMAINING WAY OUT OF HOLE. TAG STRIPPER AND UD BHA. MILL IS 3.77 NO -GO, REAMER IS 3.78 NO -GO. 13:30 - 13:50 0.33 STWHIP P WEXIT CHECK TREE BOLT TORQUE. ABLE TO SLIGHTLY TIGHTEN A FEW BOLTS. 13:50 - 14:30 0.67 DRILL P PROD1 PICK UP BHA #2, BUILD ASSEMBLY WITH 2.5 DEG AKO AND 3" COILTRAK. BHA OAL = 67.58 FT. 14:30 - 16:45 2.25 DRILL P PROD1 PRESSURE TEST QTS. RIH, PUMP 0.55 BPM / 1100 PSI THROUGH OPEN EDC. 16:45 - 17:10 0.42 DRILL P PROD1 LOG TIE -IN AT SAG RIVER AT 12,450' WITH ( -13)' CORRECTION Printed 12/17/2012 2:05:12PM TREE 4-1/16' Z 07A SA. NOTES: *** ORIG WELLBORE (Z-07) NOT =- aw 0 - WB_LI-FAD = FMC ACTUATOR= BAKER C SHOWN BELOW MILLOUT WINDOW *** INIMAL KB ELE 91 81 I ***4-112" CHROME MG*** BE agv = 57.56' KOP = 1600' 1 2102' —i 4-112' OTIS SSSV NP, D = 3 813' Max Angle = 59° @ 11377' 0 [ Datum MD ..= 12762' Datum - 11/D= 8800' SS GAS LFT MAICRELS 13-3/8" CSG, 6811, L-80, ID = 12.415' 1-1 2740' N ST MD LIVD DEV TYPE VLV LATCH FORT DATE 4 3418 3114 50 MERUl DMY RK 0 02/12/12 3 7198 5491 53 MERLA DMY FE 0 02/12/12 Minimum ID = 3.80" @12056' 2 9924 1 7271 49 tVERLA DMY FE 0 09/19/93 1 0003417344 49 MERLA DMY IN 0 02/12/12 4-112" MILLED SINN NIPPLE ) --1 10133' H 9-5/8" BKR TIEBACK SLV, D = 7.50" 0 r 10141' 1-19-5/8" X 7" BKR LIWw1 EIGR, ID= 6_187 1 I 9-5/8" MLLOUT WINDOW (Z-07A) 10286' - 10336' 9-5/8" CSG, 47#, NT-80S BUTT, 10= 8.681' H —10286 j--- 11951' H4-1/2" FKR SWS UP, 0= 3.813 . 1 II Erl 12009' --- 17" X 4-1/2' BKR S-3 PKR, D = 3.875" 1 cl I 12039' —14-112" PKR SINS X NIP, 0= 3.813' 1 • 12056' —14-112" P(R SVVN XN NP, MILLET) TO 3.80" (08/27/12) 4-1/2" TBG, 12.6# 13 CR-NSCT, ---3 12067' .0152 bpf, El= 3.958' 4-1/2" X 7" BKR WAPSTOCK (08/27/12) —1 12703' \ —1 12069' —14-1/2" WLEG, ID = 3.958' 1 12078' H a A4D LOGGED ON XX/XX/XX? FEFFORATION SUMMARY REF LOG: GR/CCL ON 09/26193 III-1 12640' HT MARKER JOINT ANGLE AT TOP PERF: 57 @ 12766' Note. Refer to Production Df3 for historical pert data rtr, SIZE SPF INTHWAL Opn/Sqz SFIOT SQZ 2-7/8" 6 12766 - 12786 S 10/26/09 09/06/12 e ‘41641: 06.% 11 6. 3-3/8" 6 12766 - 12806' S 10/14/93 09/06/12 6 164111 ‘ 1 1 ) ' t .11. 2-7/8' 6 12805- 12825 S 10/26109 09/06/12 10 4P i II 4 lk % 2-7/8" 6 12830 - 12850 S 10/10/09 09/06/12 6 .04 3-3/8" 6 12830 - 12852' S 10/19/94 09106/12 ( 164 k 111 4 1 4 11 4 11 1/4 11111 3-3/8" 6 12856 - 12866' S 04/04/95 09/06/12 10 2-7/8" 6 12860 - 12870 S 10/10/09 09/06/12 t 1 I' I P 4 41 41 1 ‘ 111% , 41111 4 3-3/8" 6 12866 - 12884' S 04/01/95 09/06/12 1, 161 1 41 % * tilli . 1 'V 111.1 1 P I ei eV. 2-7/8" 6 12874 - 12884 S 10/10/09 09/06/12 e .6. . . . 411 . 1 0 , 1111 . 1 4 , , 2-7/8" 6 12890 - 12904 S 10/10/09 09/06/12 4,4,4/P41•4 3-3/8" 4 12904 - 12924' S 09/27/93 09/06/12 6. l ite 111 I t 3-3/8' 4 12930 - 12950' S 09/27/93 09/06/12 %IP 4, -7? --I FISH- UNDERREAM BLADE (6/05/94) 1 — %Flo • 3-3/8" 4 12980 - 13000' S 10/08/93 09/06/12 6 .0ite dilti 3-3/8" 4 13004 - 13016' S 10/08/93 09/06/12 PBTD 13133' orVIIIA17 V. gr I e 4 PI e II I IF , a al it At illt.t1 Ot 7" LNR 29#, L-80 NSCC, 0371 BPF, 0 = 6.184" H 13174' DATE REV BY ' COMMENTS DATE 1 REV BY 03MAENTS PRIAHOE BAY UNIT 06113190 ' AIM 2 ORIGINAL COMPLETION 02/16/12 LEC/JIVID C/0 (02/12/12) WELL Z-07A 09/20193 13-14 RIG SIDETRACK (Z-07A) 08120112 RIVIAID TREE CIO (08/14/12) PERMIT Nn: 1931100 1 06/19/05 [RS/PJC CORRECTION KB 08/29/12 JCMJIMEI 1VILLEDXN NF'& SET WS (08/27/12) API Nu. 50-029-22046-01 1 10/14/09 MV/PJC ADPERFS (10/10/09) 11/07/12 PJC RIG PREP (DRAWING UPDATE) SEC 19, T11N, R12E, 974' FNL & 1287' FVI/1_ 1 10/15/09 PJC DRAWING CORRECTIONS 1 10/27/09 MV/SV RE/A DPERF BP Exploration (Alaska) 1 - • • ATA �G r ' Fr' 5 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader 3 BP Exploration (Alaska), Inc. "1 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z -07A Sundry Number: 312 -288 t .. 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, /q9 ix_vot i e.,& Cathy ". Foerster Chair DATED this 3L day of July, 2012. Encl. r4 ,5k .07 STATE OF ALASKA ALA KA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL „JUL 2 6 2012 20 AAC 25.280 1. Type of Request: A06 GC ❑ 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. 193 - 110 - 3. Address: 6. API Number: ®D eve l opment ❑Exp ❑ Service ❑ Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22046 -01 -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 Z -07A Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028262 & 028245 ' 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): 13174' . 9118' • _ 13133' 9096' None Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2740' 13 -3/8" 2740' 2645' 4930 2270 Intermediate 10286' 9 -5/8" _ 10286' 7511' 6870 4760 Production Liner 3041' 7" 10133' - 13174' 7410' - 9118' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12766' - 13016' 8893' - 9031' 4-1/2", 12.6# 13Cr80 12069' Packers and SSSV Type: 7" x 4-1/2" Baker S -3 Permanent Packer Packers and SSSV 12009' / 8487' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development El Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 1, 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 John lip ,, ,. Title Engineering Team Leader Signature L7 Phone 564-4711 Date ,' � 7 Prepared By Name /Number Joe Lastufka, 564 -4091 - Commission Use Only 4oval Condit ions of Notify Commission so that a representative may witness Z� ^ � 'LTV " Sundry Number: J L ❑ Plug Integrity WBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: - 3� p4-�- OOP j. Subsequent Form Required: f O.-16-7 Approved By:� -4-6fil-4.----- APPROVED BY °7 COMMISSIONER THE COMMISSION Date 7- 3/ - Z Y Form 10 -403 Revised 01 010 ,L R I G I ] n F6' / "— 7s0 �'� f v H LDMS AUG 012012 • • To: Alaska Oil & Gas Conservation Commission From: David E. Johnston by CTD Engineer Date: July 25, 2012 Re: Z -07A Sundry Approval Sundry approval is requested to plug the Z -07A perforations as part of drilling the Z -07 coiled tubing sidetrack. History of Z -07. Z -07 was drilled in 1990 to access upper zone 4 reserves. The well underperformed and was rotary sidetracked in 1993, and subsequently hydraulically fractured twice -- both jobs screened out prematurely, so fracs are not believed to be well " developed. The new well was also very poor. Perfs were added over the years, and an acid stim done, all without significant benefit. The well has been mostly SI since 2006, with the last production test in April 2011. The well is classified as an operable well. Reason for sidetrack. Z -07A is no longer a competitive producer due to a high water cut, and there are no remaining wellwork options. The proposed sidetrack will provide injection support to Zone 4, after pre - production. Proposed plan for Z -07 is to drill a through tubing sidetrack with the SLB /Nordic 2 Coiled Tubing Drilling rig on or around November 15 2012. The existing perforations will be isolated by down squeezing cement past the whipstock as well as the primary cement job for the liner. The sidetrack, Z -07B, will exit the existing 7" liner, kick off in and land in Z4. 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. cow �, (O en lair frla1 fr #/4 Ts r we/ I hal it f orer rO ."/ ct/` q g f((o,r.'/ro7 C( 0f -0 �P% / /hf 4 We � app �a a I /p� i PC/t�' To r°fce if fl ' i h �f Q Q�P _ tt pn OF T e f ool f / g/ / /y/'°" ' d ahA'�° ��Cpt car/. Vmolfr hi( /0ft Work: • (scheduled to begin Pre -Rig August 1, 2012 9 ( g g 2012) 1. F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi 2. W Cycle LDS; PPPOT- T to 5,000 psi 3. S Dummy WS Drift to deviation or 12,750'MD (63° Inc) 4. E Mill XN nipple at 12,056' to 3.80" 5. E Set 4 -1/2" x 7" TT Whipstock at -12,735' MD 6. C Cement TT whipstock in place and squeeze perfs 7. F Test cement to 2400 psi for 30 min MIT P ZQ� 8. V PT MV, SV, WV 9. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 't 10. 0 Remove wellhouse, level padA A Rig Work: (scheduled to begin November 25 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. T Mill at 12,735' and 10' of rathole. Swap the well to PowerVis. 3. Drill Build: 4.125" OH, 365' (30 deg /100 planned) 4. Drill Lateral: 4.125" OH, 1,711' (15 deg /100 planned) with resistivity 5. Run 3 -1/4" x 2 -7/8" liner leaving TOL at 12,047' MD. 6. Pump primary cement leaving TOC at 12,535' MD, 31 bbls of 15.8 ppg liner cmt planned V 7. Cleanout liner and run MCNL /GR /CCL log. 8. Test liner lap to 3,000 psi. 9. Perforate liner per asset instructions ( -800') 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 4. Test separator David E. Johnston CTD Engineer 564 -5985 CC: Well File Joe Lastufka TREE= 4- 1/16" CIW WELLHEAD = FMC • SAO NOTES: * ** ORIG W ELLBORE (Z -07) NOT ACTUATOR= OTIS Z -O T A SHOWN BELOW MILLOUT WINDOW * ** 4-1/2" KB. ELEV = 88 -62' BF. ELEV = 57.56' KOP= 1800' Max Angle = 59 @ 11377' Datum MD = 12762' F I 2102' I -14 -1/2" OTIS SSSV NIP, ID = 3.813" I Datum TVD = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 2739' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3418 3114 50 MERLA DOME RK 16 11/30/09 ID 3 7198 5491 53 MERLA DOME RK 16 11/30/09 2 9924 7271 49 MERLA DMY RK 0 09/19/93 Minimum ID = 3.725" @12056' 1 10034 7344 49 MERLA SO RK 22 11/30/09 4 -1/2" PARKER SWN NIPPLE 10133' I-I BAKER TIEBACK SLV, ID =7.50" I 10141' 1-19-5/8" X 7" BKR LTW w/ HGR, ID = 6.187 I I I PERFORATION SUMMARY 9 -5/8" MILLOUT WINDOW (Z -07A) 10286' - 10336' REF LOG: GR/CCL ON 09/26/93 - ANGLE AT TOP PERF: 57° @ 12766' • Note: Refer to Production DB for historical pert data �•• SIZE SPF INTERVAL Opn /Sqz DATE • ■ 2 -7/8" 6 12766 - 12786 0 10/26/09 • 3 -3/8" 6 12766 - 12806' 0 10/14/93 � • • 2 -7/8" 6 12805 - 12825 0 10/26/09 ► 2 -7/8" 6 12830 - 12850 0 10/10/09 • iii , 3 -3/8" 6 12830 - 12852' 0 10/19/94 ••••• ►� i . 3 -3/8" 6 12856 - 12866' 0 04/04/95 • • • • • • • • • ►•••••• 2 -7/8" 6 12860 - 12870 0 10/10/09 •••••• •• 3 -3/8" 6 12866 - 12884' 0 04/01/95 ••••••••••••• ■ 2 -7/8" 6 12874 - 12884 0 10/10/09 • • 11951' - I4 -1/2" PKR SWS NIP, ID = 3.813 2-7/8" 6 12890 - 12904 0 10/10/09 •�i�i�i�i�i�i�i • " X 4-1/2" BKR S -3 PKR, ID = 3.875" I 3 -3/8" 4 12904 - 12924' 0 09/27/93 • • • • • •• •• •• • 3 -3/8" 4 12930 - 12950' 0 09/27/93 •••••••• • •••• 3 -3/8" 4 12980 - 13000' 0 10/08/93 jjj•�•j•�•�•j�j ?: 12039' �4 1/2" PKR SWS NIP, ID = 3.813" I 3 -3/8" 4 13004 - 13016' 0 10/08/93 • .�•�•�•�• 12056' I- 4 -1/2" PKR SWN NIP, 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 12189' I ID = 3.725" I 12069' I--- I4 -1/2" WLEG, ID = 3.958" I 14-1/2" TBG, 12.6# 13 CR -NSCT, .0152 bpf, ID = 3.958" I 12067' , I 12078' I-I ELMD I Ili ,, ?? - FISH UNDERREAM illi BLADE (6/05/94) I PBTD H 13133' ,��;�� 17" LNR, 29 #, L -80 NSCC, .0371 BPF, ID = 6.184" H 13174' 4 ■ 4 ► DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/13/90 SJA ORIGINAL COMPLETION 10/15/09 PJC DRAWING CORRECTIONS WELL: Z -07A 09/20/93 RIG SIDETRACK (Z -07A) 10/27/09 MV /SV RE/ADPERF PERMIT No: '1931100 06/28/04 PWEJKAK GLV C/O 12/10/09 CJN/SV GLV C/O (11/30/09) API No: 50- 029 - 22046 -01 06/19/05 DRS /PJC CORRECTION KB SEC 19, T11 N, R12E, 4306' FSL & 3667' FEL 08/09/06 BSFJPJC GLV C/O 10/14/09 MV /PJC ADPERFS (10/10/09) BP Exploration (Alaska) TREE 4-1/16° (3W • WELLFEAD= FTC • Z -0 7 B SA NOTES: * *" ORIG W ELLBORE (Z -07) NOT ACTUATOR= OTIS SHOWN BELOW MILLOUT WINDOW * ** 4 -1/2" KB. B_EV = 88-62' Proposed CTD Sidetrack BF ELEV = 57.56' KOP= 1800' Max Angle = 59 @ 11377' Datum ND= 12762 O 2102' H4 OTIS SSSV NP, D = 3.813" Datum ND = 8800' SS GAS LIFT MANDRELS 13 -318" CSG, 684, L -80, D= 12.415" — 2739' ST I O ND DEV TYFE VLV LATCH PORT DATE 4 3418 3114 50 MERLA DOME RK 16 11/30/09 3 7198 5491 53 MERLA DOME RK 16 11/30/09 (Minimum ID = 3.725" i �7U 12056' 2 9924 7271 49 MERLA DMY RK 0 09/19/93 1 10034 7344 49 MERLA SO RK 22 11/30/09 4 -1/2" PARKER SWN NIPPLE L 10133' —I BAKER TIEBACK SLV , ID= 7.50" 10141' —19-5/8" X 7" BKR LTW w / FIGR, D = 6.187 I I I FORATION SUMMARY REF LOG: GR/CCL ON 09 /26/93 9-5/8" MLLOUT WINDOW (Z - 07A) 10286' - 10336' ANGLE AT TOP PEW: 57° @ 12766' Note: Refer to Production D8 for historical perf data ► SIZE SFF I I'TH71/AL Opn/Sqz DATE �•A 2 -7/8" 6 12766 - 12786 0 10/26/09 •� • 3-3/8" 6 12766- 12806' 0 10/14/93 •• 2 -7/8" 6 12805 - 12825 0 10/26/09 • • • • • • •••• 2 -7/8" 6 12830 - 12850 0 10/10/09 • •�•�• • • 3-3/8" 6 12830 - 12852' 0 10/19/94 •••••••• ••••• 3-3/8" 6 12856 - 12866' 0 04/04/95 • •••••••• ., 2-7/8" 6 12860 - 12870 0 10/10/09 ••••• •••••• •• ••• 3 -3/8" 6 12866 - 12884' 0 04/01 /95 •• •••• ■•••••• 2 -7/8" 6 12874 - 12884 0 10/10/09 ••••••••••••• ■ •••••••• 11951' I-14-1/2" PKRSWS = 3.813 2 -7/8" 6 12890 - 12904 0 10/10/09 • 3-3/8" 4 12904 - 12924' 0 09/27/93 •••••••••••••••• 3-3/8" 4 12930 - 12950' 0 09/27/93 ••••••••••••••••�■ ••••••••• 12009' - 7" X 4 Fit 112" BKR S 3 R D = 3.875" 3-3/8" 4 12980 - 13000' 0 10/08/93 ►•••••••••••••••• ••••••••4 3 3/8" 4 13004 - 13016' 0 10/08/93 ►•••••••••••••••• '4 12039' — 4-1/2" FKR SV1IS NIP, ID= 3.813" ••••••••• ••••••••4 ••••••••• 12056' — 4-1/7 PKR SWN NIP, ►•••••••••••••••• ' trilled pre-rig D = 3.80 ►•• • • • • •••••• •••• 9 -5/8" CSG, 47 #, L -80, D = 8.681" H 12189' F 12069' J D 4 -1/2' WLEG, = 3.958" - 3.7" deployment sleeve 12,047' MD 1 12078' I — I ELK) I I 4 -1/2" TBG, 12.6# 13 CR -NSCT, .0152 bpf, ID = 3.958' H 12067' TSGR 12,442' MD _�TOC 12,535' MD 12735' WS TO ALLOW KOP AT ]NC @ 12 ,75 0 -37deg 12,735' MD 3- 3/16" x 2 -7/8" xo (SCR) @ 13,210' MD TD - 14,811' MD ` ,,, � , � li 2 -7/8" 4.7# 13CR - 80 Ier PBTD 13133' * �� 44 14 ,; 77 — FISH- UNCERREAM 7" LNR, 29#, L -80 NSCC, .0371 BPF, D H = 6 -184" I 1 13174' 1, BLADE (6 /05/94) DATE REV BY I COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/13/90 SJA ORIGINAL COMPLETION 10/15/09 PJC DRAWING CORRECTIONS WELL: Z -07A 09/20/93 RIG SIDETRACK (Z -07A) 10/27/09 MV /SV REJADFBZF PE IV1T No: 06/28 /04 PWE/KAK GLV GO 12/10/09 CJWSV GLV GO (11/30/09) — API No 50- 029 - 22046 -02 06/19/05 DRS/PJC CORRECTION KB SEC 19, T11N, R12E, 4306' FSL & 3667' FE1 08/09 /06 BSE/PJC GLV GO 10/14/09 MN /PJC ADPH2FS (10/10/09) BP Exploration (Alaska) NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM Cho e Panel Standpipe 2" Circulation Line .® Lj Driller Gauge � M 10 � MM 1 '" Manual Choke CIRCULATING MANIFOLD .M� . ; MM 20 'f E P MM 22 Set SLB Transducer a MM 8 • PVT Sensor 7. 1/16" 5kpsi BOPEp Air Blow down - t MM 7 f: ® Blind Shears . �"� Line r'• aS - Baker Choke �Wr MM5 _ MM 21 GAS BUSTER , 2-3/r Combi • a 0 Kill Line TOT P/S Rev Cir Line M A :a - � 4, MM14 .. ra - �� z��s's �+ a� r+ ■ t i p BOP 24 ,I " -- Coiled Tubing t III ~� 2 -318" - 3 -112" VBR ram 11111111111111, llIIIIIIIIIIIIIIIIIIIIIIIIIIIINIIIIIIII 11110111111116 -* - Ba er Choke a° 2 -318" Combi MM 1 . : 4111 • MP1 in � • MM 13 0 -- i C4 t�f. 0 1- Kill Line °- Outlet f-- Cement Line to Ground 0 Mud • 2 in V '� Pu,. .s In Tranducers COILED TUBING Choke Line CIRCULATING SYSTEM Cellar CCC 111 ' • ' Area . I. i I r II ii - . ... HP 14 — _ C Flowc'» F ■ To Inner Reel Outlets Valve ,.,.. � HP 'O 140 HP7 HP4 M. .. HP3 _ I..I, Tmmi HP2 HP1 HP it • • • cement line N2 ( SLB NORDIC'S 2 I Circulate Manifold _ _ CHOKE MANIFOLD in Cellar -_- HP 11 N2 TriFlow "CM 85 Gauge �I � n. CHOKE LINE M � ., I l Test Pump Inlet — '— ,, .'—.• ti 4) CM3 HD! Gauge CMI8 It IB • Flow f/ HCR Ten : 0 4Way Block CM14 CMI CM8 ir IN E To PITS M CM5 CM6 IMI C 12 C ■ 11 mi r „ . Baker Choke Line from m Baker Choke Line MI from wall von w CM13 I'— eker Choke Line CM2 = CM19 ■ Use for O% Blowing ��I. CM 26 CM 29 M t Back MM CM20 411; CM4 = CM21 M j _ III P T II CM 30 CHOKE LINE Er - CM 75 CM10 I Tige Tank CM 25 f Outside • ® p. Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 `/ form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and 'V operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill" 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrili is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 10116109 Scblemberger _ ,rU� NO. 5418 Alaska Data & Consulting Services �,d�,A jjN & }'" Company: State of Alaska 2525 Gambell Street, suae 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job M Log Description Date BL Color CD P1 -25 AP30 -00063 INJECTION PROFILE 10/0209 1 1 W -01A B2NJ -00026 MEMORYGLS — 10/02109 1 1 12 -06A AZCM -00043 LDL 10/03/09 1 i W -36 AVIH -00028 PROD PROFILE W /GL 09/29/09 1 1 E -36A 82NJ -00027 MEM CEMENT BOND LOG 10/03/09 1 1 12 -34 AYS4 -00104 INJECTION PROFILE 10/11/09 1 1 Z -07A AYS4 -00101 PRODUCTION PROFILE I c l 10108/09 1 1 15 -18A 82WY -00015 MEM PROD PROFILE 07/01/09 1 1 05 -18A 804C -00069 SCMT .- 1 07/30/09 1 1 U4115A 914B -00068 USIT 08/17/09 1 1 P -07A AWJI.00051 MEM P PROFILE 10/09/09 1 1 09 -03 AZCW00044 PRODUCTION LOG 10/10/09 1 1 1- 45/0 -26 82NJ -00032 MEM LDL 10/10/09 1 1 S -134 AWLS -00039 USR 09/28/09 1 1 V -105 83SO -00026 IPROF 10/03/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Surte 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1 14 • STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~E~EIV~L~ ~CT 2 0 2aQ9 1. Operations Abandon ~ Repair Well ~ Plug Pertorations ~ Stimulate~ ~~~ (~8S ~,OIIS. ~ORII't11S$1 Pertormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Anchorage Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re- ter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory 193-1100 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorag~,AK 99519-6612 50-029-22046-01-00 8. Property Designation (Leas umber) : . Well Name and Number: ADLO-028245 PBU Z-07A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POO~ 11. Present Well Condition Summary: Total Depth measure~ 13174 feet Plugs (measured) None feet true vertical 9118.34 feet Junk (measured) BELOW 13032' feet Effective Depth measured 13133 feet Packer (measured) 10141 12009 true vertical 9095.53 feet (true vertical) 7415 8487 Casing Length Size MD ND Burst Collapse Structural Conductor 110 20"91.5# H-40 31 - 141 31 - 147 1490 470 Surface 2709 13-3/8"68# L-80 30 - 2739 30 - 2644 4930 2270 Intermediate Production 10257 9-5/S" 47# L-80 29 - 10286 29 - 7511 6870 4760 Liner 3033 7"29# L-80 10141 - 13174 7415 - 9118 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 27 - 12069 27 - 8520 Packers and SSSV (type, measured and true vertical depth) 7" Liner Toa Packer 10141 7415 4-1/2" Baker SABL-3 Packer 12009 8487 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~;~~~i19~~ ~r~ ~F; l~ ~ ~~~,~ d9C$~/;T 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 weli operation: 72 460 661 332 Subsequent to operation: 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ~ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL G TOR ^ 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 Preble Title Data Management Engineer Signature ~ Phone 564-4944 Date 1D/20/2009 Form 10-404 f~evised 7/2009 /~ ~O'+ ' 'S ~ ~ ('~ ~ ~~ ~~ Submit Original Oniy ~ ~v ~ ,a.ZZ.09 Z-07A 193-110 PERF ATT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z-07A 9/27/93 PER 12,904. 12,924. 8,968.66 8,979.67 Z-07A 9/27/93 PER 12,930. 12,950. 8,982.98 8,994.01 Z-07A 10/8/93 APF 12,980. 13,000. 9,010.58 9,021.65 Z-07A 10/8/93 APF 13,004. 13,016. 9,023.86 9,030.51 Z-07A 10/14/93 APF 12,766. 12,806. 8,893.16 8,914.98 Z-07A 9/15/94 RPF 12,786. 12,806. 8,904.07 8,914.98 Z-07A 9/15/94 RPF 12,766. 12,786. 8,893.16 8,904.07 Z-07A 10/19/94 APF 12,830. 12,852. 8,928.1 8,940.13 Z-07A 4/4/95 APF 12,856. 12,884. 8,942.32 8,957.68 Z-07A 10/8/09 APF 12,890. 12,904. 8,960.97 8,968.66 Z-07A 10/9/09 APF 12,860. 12,870. 8,944.51 8,949.99 Z-07A 10/9/09 APF 12,830. 12,850. 8,928.1 8,939.04 Z-07A 10/9/09 APF 12,874. 12,884. 8,952.19 8,957.68 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 TREE = 4-1l16" CNV WELLHEAD = FMC ACTUATOR= ~~ OTIS KB. ELEV = 88-62' BF. F~EV = 57.56' KOP = 1800' Max Angle = 59 @ 11377' Datum MD = 92762' Datum ND = 8800' SS 13-3/8" CSG, 6$#, L-80, ID = 12.415" Minimum ID = 3.725" @12056' 4-112" PARKER SWN NIPPLE PERFORF~TK3N SUMMARY REF LOG: GR/CCL ON 09126l93 ANGLE AT TOP PE~2F: 57° @ 12766' Note: Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz dATE 3-3/8" 6 12766 - 12806' O 10l14/93 2-718" 6 12830 - 12850 O 10/10/09 3-3/8" 6 12830 - 12852' O 10/19/94 3-3/8" 6 12856 - 12866' O 04/04/95 2-7/8" 6 12860 - 12870 O 10/10109 3-3/8" 6 12866 - 12884' O 04/01/95 2-7/8" 6 12874 - 12884 O 10/10/09 2-7/8" 6 12890 - 12904 O 10I10l09 3-3/8" 4 12904 - 12924' O 09l27l93 3-3/8" 4 12930 - 12950' O 09l27193 3-3/8" 4 129$0 - 13000' O 10(08/93 3-3/8" 4 13004 - 13016' O 10108/93 9-5/8" CSG, 47#, L-$0, ID = 8.681" • S TES: **" ORIG W ELL.BORE (Z-07) NOT Z~O ~A SHOWN BELOW MILLOUT WINDOW ""* 4-1/2" I 12189' I 4-1/2" TBG, 12.6# 13 CR-NSCT, .0152 bpf, ID = 3.958" ~-~ 12067' 1951, I-~4-1/2" PKR SWS NIP, ID = 3.813 ~ 1200g~ 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 12039~ 4-1J2" PKR SWS NIP, ID = 3.813" 12056~ 4-1/2" PKR SWN NIP, ID = 3.725" 12069~ 4-1/2" WLEG, ID = 3.958'~ 1207$' ~MD FISH- UNDERREAM I BLADE (6/05/94) ~TO 13133' 7" LNR, 29#, L-80 NSCC, .0371 BPF, ID = 6.184" 13174' DATE REV BY COMMENTS DATE REV BY COMMENTS 06t13/90 SJA ORIGINAL COM PLETION 10/15/09 PJC DRAWING CORRECTIONS 09(20/93 RIGSIDETRACK(Z-07A) 06/28/04 P/VEIKA GLV GO 06t19(05 DRS/PJC CORRECTION KB 08l09106 BSE/PJC GLV GO 10/14/09 MV/PJC ADPERFS (10/10/09) 2102' 4-112" OTIS SSSV NIP, ID = 3.813" GAS LIFf MANDRELS >T MD ND DEV TYPE VLV LATCH PORT DATE 4 3418 3023 50 MERLA SO RK 20 08/09/06 3 7198 5400 53 MERLA DOME RK 16 06/28/04 2 9923 7180 49 MERLA DMY RK 0 10/12/94 1 10034 7253 49 MFRLA 50 RK 20 06/28/04 10133~ BAKERTIEBACKSLV,ID=7.50" 10141' 9-5/8" X 7" BKR L7W w/ HGR, ID = 6.187 , 9-5/8" MILLOUT WINDOW (2-07A) 10286' - 10336' ( PRUDHOE BAY UNfT WELL: Z-07A PERMIT No: ~1931100 API No: 50-029-22046-01 SEC 19, T11 N, R12E, 4306' FSL & 3667' FEZ BP 6cploration (Alaska} ~ • Z-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ~ A~T ' . , w ,. , , , ~ ~ _ ~ ~ ~ 10/7/2009 ; *''* WELL FLOWING ON ARRIVAL*"* (E-LINE PRODUCTION PROFILE). y ~ INITIAL T/I/O 350/1500/350. ; ~RUN 1: HEAD/3 X WEIGHT BARS/PBMS/PGMC/PILS/PFCS. TOTAL LENGTH ~ °42' MAX OD 1 11/16". UNABLE TO GET PAST 11400'. PULL OUT OF HOLE ~ ;AND ADD ROLLERS TO TOOLSTRING. i 6RUN 2: ; ~ HEAD/WEIGHT/ROLLER/WEIGHT/WEIGHT/ROLLER/PBMS/PGMC/PILS/PFCS. =TOTAL LENGTH 44' MAX OD 2.65". TAG TD AT 13027' AND MADE UP DOWN ~ ~PASSES AT 40, 80, 120 FPM FROM 12700' TO TD. WELL WAS CYCLING AND ~ ' FLUID VELOCITY WAS SO SLOW IN 7" LINER THAT PRODUCTION SPLITS I ~ARE UNRELIABLE, FLUID APPEARS TO ONLY BE ENTERING FROM UPPER ; ~ ~MOST PERF ZONE: 12766'-12806'. HOWEVER THIS COULD NOT BE ~ E UNTS BECAUSE FLUID VELOCITIES WERE ~ ;BELOW THE SPINNER THRESHOLD. E € MADE STOP COUNT AT 12700' TO TRY AND CAPTURE A FULL DOWN HOLE ~ ! 'PRESSURE CYCLE. ~ ~ ~..... _ _.__ w ____ e"**JOB CONTINUED ON 8-OCT-2009'"*~ _ __.__._ _ _~___ _ . ~= 10/8/2009 _ _ ~ _______ ~ ~_. ___ _ ~ ~ ~_ ... ~ _ ._ __. ~ __ ~*"*JOB CONTINUED FROM 7-OCT-2009'""* (E-LINE PRODUCTION ~ `PROFILE/PERF). a CONTINUED STOP COUNT AT 12700' TO TRY AND CAPTURE A FULL DOWN ; ` €HOLE PRESSURE CYCLE. WELL APPEARS TO UNLOAD ROUGHLY ONCE ' ~ ~EVERY HR, BUT NOT TO THE SAME EXTENT. ; ~THE MAJORITY OF PRODUCTION APPEARS TO BE COMING FROM THE ! UPPER MOST PERFS 12766'-12806'. THERE MAY BE SOME SMALL [ ~AMMOUNT OF FLUID PRODUCTION FROM THE 2ND DEEPEST PERF 12980'- ! ' ~;13000'. NONE OF THE OTHER PERFS APPEAR TO BE PRODUCING. iSPLITS AS PERCENTAGES WERE NOT POSSIBLE BECAUSE THE FLOW 3 RATE WAS TOO LOW. SHUT IN WELL TO MAKE GUN RUNS. ~ iALL GUNS ARE 2-7/8" POWERJET 2906 HMX, 6 SPF, 60 DEG PHASING. ~ ~RIH WITH FIRST GUN. HEADM/EIGHT/CCL/ROLLER/FIRING HEAD/2 7/8" ~ ~PERFORATING GUN/ROLLERS. TOTAL LENGTH 36' MAX OD 3.2". `CORRELATED TO ATLAS GR/CCL LOG DATED 26-SEP-1993. 1~ ~ PERFORATED FROM 12890'-12904'. [ ~RIH WITH SECOND GUN. HEAD/CCL/ROLLER/FIRING HEAD/2 7/8" 'PERFORATING GUN/ROLLERS. TOTAL LENGTH 20' MAX OD 3.2" ~ ~ ~ Tm^~ ~***JOB CONTINUED ON 9 OCT-2009'''`'` 10/9/2009 ***JOB CONTINUED FROM 8-OCT-2009*"* (E-LINE PERFORATING). ~ O PERFORATE FROM 12874'-12884' ~ ' .RIH WITH 3RD GUN STRING. HEAD/CCUROLLER/FIRING HEAD/2 7/8" ~ ; PERFORATING GUN/ROLLERS. TOTAL LENGTH 20' MAX OD 3.2". ~ PERFORATE FROM 12860'-12870' ~RIH WITH 4TH GUN STRING. HEAD/CCUROLLER/FIRING HEAD/2 7/8" aPERFORATING GUN/ROLLERS. TOTAL LENGTH 30' MAX OD 3.2". ~ PERFORATE FROM 12830'-12850' ~ ~TOOLS HUNG UP AT 1150' WHILE POOH (ICE PLUG?) PUMPED 6 BBL ~METHANOL DOWN TUBING, THEN TOOL WAS PUSHED OFF THE LINE 'WHEN ICE PLUG SHIFTED. ~ ~ ~~~ ~ ~ LRS PUMPED 200 BBL CRUDE DOWN TUBING TO KILL WELL FOR E-LINE TO SAFELY POOH WITH ONLY WIRE. ~ 3 **"JOB CONTINUED ON 10-OCT-2009*** ~ ~.~~~.. ~ 10/9/2009~ ; ~ T/I/0= 1150/1300/220 Assist E-line Pumped 3 bbl meth spear down tbg followed by 175 bbls of crude down tbg (continued on 10-10-09) '~ 10/10/2009 Continued from 10/9/09 Assist E-Line.. Pumped 117 bbls crude (Total of 290 bbls) ~ down tbg to knock down pressure. Freeze protect flowline with 10 bbls of methanol. Pad op notified of well status and tree valve positions as follows: j ESV,WV = closed. SSV, Master= open. IA and OA open to gauges. Final WHP= ~ ~ 500/1300/220 ~...~._ ~ 10/10/2009 *"'`JOB CONTINUED FROM 9-OCT-2009''** (E-LINE PERFORATING). ~ ; LRS PUMPED 292 BBL CRUDE AWAY, THEN WITH PUMPS SHUT DOWN THE ~ WHP SLOWY DROPPED FROM 1300 TO 600 PSI. ~ PULLED E-LINE WIRE TO SURFACE AND RIGGED DOWN. WELL TURNED ~ OVER TO LRS TO FREEZE PROTECT THE FLOW LINE. ~ ~ j ~ FINAL T/IA/OA: 600/1300/240. PAD OPERATOR NOTIFIED OF VALVE POSITIONS: MASTER:O, WING:C, ~ ' ~ ; ~ ~~ SSV:O, SWAB:C, IA/OA:OTG, GAS-LIFT:C, GROVE:C. OPERATOR NOTIFIED OF NO-GO CONDITION OF THE WELL DUE TO TOOL STRING LEFT DOWN ~HOLE. WELL LEFT SHUT-IN. """JOB INCOMPLETE*** 10/18/2009 ~ ~ ''*" WELL SHUT IN ON ARRIVAL"** ~ ~~~ 10/19/2009 RU SLICKLINE """CONT. ON 10/19/09 WSR*''* *"''CONT. FROM 10/18/09 WSR*** ~~ ~~5 ~ ~ Q FISH E-LINE TOOLS AND SPENT PERF GUNS a~ 12975' SLM v~ ~ ~ALL E-LINE TOOLS RECOVERED. LAY DOWN TOOLS AND GUNS. ~ ~"** RIG DOWN TURN WELL BACK TO PAD OP *** ~ ~***JOB COMPLETE*'"'" ~ ~__ **" NOTIFY PAD OP OF DEPARTURE *** _ __~ FLUIDS PUMPED BBLS 2 DIESEL 6 METH 8 Total 8~~ ~ BP Expioration (Alaska) inc. Attn: Weli Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~.~~~~~~ y~~r~,f -, ~t ~i~~`~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, ~ bp ~~V~~~E~ OCT 0 5 2009 d~las~C~ Oil & Gas Cons. GOI~RRIA1~ Anchoraqe t~~"~IC~ z_ o ~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTO # API # initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/2M2009 Z-08A 1931280 500292t7870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 02 fVA 1.70 7l24J2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-1tA 2050310 50029220530t00 NA 0.2 NA 1.70 7/26/2009 z-12 1891020 soo2s21snoooo NA 1.2 NA 8.50 ~i2si2oos Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 500292t8790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 500292i9540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-32BL1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-1o8 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-1~2 2071720 50029233800000 NA surface NA 09/28/07 $chlumberger NO. 4440 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400�e, NOV ��R Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 i C; ►V V / Attn: Christine Mahnken yJ, ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Color CD 15 -39A 11661174 MEMORY PROD PROFILE ( ( 09/23/07 1 II W-42 11745235 MEM SBHPS /TEMP Ui ,_ its-- 653.. 09/14/07 1 r-31° Z-07A N/A SBHP SURVEY 9.3 — / (e 09/14/07 1 A -04 11594519 SBHP SURVEY a —00(„ 08/26/07 1 Y -24 11630499 LDL u-T, C / f5. (, _ 03 3 09/04/07 1 L5 -28A 11855810 PRODUCTION PROFILE r`90G —0 08/31/07 1 X -33 11849931 SBHP SURVEY J /el (., - /[(G( 08/31/07 1 E -14A 11686784 LDL (ci q — 133 • 09/23/07 1 01 -15A 11855509 DDL 196 al b 09/22/07 1 D -21 11626119 PRODUCTION PROFILE /'5 — 05a 09/11/07 1 K -07D 11745234 MEM PROD PROFILE ! /C _ a4I 09/06/07 1 11 -32 11630498 PRODUCTION PROFILE J C - 09/03/07 — 1 L -01 11745233 MEM LDL a Q / - 0 a 09/04/07 1 07 -30A 11661168 MEM STP & CORRELATION a 03 -gyp 08/28/07 1 Z -28 11630500 INJECTION PROFILE (27_,C /tic_ /0"3- 09/05/07 1 Z -16 N/A SBHPS /JEWELRY / a-C3/ 09/13/07 1 14 -26 11676959 LDL / O / —//o 09/09/07 1 04 -02A 11630504 LDL ic2 J— / / 09/11/07 1 14 -37 11695075 LDL / f ,4 09/13/07 1 III 3- 35/L -36 11630502 PRODUCTION PROFILE /15 —D() 09/09/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANDRETU ING -O,NE COPY EACH TO: BP Exploration (Alaska) Inc. = Y„: ,--- t. \r, 7^ .: Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-28i Anchorage, Alaska 99508 'T 3 71107 ATTN: Beth Date Delivered: Received by: I , I 7. ,. 1. :i < . q;4s91 ' 1 %fit[ ?at V/ ■ 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS J" , , UN I 4 2005 Repair WellD Pull Tubing 0 Operation Shutdown 0 PluQ Perforations 0 Perforate New Pool D Perforate 0 Stimulate ŒJ WaiverD \:1, to"~ ',. O~QerD _, . ü¡ .,t~.~,'ì,~~ t.!::H~ !;i)nr¡.~r~'"i(':; ':i,o, Time Exte!1slonu' ", .. 'dl" ·¡;,,'l p:::'';I i,ï~,' !;'} r:~~ ~',1~'::\ Re-enter Suspe~d~d' \.\"~¡I:D 5. Permit to Drill Number: 193-1100 6. API Number 50-029-22046-01-00 2. Operator Name: 3. Address: BP Exploration {Alaska}, Inc. 4. Current Well Class: Development Œ] ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 88.62 8. Property Designation: ADL-028245 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: Z-07 A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool Total Depth measured 13174 feet true vertical 9118.3 feet Effective Depth measured 13133 feet true vertical 9095.5 feet Plugs (measured) None Junk (measured) Junk (below 13032') Casing CONDUCTOR LINER PRODUCTION SURFACE Length 110 3033 10257 2709 Size 20" 91.5# H-40 7" 29# L-80 9-5/8" 47# L-80 13-3/8" 68# L-80 MD TVD Burst Collapse 31 141 31.0 141.0 1490 470 10141 - 13174 7414.5 - 9118.3 8160 7020 29 - 10286 29.0 - 7510.9 6870 4760 30 - 2739 30.0 - 2644.1 4930 2270 Perforation depth: Measured depth: 12766-806, 12830-852, 12856-884, 12904-924, 12930-950, 12980-13000, 13004-016 NNED JUN 1 'I' 2005 True vertical depth: 8893-8904,8928-8940,8942-8858,8987-8980, 8983-8994, 9011-9022, 9024§&f\· " " TubinQ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 27 12069 Packers & SSSV (type & measured depth): 7" Liner Top Packer 4-1/2" Baker SABL-3 Packer 4-1/2" Otis SSV Nipple @ 10141 @ 12009 @ 2102 RBDMS 8Fl JUN 1 5 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12766 - 13016 Treatment descriptions including volumes used and final pressure: 145 bbls 9:1 Mud Acid, 45 bbls 90:10 DAD, 400 bbls 3% NH4CL wI F-103 @ 3800 CTU psi. Prior to well operation: Subsequent to operation: Oil-Bbl 93 94 Representative Dailv Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 206 1224 0 284 1196 0 Tubing Pressure 267 284 13 Copies of Logs and Surveys run_ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development [!I Service D 14. Attachments: Contact DeWayne Schnorr WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name DeWayne Schnorr Signature A.:t.~þ.J ~ ~ Title Petroleum Engineer Form 10-404 Revised 4/2004 (, R. " ¡ (' i ~:>hJ\neL 564-5174 \....,! 1'\ ~ u i \ \; I~ Date 6/14/05 ') ) Z-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/19/05 CTU #5, ACID TREAT; MU/RIH WI 2.5" DJN. JET HYDRATE PLUG FROM 23431 TO 3417' WI METH/WTR AND HOT KCL. JET TO 60721. LOAD IA W/277 BBL CRUDE, CAP WI DIESEL. MU/RIH WI 2.5" BDN. 04/20105 CTU #5, ACID TREAT; RIH WI 2.5" BDN. LOADIFLUID PACK WELL WI NH4CL WI F- 103. CAP WI WATER/METH. COOL DOWN PERFS WI 60 BBLS NH4CL DOWN CT. JET 45 BBLS DAD ACID FROM 130161-127661. JET 19 STAGES OF 7.5% HCL, 9:1 MUD ACID, NH4CL WI F-103, AND WAX BEAD DIVERSION BETWEEN 13016'-127661. POOH. FP WELL WI METH. HAND WELL OVER TO ASRC TO FLOW BACK. *** JOB COMPLETE *** 04/23/05 4 HOUR WELL TEST. CORRECTED GROSS FLUID RATE 983.2 STBFPD. CORRECTED OIL RATE 282.4 STBFPD. CORRECTED FORMATION GAS RATE 0.276 MMSCFPD. NET WATER RATE 700.8 BWPD. LIFT GAS RATE 2.0 MMSCFPD. WHP 287 PSI. CHOKE 176 BEANS. AVERAGE WIC 72.60/0. FLUIDS PUMPED BBLS 403 Methanol Water 207 1 % KCL Water 14 Diesel 277 Crude 400 3% NH4CL with F-103 45 90:10 DAD 145 9: 1 Mud Acid 37 Fresh Water 1230# Wax Beads 1528 TOTAL Page 1 ') TREE = 4-1/16" OW WELLHEAD = FMC A'CWATäR'; ""'''''oris kELËLBï;·'....·'§'2':Tëi 88.' Z SF:' ËLBï';;;;' ...... ""'57:56; kÖÞ';;;;' .... ············ÜiöÖ; .~¡;)~..~,~~I.IõJ..,:. ...,?~.~..,~,~~!.!: Datum I\¡[) = 12762' ..., "",,"'.............. Datum ND= 8800' SS 13-3/8" CSG, 68#, L-80, 10 = 12.415" 1-1 2739' r---J Minimum ID = 3.725" @120561 4-1/2" PARKER SWN NIPPLE BAKERTIEBAO< SLV, 10= 7.50" 1-1 10133' 9-5/8" x 7" BKR LNR TOP A<R -I 10141' W/TIEBACK, 10 = 6.187" 9-5/8" X 7" BKR Hrv'C LNR HNGR, 10 = 6.187" H 10146' PERFORATION SUMMA RY RB= LOG: GR/CCL ON 09126/93 ANGLEATTOPÆRF: 57@ 12766' I\bte: Refer to A"oduetion DB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 3- 3/8" 6 12766 - 12806' 0 10/14/93 3- 3/8" 6 12856 - 12866' 0 04/04/95 3-3/8" 6 12866- 12884' 0 04/01/95 3-3/8" 6 12830 - 12852' 0 10/19/94 3-3/8" 4 12904 - 12924' 0 09/27/93 3-318" 4 12930-12950' 0 09/27/93 3- 318" 4 12980 - 13000' 0 10/08/93 3-318" 4 13004 - 13016' 0 10/08/93 ') Z-07 A SAFETY NOTES: 13 CHROME TBG. OLDWB.LBORE (Z~7) NOT SHOWN BELOW MILLOUT WINDOW. FISH ON BTM (UNDERREAMER BLADE LOST ON 06/05/94). e 2102' H4-1/2"OTlSSSSV NIP,ID=3.813" I ~ L ST fvD 4 3418 3 7198 2 9923 1 10034 GAS LIFT MANDRELS DEV TYPE V LV LA TCH 50 MERLA DOME RK 53 MERLA DOME RK 49 MERLA D\1Y RK 49 MERLA SO RK FORT DATE 16 06/28/04 16 06/28/04 o 10/12/94 20 06/28/04 TVD 3023 5400 7180 7253 :) J ~ 9-5/8" MILLOUT WINDOW 10286' - 10336' 11951' H4-1/2" PARKER SWS NIP, 10 = 3.813 12009' 1-17" X 4-1i2" BKR SABL-3 A<R, 10 = 3.875" 12039' 1-14-1/2" PARKERSWS NIP, 10 =3.813" 1-{4-1/2" PARKER SWN NP, 10 = 3.725" 1-14-1/2" WLEG I 12078' 1-I8.MD 9-518" CSG, 47#, L-80, D = 8.681" 1-1 12189' 14-1 i2" TBG, 12.6# 13 CR-NSCT, .0152 BPF, 10 = 3.958" l-t DATE 06/13/90 09/20/93 06/23/01 06/30/03 06/28/04 REV BY OOrvfv1ENfS SJA ORIGINAL COM PLETION RIG SIŒTRACK (Z-07A) CI-VTP CORRECTIONS JJiKA K GL V C/O FW6'KAK GLV C/O 13133' IT' LNR, 29#, L-80 NSCC, .0371 BPF, 10 =6.184" 1-1 13174' I DA.1E RBI BY Cürv1MENTS FRLDHOE BA Y UNIT WELL: Z-07 A PERrv11T No: 1931100 A A No: 50-029-22046-01 SEC 19, T11 N, R12E. 4306' FSL & 3667' ÆL BP Exploration (Alas ka) OR BEFORE ~L- _ ~~L U N ~ C:i,Og.~,v~ILM.DOC STATE OF ALASKA AL,--,¢KA OIL AND GAS CONSERVATION COMMISb, lwN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate . Plugging__ Pull tubing __ Alter casing __ Repair well__ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 947' SNL, 1287' WEL, SEC 19, T11N, R12E At top of productive interval 2612' NSL, 810' WEL, SEC 14, T11N, R11E At effective depth 2528' SNL, 1091' WEL, SEC 14, T11N, R11E At total depth 2765' SNL, 1458' WEL, SEC 14, T11N, R11E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE= 88.62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-O7A (42-14-11-11) 9. Permit number/approval number tto 10. APl number 50- 029-22046-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2706 I nterm ediate 10252 Production -- Liner 3041 Perforation depth: measured 13174' feet Plugs(measured) 9110'feet 13133' feet Junk(measured) 9089'feet Size Cemented 20x30 280 c.f. Arcticset 13-3/8 3806 cuft Permafrost 9-5/8 365 cuft Class "G" 7" 209 cuft Class "G" 12904'- 12924', 12930'- 12950' Measured depth 144 2740 10286 10133-13174 True vertical depth BKB 144 274O 7510 7418-9117 true vertical subsea 8967'- 8978~ 8981'- 8992' Tubing (size, grade, and measured depth) 4-1/2" 13CR @ 12068' Packers and SSSV (type and measured depth) TIWpacker @ 12008' SSSV @ 2102' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 348 590 210 2710 316 533 2O2 249O Tubing Pressure 253 272 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Ope/ra, tions .__ 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereb~ ce6ity that the,foregoing is true, and ¢orrect to the best of my knowledge. / Ii /:."/." ..'~-~. I I/' //~ · ... ; / ~./.~.,.~,, ,/ / S,gned ?- t ..~..-,:..., ~/_..,.__./~/ ; ,.-,,..~ ~.~'~ ./-//~.~ .~ ....-._., Title TeChnicalAssistantlll Form 10-404 Rev 06/15/88 /' Date '" '~ ":-"' ? SUBMIT IN DUPLICATE WELL Z-07A(42-14-11-11) Addperf 4/01/95 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12866'- 12884' MD' Addperf 4/04/95 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12856'- 12866' MD' STATE OF ALASKA AL,-,,..4.(A OIL AND GAS CONSERVATION COMMISS~tJN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging__ Pull tubing__ Alter casing Repair well_ Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 947' SNL, 1287' WEL, SEC 19, T11N, R12E At top of productive interval 2612' NSL, 810' WEL, SEC 14, T11N, R11E At effective depth 2528' SNL, 1091' WEL, SEC 14, T11N, R11E At total depth 2765' SNL, 1458' WEL, SEC 14, T11N, R11E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE= 88.62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-O7A (42-14-11-11) 9. Permit number/approval number 10. APl number '" 50- 029-22046-01 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical 13174' feet 9110' feet Plugs (measured) Effective depth: measured 13133' feet Junk (measured) true vertical 9089' feet Casing Length Size Cemented Structural -- Conductor 110 20x30 280 c.f. Arcticset Surface 2706 13-3/8 3806 cu fl Permafrost Intermediate 10252 9-5/8 365 cu ft Class "G' Production -- - Liner 3041 7" 209 cuft Class "G" Perforation depth: measured 12904'- 12924', 12930'- 12950' Measured depth 144 274O 10286 10133-13174 True vertical depth BKB 144 274O 7510 7418-9117 true vertical subsea 8967'- 8978', 8981'- 8992' Tubing (size, grade, and measured depth) 4-1/2" 13CR @ 12068' Packers and SSSV (type and measured depth) TlWpacker @ 12008' SSSV @ 2102' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 348 590 210 2710 316 533 202 2490 Tubing Pressure 253 272 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Opezr~tions __ Oil X Gas Suspended 17. I hereb, v; ce!;Cf¥ tha4 the,f'o/e.qoing is true/~and correct to the best of my knowledge. S ig n ed ~'~(//'~~ ~/~~~ Title TechnicalAssistantlll Form 10-404 Rev 06/15/88 Service Date SUBMIT IN DUPLICATE~~' WELL Z-07A(42-14-11-11) Addperf 4/01/95 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12866'- 12884' MD' Addperf 4/04/95 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12856'- 12866' MD' " STATE OF ALASKA AL /.A OIL AND GAS CONSERVATION COMMIS ,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 947' SNL, 1287' WEL, SEC 19, T11N, R12E At top of productive interval 2612'NSL, 810' WEL, SEC 14, T11N, R11E At effective depth 2528' SNL, 1091' WEL, SEC 14, T11N, R11E At total depth 2765'SNL, 1458' WEL, SEC 14, T11N, R11E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE= 88.62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-O7A (42-14-11-11) 9. Permit number/approval~uj'n_.b~r 10. APl number 50- 029-22046-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2706 Intermediate 10252 Production -- Liner 3041 Perforation depth: measured 13174' feet 9110' feet Plugs (measured) 13133' feet Junk (measured) 9089' feet Size Cemented 20x30 280 c.f. Arcticset 13-3/8 3806 cu ft Permafrost 9-5/8 365 cuft Class "G" 7" 209 cu ft Class "G" 12904'- 12924', 12930'- 12950' Measured depth 144 2740 10286 10133-13174 True vertical depth BKB 144 274O 7510 7418-9117 true vertical subsea 8967'- 8978', 8981'- 8992' Tubing (size, grade, and measured depth) 4-1/2" 13CR @ 12068' Packers and SSSV (type and measured depth) TlWpacker @ 12008' SSSV @ 2102' 13. Stimulation or cement squeeze summary See Attachment '" 'ED :..~L" ',~ ' AUG 3 0 1995 0il & Gas Cons. C0mmJssi0n Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 338 297 88 1510 306 372 198 2000 Tubing Pressure 2~ 260 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil X Gas__ Suspended 17. I hereby c, ertify that the for~b'~r~g i~u,e and correct to the best of my knowledge. s igned ~ Title Senior Technical Assistant II Form 10-4(J4 Rev 06/15/88 Service Date SUBMIT IN DICPLIC'ATE ...~.~' 09/15/94 10/01/94 WELL Z-07A (42-14-11-11) ReperffFrac Addperf Operation The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12766'-12786'MD 12786'-12806'MD A Hydraulic Fracture was performed using the following fluids: Operational problems Tree not grease locked delayed things. During 7 ppg sand stage, screened out tub and had to drop rate to 20 bpm. Total time under 40 bpm was less than 30 seconds. Comments Note plot on pad looked wierd. Really nosedived from 9 min to 11 min after pad on formation. This is about when 1 ppg was on perfs. Got away 80 more bbls than last time, with 7 ppg on perfs. 1/2 of a treesaver rubber left in hole. WL to fish. FLUIDS PUMPED DOWNHOLE IT/DF: 1107 Bbls FRAC: 955 Bbls 50 100 150 2062 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME Diesel to IA, tubing, or GC Diesel Recovered (not downhole) Total Diesel 10/19/94 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12830'-12852'MD ,<) 3 .... 1 i 0 g 3 ' 11 ~I--I .... ,3R~ i '185(;) ....13 102 ~;,H .... CDR/CDN~ I2685-.-i3'1/~19 ~&:B~~gO00 g600 rJ ~,~' L ) L4~.....B '~ ~ 1 i 8 5 0 .... 1 3 '1 0 2 · i'::'EiRF) ~~.~ 12'/8~ .... 13000 I... 'i2F~00 ..... i2.~36 P o. E! e * i Date: 13 ~'~,. / '~ 0 /' ~ ~:~ i~1i N E, .A T ~: ~. r: ..... R E C V D ........................................ . i 0/1 o/i /lO/lgO'' 10,, ~16/' log'~ I 1,,' ' .... /1° i0/04., .:,g3 / i i0/-i3,, . i O/1 g/'/gg 3 1 O/'I 3/i 993 1 i i / 0 i / i i 0/I 5/1993 i i/.' .16 / lC~g :~ I O/'I g/1 gg3 i'i 0 yEaE~ iqO LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 125 DESCRIPTION PFC/PERF FINAL BL+RF CN/GR FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF ECC No. Run # 1 926.07 Run # 1 3763.02 Run # 1 4472.02 Run # 1 4880.04 Run # 1 6042.09 Run ~ 1 6403.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Pe-troteel:nical Data Cente~ DP E~!oration (Alaska) In~ 900 East Benson Boulevard , . · A~cho~ge LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 4 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 93-' I I O DESCRIPTION CCL/CUT FINAL BL+RF PFC/PERF FINAL BL+RF CCL/CUT FINAL BL+RF ECC No. Run # 1 3916.01 Run # 1 6042.08 Run # 1 6399.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: RECEIVED ~PR 3 7 1995 A~.~ Oil & 6as cons. Commission LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 26 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: ELL .E-ii (33-32-12-14) f~~ F-32 (44-34-12-13) DESCRIPTION ¢ PO~'/cc~. FInAl. sr., 1 POL/CCL RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 CCL/CHEMCUT FINAL BL 1 CCL/CHEMCUT RF SEPIA ECC No. Run # 1 3060.04 Run # 1 Run # 1 4123.03 Run # 1 Run # 1 4473.02 Run # 1 Run # 1 6042.07 Run # 1 Run # 1 6285.01 Run # 1 ~Pi~ca sign =,,d reuurn to: Atlas ~ ....... crviccs ~ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson .~ '~A - ~ Or FAX to (907) 563-7803 '~. ~ ~ ~ ~r_J~l 131 ,hr rJ~rLL~R~I Ig~l~ ~ ~ ~-~-~ ~ ~,~.~ ~ B~ rE~U~E~ rE~ ~ Z/ 2 / TOTAL: WELLS ~QT IN AOGCC CO,MPLIANCE;exel. susp,/H20 Inl.lWaiverm} (s~ed ~ate) GL WELLS NOW SHOW THE SAME 8.1.P. A5 THE INJ II~:~TI n,~'?~ SIZE/TYPE T PPM Fvc-a~-e~ COMMBN'I~ FL ~ 6" CIW R~ and r~ ~p pmxim~ J-a3 o~1~,~ 2750 11 41/ZRQ OI1~ ....H 1 13 tent~tsssvg-28.94 W-04 'FL ~T '" ~ =l~l ~d treatment up ~ming 7/~4 ;500 3~ 31~X L 7 11 tent ~t ~v 9.2~ ..... FL ~T ' 4" ~ ,' ~ul~er ~imu~ti°n ug ~mi~' W-15 ~ 7~ 51 4 1~ X OTIS L 6 9 :~ sat sssv 9-~-94 Z-05 T 711~ 0 3 I~X AXELSON L 7 12 te~~15~4 FL ~T K-VALVE ~ Wa~i~ ~ ~Us for k-va~o .... R-12 ~ 7/24~1 1990 78 2~,,C OTIS L 29 400 tentset~vg-18-~ Z~7a ~ 7/24~ 21 4 1~ X 0TIS L 6 20 t~ ~et ;ssv 9-~.~ F~ ~T ' 4" C~ ~ down for g~e ~ well ~nla~ing J-28 ~ ,, 2200 64 5 1~ C AxELSON H 5 e tent set sssv9.20.~ FI ~, IT 4" C~ up ~mi ~ag ~ffa ..... ~;17 GL 8/~4 1990 68 4 lA X AXELSON' L 18 36 ranl set sssv 9-20.~ FL ~T ~. 3" FMO up ~,d~ I~1~ an~ gl ~rA · ~94 1760 67 31~X BAKER L NO]ES.' 5-112"O & 4-1/2" - CAMCO FLAPPERS ALL OTI Ir'R,9. OTIEI Ball Vulvu- (l.~. B & G Lines are in ~;ernmur'AT, aliOh} X ~ A~C W~r ~ ha~ ~5V ~t (~-~rm SJ wall} · · GgV ~T~L UNE ~NI~ INST~LED ~L · ~N~S ~L LINES EOS - CMCRGENOY ~SlNa SLIPS ~RLOT: D- Du~ N~ Press L- Low Pass REVISED: 9/4f94 (*H25: 5~9/94 ) DB - DRILLBY FAG - FAC&I'IY Gl. · GAS UFT C,__~)R - HIGH GA,.e.e.e.e.e.e.e.e.e2OIL RATIO MEG -. MECHANICAL FAILUI::~= PE - PROD ENGINEER Pt, LOW PI RCKS-~ S.~Z- SQUEEZE wa- WATER ~IJT '° CHECK H25 BEFORE WORKING ON WEll_ ANY WELLS ABOVE 20 PPM REQUIRE A SNIFF PRIOR TO COMMENCING, OPEPA TtON$. STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSIC~--' ' REPORT (.,.' SUNDRY WELL OPE,.ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 947' SNL, 1287' WEL, SEC 19, T11N, R12E At top of productive interval 2612'NSL, 810' WEL, SEC 14, T11N, R11E At effective depth 2528'SNL, 1091' WEL, SEC 14, T11N, R11E At total depth 2765' SNL, 1458' WEL, SEC 14, T11N, R11E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13174' feet Plugs (measured) 9110' feet 13133' feet Junk (measured) 9089' feet Casing Length Size Cemented Structural -- Conductor 110 20x30 280 c.f. Arcticset Surface 2706 13-3/8 3806 cuft Permafrost Intermediate 10252 9-5/8 365 cuft Class "G" Production -- Liner 3041 7" 209 cu ft Class "G" Perforation depth: measured 12904'- 12924', 12930'- 12950' true vertical subsea 8967' - 8978', 8981'- 8992' Tubing (size, grade, and measured depth) 4-1/2" 13CR @ 12068' Packers and SSSV (type and measured depth) TlWpacker @ 12008' SSSV @ 2102' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 6. Datum elevation (DF or KB) KBE= 88.62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-O7A (42-14-11-11) 9. Permit number/approval number ¢,.~-//,¢-9(~-a¢-- / 10. APl number 50- 029-22046-01 11. Field/Pool Prudhoe Oil Pool Measured depth 144 2740 10286 True vertical depth BKB 144 2740 7510 10133-13174 7418-9117 R£C£1V£D JUL 3 1994 on,-,. I~nne P. nrn~iSsiOl~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1170 ~.~ 689 12 1065 1231 1237 0 250 Tubing Pressure 255 264 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foreg~ng is true and correct to the best of my knowledge. Signed ~'~/tct4~ ~x::v,~ ~ ~ o,~ O¢~ Title Senior TechnicalAssistant, Form 10-404' Rev 06/15/88 f Date SUBMIT IN DU'PLI(~ATE 10/14/93 11/12/93 WELL Z-07A(42-14-11-11) Addperf/Hydraulic Fracture The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 12766'-12805MD Performed a Hydraulic Fracture using the following fluids: FRAC TREATMENT FLUIDS PUMPED DOWNHOLE INJ TEST: 349 Bbls 20# Gel 103 bbls1% HCL w/inhibitor DATA FRAC: 591 bbls FI{AC: 875 bbls LOAD VOLUME: 1918 (TOTAL FLUIDS PUMPED DOWN HOLE) 200 Diesel to IAand GC fjh 7/11/94 RECEIVED JUL. '~ 3 199,1 hJaska 0il & Gas Cons. [;ommission Anchorage This is to acknowledge _eceipt of the following pz±nts and negatives. COMPANY: STATE OF ALASKA-OIL & GAS CONSERVATION COMMISSION ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY & ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA Q-03 PLS (LEAK ~~) ~, 1%~ -- ~7 1 K-08 PLS L~AK- D~ECT 5,, ~OO 3 ~O Y-37 SBT-GR-CCL ~ ~0~U0~ [0~Z 1 Y-37 PFC/CC5 (~F] 1 ~O - ~0%77 . '?ECE!VEi '~chorage S I GNED ~- DATE Please return one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT~RTN~i No. 8272 SCHLUMBERGER GEOQUEST INTERPRETATION AND COMPUTING SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY : LOCATION : ATTENTION : WELL NAME : SERVICES NO. OF BOXES: JOB NO. : ADD'L TAPES : STATE'iOF ALASKA ALAsr,,A O~L & GAS COiiSERVATiONDpdMM..~'r. 3001 PORCUPINE DR. LARRY GRANT Z-07A WELL NAME · I 0H"LIS TAPE~.E.bdC,~ SERVICES · I NO. OF BOXES: 93434 JOB NO. · --- ADD'L TAPES · NOVEMBER 15, 1993 WELL NAME · SERVICES · WELL NAME ' SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · NO. OF BOXES: JOB NO. · ADD'L TAPES ' WELL NAME ' SERVICES · NO. OF BOXES: JOB NO. ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: WELL NAME SERVICES NO. OF BOXES: JOB NO. · ADD'L TAPES · /vO 7 a -', ,,rOgo -'"' ..... STATE OF ALASKA ALASKA ,...,- AND GAS CONSERVATION CO,~,MISSION WELL COMPLETION OR RECOMP L£TION 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 93-110 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50-029-22046-01 4. Location of well at surface .- .' 9. Unit or Lease Name ~ ~.C,C^ i~,~ ~ ~ i Prudhoe Bay Unit 974'SNL, 1287'EWL, SEC. 19, T11N, R12E7_~ """~"'"i 10. Well Number At Top Producing Interval ~ I ...... l: V~ ~l J ~ J"¥~L~ i 2612'NSL, 810' WEL, SEC. 14, T11N, R11E : ~ .~:'~,..4~.~ ~,, ...... ~..,..,.~,.;..;. Prudhoe Bay Field/Prudhoe Bay Pool 2765' NSL, 1128' WEL, SEC. 14, T11N, R11E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 88. 62' I ADL 28245 12. Date Spudded 13. Da:teT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 9/5/93 9/13/93 9/27/93I IN/A feet MSL One 13174'MD/9110' TVD 15133' MD/9089' TVD ~ !~1 ~o [] 2102'feet ~D l~O0' (Approx.) 2?.. Type Eloctric or Othor Lo~s Run DLI_/BHCS/GR/SP, CNL/GR 23. CASING, LINER AND CEMENTING REC, OF~ SE'FFf,~ DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEM~ RECORD AMOUNT PULLED 20" Insulated conductor Surface 110' 30" 280 cu ft Arcticset (Approx) 13-3/8" 681/ L-80 Surface 2740' 17-172" 3806 cuft Permafrost 9-5/8" 47t/ NT80-S Surface 10286' 12-1/4" 365 cu ft Class "G" 7" 291/ L-80 10133' 13174' 8-1/2" 209 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBI',IG RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MDI Gun Diameter3-3/8" 4 spf 4-1/2", 13CR 12068' 12008' MD TVD 12904'-12924' 8967'-8978' 12930'-12950' 8981 '-8992' 26. ACID, FRACTURE, CEMENTSQUFFTF. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 9/28/93 J Gas Lift Date of Test Hours Tested PRODUCTION FOR OlL-BBL ,.~AS-MCF WATER-BBL CHOKESIZ~ IGAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL !GAS-MCF !WATER-BBL :)IL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brier description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. - GEOLOGIC MARKERS F~',-.MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Eileen Sand 12696' 8764' Top Sadlerochit 12757' 8797' 'OWC 13038' 8952' 31. LIST OF A'I-rACHMENTS 32. I herebyce.~t tl!e foregoil~g is t~rect tothe best of my knowledgel '~ F ~ Signed._) - ~lu~. . tie Drillino EnoineerSuoervisor Date-,,j~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~ E C E IV E ~} Item 28: If no cores taken, indicate "none". Form 10-407 c)OT ! 5 199: ~,laska u~l ~, ~as bo~ls, uu~i~rniss~u" Anchorage ow/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: Z-07A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 56-029-22046 PERMIT: APPROVAL: ACCEPT: 08/31/93 04:00 SPUD: 09/05/93 03:30 RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 14 08/31/93 (1) TD: 0 PB: 0 PULL BPV TO DISPL DIESEL TAKE ON SEAWATER. RU & PULL BPV. MW: 8.5 Seawater 09/01/93 (2) TD:13143 PB:12110 09/02/93 (3) TD:13143 PB:12110 POOH W/ TBG. MW: 8.5 Seawater CIRC OUT DIESEL. CIRC. N/D TREE. N/U BOPE. TEST BOPE. OK. PULL TBG. CIRC. POOH W/ TBG, CNTRL LINES. POOH W/ TBG. RIH. MW: 8.5 Seawater POOH W/ 4-1/2" TBG. TEST BOPE. RIH W/ BAKER RET. 09/03/93 (4) TD:13143 PB:12110 09/04/93 (5) TD:10336 PB: 0 09/05/93 (6) TD:10296' (10296) 09/06/93 (7) TD:10703' ( 407) 09/07/93 (8) TD:l1044' ( 341) 09/08/93 (9) TD:l1761' ( 717) CUT SECTION. MW:10.2 WBM RIH W/ BP TO 10500' SET BP @ 10498'. TEST CSG. OK. DISP WELL TO MILLIN~ FLUID. POOH. RIH W/ SECTION MILL TO 10286'. MILL SETION F/ 10286'. SQZ CMT K/O PLUG. MW:10.2 WBM MILL SECTION F/ 10312'-10336'. CIRC. POOH. CIRC. POOH. RIH. REV CIRC. PUMP 20 BBLS WATER, 170 SX (29.7 BBLS) CMT. DISP W/ MUD. POOH 10 STDS. SQZ CMT W/ 2000 PSI. KICK OFF 8-1/2" HOLE. MW:10.2 VIS: 86 POOH. TEST BOPE. RIH W/ DRLG BHA #1. WASH F/ 10086'-10232' NO FIRM CMT. WOC. REAM CMT F/ 10232'-10288' KICKOFF WELL @ 03:30 HRS, 9/5/93. DRLG F/ 10288'-11295' DRLG. MW:10.0 VIS: 50 DRLG F/ 10295'-10388'. DISP WELL TO KCL-POLY MUD. REAM TO BTM. DRLG F/ 10388'-10703'. DRLG. MW:10.0 VIS: 60 DRLG F/ 10703'-10891'. CIRC. POOH TO SHOE. CIRC. POOH. CHANGE MWD TOOL, BIT. RIH. REAM F/ 10850'-BTM. DRLG F/ 10891'-11044'. DRLG. MW:10.1 VIS: 65 DRLG F/ 11044'-11604'. SHORT TRIP TO SHOE. DRLG F/ 11604'-11761'. · ~LL : Z-07A O~ERATION: RIG : DOYON 14 PAGE: 2 09/09/93 (10) TD:12478' ( 717) 09/10/93 (11) TD:12698' ( 220) 09/11/93 (12) TD:12810' ( 112) 09/12/93 (13) TD:13106' ( 296) 09/13/93 (14) TD:13135' ( 29) 09/14/93 (15) TD:13174' ( 39) 09/15/93 (16) TD:13174 PB: 0 09/16/93 (17) TD:13174 PB: 0 09/17/93 (18) TD:13174 PB: 0 09/18/93 (19) TD:13174 PB:13133 DRLG. MW:10.1 VIS: 82 DRLG F/ 11761'-12011' CBU. SHORT TRIP TO SHOE. DRLG F/ 12011'-12478'. POOH. MW:10.2 VIS: 60 DRLG F/ 12478'-12541'. CBU. WIPER TRIP. DRLG F/ 12541'-12698' CBU. POOH. DRLG. MW:10.2 VIS: 57 CHANGE BHA. TEST BOPE. RIH. REAM F/ 12645'-12698' F/ 12698'-12810' DRLG POOH. MW:10.5 VIS: 61 DRLG F/ 12810'-12988'. CIRC. DRLG F/ 12988'-13106'. CBU. POOH. DRLG. MW:10.5 VIS: 85 POOH. CIRC. POOH. CIRC. POOH. CHANGE BIT. RIH. REAM F/ 12989'-13106'. DRLG F/ 13106'-13135'. POOH. MW:10.5 VIS: 62 DRLG F/ 13135'-13174'. TD WELL @ 11:00 HRS, 9/13/93. CIRC. SHORT TRIP TO SHOE. WORK THRU TIGHT SPOTS. RIH. CIRC. POOH. MAD PASS W/ ANADRILL. MW:10.6 WBM POOH. R/U ATLAS. LOG RUN: DLL/BHCS/GR/SP. STOPPED @ 10550'. POOH. L/D AC LOG TOOL. RIH. LOG STOPPED. POOH. LOG RUN: CN/GR. R/D ATLAS. P/U ANADRILL LWD TOOL. MAD LOG RUN RUN 7" LNR. MW:10.5 WBM MAD PASS W/ ANADRILL LWD TOOL F/ 12850'-13174'. POOH TO SHOE. CBU. POOH. L/D LWD TOOL. L/D BHA. RIH W/ 7" L-80 LNR. TEST CSG. MW:10.6 WBM RIH W/ 7" L-80 LNR, BAKER HGR, LNR TOP PKR ON DP. CIRC. RIH W/ 7" LNR. CIRC. PUMP 25 BBLS ARCO PREFLUSH, 75 BBLS ARCO SPACER, 177 SX (275 CU FT) 'G' CMT. DISP W/ MUD. BUMP PLUGGED, SET PKR, HGR W/ 4000 PSI. RELEASE F/ HGR. CBU. POOH. TEST CSG, LNR. L/D DP. MW: 8.4 Seawater RIH W/ BHA. TAG CMT @ 13100'. REV CIRC. CLEAN OUT CMT F/ 13100'-13133'. REV CIRC. POOH. L/D DP. 09/19/93 (20) TD:13174 PB:13133 RUN TBG. MW: 8.4 Seawater L/D DP, BHA. R/U WOTCO. RIH W/ 4-1/2" 13 CR TBG. RECEIVED · &laska bil ~ L:,;.JS bUit~ ,..,~,,, Anchora~ge v~LL : Z-07A OPERATION: RIG : DOYON 14 PAGE: 3 09/20/93 (21) TD:13174 PB:13133 RIG RELEASED. MW: 8.4 Seawater RIH W/ COMP ASS'Y. TBG TAIL @ 12068' SABL-3 PKR @ 12008'. SSSV @ 2102'. DISP WELL W/ SEAWATER. N/D BOPE. N/U TREE. TEST TREE. OK. SET BAKER PKR W/ 4000 PSI. TEST ANNULUS. OK. SHEAR RP VALVE. PUMP 140 BBLS DIESEL F/P. RIG RELEASED @ 24:00 HRS, 9/19/93. SIGNATURE: (drilling superintendent) DATE: RECEiVing Anchorage PRUDHOE BAY PBU/Z-O7A 500292204601 NORTH SLOPE COHPUTATION ,c?~ERRY-SUN DRILLING SERVICE? ANCHORAGE ALASKA PAGE DRILLING DATE' 9/21/93 DATE OF SURVEY' 091093 MWD SURVEY JOB NUMBER' AK-MW-30065 KELLY BUSHING ELEV. = 88.62 FT. OPERATOR' BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES VERT. NORTH/SOUTH EAST/WEST SECT. 10286 7511.95 7423.33 48 45 N 58.93 W .00 10472 7631.00 7542.38 51 42 N 65.00 W 2,97 10535 7670.61 7581.99 50 24 N 68.00 W 4,24 10598 7711.10 7622.48 49 35 N 68,20 W 1,29 10692 7771.71 7683.09 50 5 N 71.20 W 2.50 2795.22N 5489.14W 6158.82 2862,20N 5615.27W 6301.54 2881.74N 5660,19W 6350.48 2899.75N 5704.97W 6398.63 2924.66N 5772.33W 6470.10 10723 7791.11 7702,49 52 24 N 70.10 W 7.92 10786 7828.67 7740.05 54 24 N 71,30 W 3,52 10818 7846,89 7758.27 56 12 N 72.40 W 6.29 10911 7897.67 7809.05 57 35 N 70,80 W 2.08 11004 7947.50 7858,88 57 35 N 70.80 W .00 2932.67N 5795.14W 6494.11 2949.38N 5842.86W 5544.34 2957.57N 5867,86W 6570.40 2982.16N 5941.77W 6647.63 3007.99N 6015.92W 6725.61 11097 7997.33 7908.71 57 35 N 70,80 W .00 11191 8047.63 7959,01 57 42 N 71.00 W .21 11284 8096.98 8008,36 58 12 N 69.90 W 1.14 11377 8145.71 8057.09 58 35 N 69.40 W .63 11470 8194.38 8105.75 58 17 N 68.20 W 1,15 3033.81N 6090.08W 6803.59 3059.79N 6165.12W 6882.44 3086.17N 6239.40W 6960.77 3113.72N 6313.66W 7039.60 3142.37N 6387.55W 7118.58 11563 8243.66 8155.04 57 42 N 67.10 W 1.19 11657 8294.92 8206,30 56 12 N 66,89 W 1.61 11751 8347,00 8258.38 56 30 N 68.20 W 1.20 11844 8398.06 8309.44 56 54 N 66.10 W 1.94 11938 8449.47 8360,85 56 47 N 66.10 W .11 3172,36N 6460.49~ 7197,29 3203.15N 6533.00W 7275.97 3233.03N 6605.32W 7354.07 3263.22N 6676,93W 7431,68 3295.10N 6748.89W 7510.33 12032 8500.80 8412.18 57 0 N 65.70 W .42 12125 8551.32 8462.70 57 12 N 65.90 W .28 12219 8602,10 8513.48 57 24 N 65.00 W .83 12310 8650.99 8562.37 57 35 N 65.40 W .43 12405 8701.83 8613.21 57 42 N 64.50 W .81 3327.25N 6820.77W 7589.03 3359,26N 6891.99W 7667.08 3392.13N 6963.94W 7746.16 3424.32N 7033.61W 7822.89 3458.30N 7106.31W 7903.13 12468 12499 12593 12625 12698 8735.35 8751.80 8801.75 8818.76 8857.55 THE CALCULATION PROCEDURES ARE BASED ON 3~ THREE-DIMENSION MINIMUH CURVATURE METHOD. 8646.73 58 0 N 64.60 W .49 3481,22N 7154,48W 8663.18 57 54 N 65.40 W 2.21 3492,33N 7178.29W 8713.13 57 54 N 64,50 W ,81 3526,04N 7250.43W 8730.14 57 54 N 64.30 W .53 ¢~3537,75N ~7274.87W 8768.93 57 54 N 64,30 W O0 3564 57N %~7330 60W /7~ USE OF 7956.47 7982.74 8062.36 8089.47 8151,31 HORIZONTAL DISPLACEMENT = 8151.31 FEET AT NORTH 64 DEG. 4 MIN. WEST AT ND = 12698 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COFdPUTED ALONG 295.93 DEG. Anchorage -' ~ PAGE 2 PRUDHOE BAY PBU/Z-OTA 500292204601 NORTH SLOPE CONPUTATION "'~'"~RRY-SUN DRILLING SERVTCE~ ANCHORAGE ALASKA DRILLING DATE OF SURVEY: 091093 DATE: 9/21/93 JOB NUHBER: AK-HW-30065 KELLY BUSHING ELEV. = 88.62 OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH TRUE SUB-SEA NEASD VERT]:CAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST HD-TVD VERTICAL DIFFERENCE CORRECTION 10286 7511.95 7423.33 2795.22 N 5489.14 11286 8098.04 8009.42 3086.76 N 6240.99 12286 8638.13 8549.51 3415.88 N 7015.18 12698 8857.55 8768.93 3564.57 N 7330.60 2774.05 3187.96 413.91 3647.87 459.90 3840.45 192.58 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DINENSION NINZMUH CURVATURE HETHOD, FT. RECE VE Alaska Oil & Gas C;ons. Oommissior~ Anchorag6 PRUDHOE BAY PBU/Z-O7A 500292204601 NORTH SLOPE CONPUTATZON F ....RRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PAGE DRZLLZNG DATE OF SURVEY" 091093 DATE' 9/21/93 JOB NUHBER' AK-HW-30065 KELLY BUSHZNG ELEV. = 88.62 OPERATOR' BP EXPLORATZON FT. ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA NEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST ND-TVD VERTZCAL DZFFERENCE CORRECTZON 10286 7511.95 7423.33 10404 7588.62 7500.00 10563 7688.62 7600.00 10718 7788,62 7700,00 2795.22 N 5489.14 W 2774.05 2839.09 N 5568.03 W 2815.83 41.78 2889.90 N 5680.38 W 2874.63 58.80 2931,59 N 5792.12 W 2930.32 55.68 10894 7888.62 7800.00 11080 7988.62 7900,00 11268 8088.62 8000.00 11459 8188.62 8100.00 11645 8288.62 8200.00 2977,47 N 5928.30 W 3005.49 75.17 3029,29 N 6077.11 W 3092.12 86.63 3081,54 N 6226,73 W 3179.51 87.39 3138,91 N 6378,89 W 3270,43 90,92 3199,46 N 6524.35 W 3357.06 86,63 11826 8388.62 8300.00 12009 8488.62 8400.00 12193 8588.62 8500.00 12380 8688.62 8600.00 12568 8788,62 8700.00 12698 8857.55 8768.93 H~¢HE CALCULATZON THE NEAREST 3257.35 N 6663.69 W 3438.09 81.03 3319.54 N 6803,67 W 3521.02 82.93 3383,22 N 6944,84 W 3605,36 84.35 3449,31 N 7087,46 W 3691,67 86.30 3517,03 N 7231.53 W 3779,67 88.00 1 3564.57 ~ 7330.60 W 3840.45 60.78 PROCEDURES USE A LTNEAR TNTERPOLATTON BETWEEN 20 FOOT I'4D (FROM f4TNTHUM CURVATURE) POTNTS RECEIVED E SIGN ONE COPY AND RETUi ATLAS WIRELINE SERVICES Pouch 340013 Prudhoe Bay, AK 99734 .'O: This is to acknowledge receipt of the-following prints and negatives. COMPANY: STATE OF ALASKA ATTENT I ON: LARRY GRkNT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA c-o3 p C£PERF)/C J-- I°__ J- 06 PLS 1 0 1 I~-- I~qO 1 0 1 l J-08 PLS(LEAK DETQ ~t, ~-- ~qO 0 1 J-08 GR/CCL OEWELRY) S" 1 10~-- [~O 1 J- 17 PLS %O~ - ~OETO 1 0 P- 09 PAS ~LEAK DET) 5 ~' 1 ~ -- ,~_ 1 ~'~ 1 0 1 Q-04 CN/GR S - 24 PLS ~ 50- (~ 1 0 1 Z-07 A SBT/GR/~U ~,, Il ! ~O ~ I~1 0 1 FORMTO0 L k RTNCARD DATE This is to acknowledge receipt of the following prints and negatives. COMPANY: STATE OF ALASKA - ALASKA OIL & GAS COMMISSION ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA X-22 DILF/GR 2~' 1 0 1 , X- 22 BHC/AC-GR 1 0 1 [X-22 WATER SATURATION ~,, 1 '~qO[f-- ~%~3q~0 1 ~_~ S-36 I PFC/CCL(PERF) ~,~ 1 ~_ q%LO0 1 Please return one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT~RTNCARD1 F LSE SIGN ONE COPY AND RETI' TO: ATLAS WIRELINE SERVICES Pouch 340013 Prudhoe Bay, AK 99734 This is to acknowledge receipt of the following prints and negatives. COMPANY: STATE OF ALASKA OIL & GAS CONSERVATION COMM. ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA A-18 A PFC~PERF) G~Cr4- 5" c~[~O0 __1 ~~ 0 1 E-03 PLS ~,, ~~~ ~85 O. 1 S-!8 PLS ~,, ~0%00 3 105~ 0 1 P-09 PLS~LEAK DET~ a" %%0o ~ %1~O 0 1 R-24 PFC~ERF)GR/~ 5" ~ ~ ~q~ 0 1 W-07 PDK-100 SR[ u 5,, 0 Z-07 A PFC~PERF)G~ 5" 1%a~ ~%q~[ 0 1 Y-36 BHC/AC GR a~" ~[o~--1 ~%o~5 0 1 CN/GR g~" %[0~~ ~~ 0 1 WATER SA~TION ~'~ 1 ~{~- ~ 0 1 FORMTOOLIRTNCARD DATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 10/4/93 T~ 85082 BPX/PBU~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 09/28/93 91 09/28/93 #1 09/27/93 91 09/27/93 #1 09/26/93 %1 09/26/93 #1 10700.00-11568.00 ATLAS 5 " 10250.00-11102.00 ATLAS 5 " 9650.00-10301.00 ATLAS 5 " 9900.00-10301.00 ATLAS 5 " 12788.00-13000.00 ATLAS 5 " 11850.00-13102.00 ATLAS 5 " Information Control Well Records ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 October 1993 RE: Transmittal of Data ECC #: 6042.00 Data: CN/GR Dear Sir/Madam, Reference: BP Z-07A NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 Sent by U.S. MAIL CN/GR LDWG TAPE+LIST Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 .Anchorage, AK 99518 Attn. Rodney D. Paulson Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 October 1993 RE: Transmittal of Data ECC #: 6042.02 Data: NONE Dear Sir/Madam, Reference: BP Z-07A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 Sent by U.S. MAIL GR/CCL LDWG TAPE+LST Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/22/93 T# 85046 BPX/PBU~OG Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. q~O Z-07A- CNL/~ 09/14/93 #1 9000.00- 9600.00 ATLAS 2/5" Information Control Well Records t?£CEIvEb OCT 0 4 199,~ Alaska 0il & Gas Cons. C°mmissioll Anchorage SCHLUMBERGER WELL SERVICES A DIVIS,_,~I OF SCHLUMBERGER TECHNOLOGY CO[', ,RATION HOUSTON, TEXAS 77251-2175 Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley BP Exploration 900 E. Benson Blvd. Anchorage, AK 99519-6612 Attention: Petrotechnical Data Center, MB 3-3 Gentlemen: Enclosed are2 BL prints of the DITE/BHC, Run 1, 8/28/93 Company BP Exploration Well X-21 Field Prudhoe Bay Additional prints are being sent to: 3 BL prints, 1 RRolled Sepia ARCO Alaska, Inc. AT0-1529 P. O, Box 100360 Anchorage, AK 99510-0360 Attn: Prudhoe Records Clerk on' County North Slope State' Alaska 1BL prints Mobil Oil Company 12450 Greenspoint Drive Houston, TX 77060 Attn: Barbara Sullivan, Suite 550B /I BL mrints, 1 RFolded Sepia ~iask~ Oil & Gas Con~er~vation Commission ~\ AnchoraKe, AK 99501 ~ x'--~n: ~arry GrantJ Exxon Company, U.S.A. 800 Bell Street, Suite 3083 Houston, TX 77252 Attn: Susa~ Nisbett. 1BL prints Chevron U.S.A., Inc. Technical Information Services P. O. Box 1635 Houston, TX 77251 Attn-: Okay-Cha Sea ~prints Texaco, Inc, P. O. Box 46555 Denver, CO 80201-6555 JIO - Attn: .R, W, Hill 1BL prints Phillips Petroleum .Company P. O. Box 1967 Houston: TX 77251-1967 Attn~ Mnn~cn Warnken: Room B-2 The film is returned to BP. We appreciate the privilege of serving you. SWS-- 1327.F OH (1 iBL/1RF/1RR) Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John, DATE: Chairman ~ THRU: Blair Wondzell, .4~__~_~;,. FILE NO: P. I. Supervisor FROM: Bobby Foster, SUBJECT: Petroleum Inspector September 1, 1993 AIGIIAAC.doc BOP Test - Doyon 14 BPX - PBU - Z - 07A PTD#93-110 PB Field Wednesday, September 1, 1993: ! traveled to Doyon rig 14 on BPX's Z - 07A and witnessed the initial BOP test. As the attached BOPE TEST REPORT shows there was one failure. The HCR valve on the choke line failed. It was replaced and tested OK. Summary: ! witnessed the BOPE test on Doyon 14 - test time 2.5 hours - one failure. Attachment: AIGllAAC.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drtg: EDRII_ Workover: ..... Drlg Contractor: J~o ~/e n/ Rig No. ___.-_ Operator: ' BPX Well Name: Z- 07A Casing Size: g 5/8 Set ~ I0.500 Test: Initial X Weekly Other DATE: 9/1/93 14 PTD# g3 - 110 Rig Ph.# 659-4510 , , , , Rep.: DON WESTER Rig Rep.: MARK EGHOLM Location: Sec. 19 T, 11N R. 12E Meridian U MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK" (Gen) Drl. Rig OK Reserve Pit N Test Quan. Pressure I 30012500 BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve 3OO 15OOO P/F P P p, P , P i ! , I 30O15000 I 300 ~ 5000 1 3 2 3 MUD SYSTEM: ~ual Alarm Trip Tank YES YES Pit Level Indicators i y~$ , ~:S Flow Indicator YES Y~.$' Gas Detectors YES YES' FLOOR SAFETY VALVES: Ouan. Pressure Upper Kelly /IBOP 1 ! 300 ~ 5000 Lower Kelly / IBOP , I I t 5, . , Ball Type I I Inside BOP · I 5 P/F P P P ,, CHOKE MANIFOLD: No. Valves 14 No. Flanges ",,34,. Manual Chokes f Hydraulic Chokes Test Pressure 300 ~ 5000 30015000 Functioned Funclioned P/F P P P P . . ACCUMULATOR SYSTEM: System Pressure 2,950 J P Pressure After Closure 1,500 ! ,,P, 200 psi Attained After Closure 0 minutes 34 System Pressure Attained 2 minutes 58 Blind Switch Covers: Master: YES Remote: ~ , Nitgn. Btl's: 4 ~ 2100 Psig. sec. sec. YES Number of Failures: I ,Test Time: 2.5 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within O. 5 day~i Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax N 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 I I I I_ I ! I I II I I IF I . I II r II I' I , II II I II I I I I I I I IIII REMARKS: The choke line HCR valve failed - replaced and tested OK. Distribution: orig-Wetl File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED7 YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: v~.r~essed By: FI-021L (Rev. 7/93) AtGIIAAC.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION August 11, 1993 M. E. Miller Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Prudhoe Bay Unit Z-07A BP Exploration (Alaska), Inc. Permit No: 93-110 Sur. Loc. 4306'NSL, 3667'WEL, Sec. 19, TllN, R12E, UM Btmhole Loc. 2729'NSL, 969'WEL, Sec. 14, TllN, RllE, UM Dear Mr.Miller: 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. 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. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures , I cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. printed on recycled paper b y G D ~'--- STATE OF ALASKA ALASKA .~,L AND GAS CONSERVATION CL,,.,,vllSSION PERMIT TO DRILL 20 AAC 25.005 a. Type of work Drill [] RedrillElllb. Type of well. Exploratory Fi Stratigraphic Test [] Development Oil[] Re-Entry [] Deepenl-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator BP Exploration 3. Address P. O. Box 196612. Anchorage. Alaska 99519-6612 4. Location of well at surface 4306'NSL, 3667' WEL, SEC. 19, T11N, R12E At top of productive interval 2624' NSL, 729' WEL, SEC. 14, T11N, R11E At total depth 2729' NSL, 969' WEL, SEC. 14, T11N, R11E 12. Distance to nearest 113. Distance to nearest well property line I ADL feet No close approach feet 16. To be completed for deviated wells Kickoff depth ~o3oo feet Maximum hole angles-~.~ o 18. Casing program size Hole Casing 8-1/2" 7" 5. Datum Elevation (DF or KB) KBE = 80.02' feet 6. Property Designation ADL 28245 7. Unit or property Name Prudhoe Bay Unit 8. Well number Z-O7A (42-14-11-11) 9. Approximate spud date 8/2O/93 4. Number of acres in property 2560 O. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool Specifications W2e;ht NG rT~; Coupling NSCC ILength 2893' Top MD I 'I-VD 10150' 7422' 11. Type Bond(~,, 20 ,&AC 25.025) Number 2S100302630-277 Amount $200,000.00 5. Proposed depth (MD and TVD) 13043' MD 9126' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum sudace 33'30 pslg At total depth (TVD) ~0Q'/'z~,.,qg0 pslg Setting Depth Bottom TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13143 feet Plugs (measured) true vertical MD 13043' 9126' 473 sx Class "G" Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation 'depth: Quantity of cement (include stage data) measured true vertical Length Junk (measured) ..'~Jask;~ Oil & Cemented Measured depth True Ve~ical depth 9331 feet 13023 feet 9251 feet Size 110' 20" 110' 110' 2740' 13-3/8" 3806 cu ft PF 2740' 2645' 12189' 9-5/8" 2740 cu fl "G" 12189' 8698' 1225' 7". 365 cu ft "G" 11917'-13142' 8522'-9331' measured 12458'-12474', 12494'-12532', 12548'-12634', 12649'-12674' true vertical 8874'-8885'~ 8898'-8923', 8934'-8991', 9001'-9017' 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 requirementsl-] 21. i herel~y certify that the foregoing is true and correct to the best of my knowledge ' ~[~;~---"--____.~ Title Drillin~ Engineer Supervisor Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~'3-//',,/C~ 150-0.2..~--~-.~,.C) ~'~-~ _/ I ~:~-/,/ "' ~-.~ Ifor other requirements Conditions of approval Samples required [] Yes ~ No Mud log required []Yes J~ No Hydrogen sulfide measures [] Yes ,E~ NO Directional survey requ~reo J~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; ~5M; F'IIOM; [-]15M; Other: by order of me commission I i ,/I Approved by Original Signed By David W. Johnston Commissioner Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: I Z-07A Redrill Plan Summary Type of Redrill (producer or injector): i PRODUCER Surface Location: Target Location: Bottom Hole Location: 4306 FSL 3667 FEL S 19 T11N R12E UM 2624 FSL 729 FEL S 14 T11N R11E UM 2729 FSL 969 FEL S 14 T11N R11E UM I AFE Number: [4P8008 I I Estimated Start Date: [ 20AUG93 [ IMD: I 13,04Y ] [TVD: I Well Design (conventional, slimhole, etc.): [Rig: [DOYON RIG #14 ] Operating days to complete: [ 12 19,126' I [K BE: I !80.°2' ! [CONVENTIONAL [Objective: [ SADLEROCHIT Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. Special design considerations NONE Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 10 0 5 tO tO tO tO tO tO tO tO tO TD' 10.0 18 30 15 30 5 0 8 Directional: I KOP: [ 10,300'MD/7,517'TVD Maximum Hole Angle: [ 53.5° Close Approach Well: [ NONE The above listed wells will be secured during the close approach. Z-07A Sidetrack Plan Summary Casin,,/Tubin, ' Pro~ ram: Wt/Ft Hole Siz~ Csg/ ~'Wt/Ft~ Grade Conn Length Top Btm Tb[~ O.D. MD/TVD MD/TVD 8-1/2" 7" 29#/FT NT-80 NSCC 2893' 10150'/7422' 13,043'/9,126' Cement Calculations: I Liner Size: 17" Basis:I 50~o open hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above linei' with DP. Total Cement Volume: 473 sxs of Class G Blend @ 1.18 ft3/sx I Liner Size: BaSis:1 50~o open hole ex~ess, 40' shoe joint, 150' liner lap and 150' excess above line[' with DP'.' Total Cement Volume: sxs of Class G Blend @ 1.18 ft3/sx Well Control: .- Well control equipment consisting of 5000 psi W.P. pipe rams, blind shear rams, and annular preveater will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Z-07A Sidetrack Plan Summary PRbOHOE BAY DRILL_LNG ~l~,oo~c~ ,o..~o ~ ~, ~.~,~ VERTICAL SECTION VIEW ,, D) TO 13043 9126 839t 54.21 ~Section at' 293.80 :TVD Sca]~.' ~ ir)ch = ~500 feet <KB> o,- Dep Scale.' ~ inch = ~500 feet I I i Drawn ' 06/24/93 750 ............... ~ ~ ~' ~pPSt ~BRU ~jPSCtjOROj ~Pjj]jR~, ,, ..... . 2~so .... i ~ i I . 3000--, ... . ~ , '- ~7S0--- 4500 I ~ ..... , s:'~o ~ ---~ .... I --- '~2~ r~.7~~ - ~7 .............................. ' 0500 ~-- 0 750 1500 2~50 3000 3750 4500 5~50 6000 575o 7500 ~250 ~000 9750 Section Debenture STATE OF ALASKA ALAS,,~ OIL AND GAS CONSERVATION COMMISSIL,,. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend__ Alter casing ~ Repair well ~ Change approved program ~ 2. Name of Operator BP Exp/oration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 974' SNL, 3991' WEL, SEC. 19, T11N, R12E At top of productive interval 2514' SNL, 305' WEI_, SEC. 14, T11N, RI 1E At effective depth Operation Shutdown ~ Re-enter suspended well~ Plugging X Time extension ~ Stimulate ~ Pulltubin Variance~ Perforate~ Other X Plugback for redrlll 5. Type of Well: 6. Datum elevation (DF or KB) KBE=91.81' feet Development X Exploratory ~ Stra~graphic ~ Service At total depth 2202' SNL, 728' WEL, SEC. 14, T11N, R11E J U L 0 199 Alaska 0il & Gas Cons. CommisSiOn Anchorage 12. Present well condition summary Total depth: measured true vertical 13143 feet Plugs (measured) 9331 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-07(42-14-11-11) 9. Permit number 90-57 10. APl number 50- 029-22046 11. Field/Pool Prudhoe Bay Field~Oil Pool Effective depth: measured 13023 feet Junk (measured) true vertical 9251 feet Casing Length Size Cemented Measured depth Structural Conductor 110' 20" 110' Surface 2740' 13-3/8" 3806 cu ft Permafrost 2740' Intermediate 12189' 9-5/8" 2740 cuft Class "G" 12189' Production 1225' 7" 365 cu ft Class "G" 11917'-13142' Liner Perforation depth: measured 12458'-12474, 12494'-12532', 12548'-12634', 12649'-12674' True verticalde~h 110' 2645' 8698' 8522~ 9331' true vertical 8874'-8885', 8898'-8923', 8934'-8991', 9001'-9017' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 12547'MD Packers and SSSV (type and measured depth) 9-5/8" 'HBBP-R'packer @ 11887' MD; Camco SSSV @ 2104' 13. Attachments Description summary of proposal x . Detailed operations program BOP sketch 14. Estimated date for commencing operation 8/5/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended~ Service 17. I hereby c~ertify that the foregoing is true and correct to the best of my knowledge. Signed '~/'~ !/~ ~_. ~ ~_.....) Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity // BOP Test ~ Location clearance~ Mechanical Integrity Test~ Subsequent form required 10-. Original Sl~jned By Approved by order of the Commission )Da¥1~ W, Johnstor) J Approval No. Approvl~d Returned ... ~mmissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN I'I~IPLICATE ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Loc ~.'~r .~/(~?~ [2 thru 8v][ ' (3) Admin [.4¢,~,- ~/?/'~L~, '[§ thru -1'3]' [10 & 13] (4) Casg x~ ~/~ [14 thru 22 [23 thru 2~] (5) BOPE [29 thru 31] (6) Other (7) Contact [32] (8) Addl _ geology' engineering' DW RPC~J~ MTM -- BEW~JDN~ ~, rev 6/93 jo/6.011 .1. 2. 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES Is permit fee attached ......................................... ' ..... .~ Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ .... Does operator have a bond in force ................................... ~. Is a conservation order needed ....................................... ~t~ Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... ~ Does well have a unique name & n~nber ................................ ~L Is conductor string provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ xJqk Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ,~ Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Lease & Wel 1 NO ' R~"O, RKS ' 29. 30. 31. 32. 33. FOR EXPLORATORY g STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL I UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' MERIDIAN' UM X SM WELL TYPE' Exp/e~~' Inj Red ri 11 )q~ Rev o -4 -rz ~-~o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: 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 Z-07A 500292204601 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 06-OCT-93 6042.00 R. ECK R. KALISH 19 liN 12E 974 3991 92.16 90.66 54.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 12189.0 PRODUCTION STRING 8.500 13174.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS 2435 GRCH 1 5 14-SEP-93 ATLAS WIRELINE SERVICES LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN/GR Cased Hole. 47.00 CN LOGGING PARMS: SANDSTONE MATRIX CHISM ACTIVE CALIPER CORRECTION = 12.250" CASING THICKNESS = 0.472" CEMENT THICKNESS = 1.313" SALINTY = 0.000 PPK CIRCULATION STOPPED @ 24:00 13-SEP-93. COULD NOT GET PAST 10853' IN OPEN HOLE SECTION. OPEN HOLE SECTION NOT LOGGED. COMPENSATED NEUTRON LOGGED IN 9 5/8" CASING. THIS IS THE ONLY WIRELINE LOGS IN THIS SECTION OF THE WELL AND AS SUCH IS THE DEPTH REFERENCE. THERE ARE NO SHIFTS DONE TO ANY OF THE DATA. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2435 $ START DEPTH STOP DEPTH 8963.0 9606.0 8970.0 9612.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: 0 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: MAIN PASS DATA. NO SHIFTS WERE APPLIED. $ CN : BP EXPLORATION WN : Z - 07A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TENS 2435 68 1 LB 4 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 32 Tape File Start Depth = 9625.000000 Tape File End Depth = 8960.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7987 datums Tape Subfile: 2 130 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8963.0 2435 8970.0 $ LOG HEADER DATA STOP DEPTH 9612.0 9619.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CN COMPENSATED NEUTRON PCM PULSE CODE MODULATOR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-SEP-93 FSYS REV. J001 VER. 1.1 1539 14-SEP-93 13174.0 0.0 9000.0 9600.0 1800.0 YES TOOL NUMBER 1309XA 2435XA 3506XA 8.500 12189.0 0.0 KCL BIOZAN 10.50 62.0 158.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 70 NEAR COUNT RATE HIGH SCALE (CPS): 570 TOOL STANDOFF (IN) : 0.0 REMARKS: MAIN PASS DATA. LOG HEADING INFO: DENSITY = 10.5 PPG VISCOSITY = 62 SEC/QT PH = 9.0 METER FLUID LOSS = 7.0 CC RM @ MT = .231 OHMM @ 62 DEGF RMF @ MT = .184 OHMM @ 56 DEGF RMC @ MT = .463 OHMM @ 50 DEGF SOURCE OF RMF/RMC = MEASURED/MEASURED RM @ BHT = 0.091 @ 158 DEGF MAX TEMP = 158 DEGF $ CN : BP EXPLORATION WN : Z - 07A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CCL 2435 68 1 4 3 CN 2435 68 1 PU-L 4 4 CNC 2435 68 1 PU-S 4 5 CNCF 2435 68 1 PU-S 4 6 LSN 2435 68 1 CPS 4 7 SSN 2435 68 1 CPS 4 8 SPD 2435 68 1 F/MN 4 9 TEN 2435 68 1 LB 4 10 TTEN 2435 68 1 LB 4 4 08 501 10 0 4 90 640 78 6 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 19 912 29 5 4 19 912 29 5 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 119 Tape File Start Depth = 9626.000000 Ta~e File End Depth = 8946.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29932 datums Tape Subfile: 3 203 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9187.0 2435 9193.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9614.0 9620.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CN COMPENSATED NEUTRON PCM PULSE CODE MODULATOR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : 14-SEP-93 FSYS REV. J001 VER. 1.1 1522 14-SEP-93 13174.0 0.0 9000.0 9600.0 1800.0 YES TOOL NUMBER 1309XA 2435XA 3506XA 8.500 12189.0 0.0 KCL BIOZAN 10.50 62.0 158.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 70 NEAR COUNT RATE HIGH SCALE (CPS): 570 TOOL STANDOFF (IN): 0.0 REMARKS: REPEAT PASS DATA. $ CN : BP EXPLORATION WN : Z - 07A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CCL 2435 68 1 4 3 CN 2435 68 1 PU-L 4 4 CNC 2435 68 1 PU-S 4 5 CNCF 2435 68 1 PU-S 4 6 LSN 2435 68 1 CPS 4 7 SSN 2435 68 1 CPS 4 8 SPD 2435 68 1 F/MN 4 9 TEN 2435 68 1 LB 4 10 TTEN 2435 68 1 LB 4 4 08 501 10 0 4 90 640 78 6 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 19 912 29 5 4 19 912 29 5 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 81 Tape File Start Depth = 9628.000000 Tape File End Depth = 9164.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28415 datums Ta~e Su'Ibfile: 4 Minimum record length: Maximum record length: 155 records... 62 bytes 1018 bytes Tape Subfile 5 is type: LIS 93/10/ 6 01 **** REEL TRAILER **** 93/10/ 6 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 6 OCT 93 5:22p Elapsed execution time = 20.27 seconds. SYSTEM RETURN CODE = 0 * ALASKA CONPUTING CMNTER * * , ****************************** ****************************** COMPANY N~NE : BR MXPLORATIO~ WELL M~E : Z- O7A FIELD MA~E : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE ~ ALASKA AP! NU~EER : 50-029-2~046-0! PEFEREMCE NO : 93434 RECEIVED Nas~ Oil & Gas Cons. Commission '._~chorage TaPe vertf~cat.ion i.,istino ~ch].tlmberger ~ilas~a Computin~ Center 12-~0V-1993 !8:26 $~RVICE NA~E : EDIT D~TE : 93/1~/!2 O~IGIN : FLIC ~EEL NA~E : 93434 CONTINUATION ~ : P~EVIOUS REEL : CO~ENT : BP EXPLORATtO~.,PRUDMOE BAY, Z-O7A,50-029-2~046-O~ **** TAPE HEADER SERVICE NAME : EDIT DATE : 9.3/1l/!2 O~i~!N : FLIC T~P~ NA~E : 93434 CONTINUATION # : I CO~ENT : BP E×PLORATIO~,,PRUDHOE T~PE HEADER PnUDHOE B~Y ~D,/~.AD bOGS OPERATOR: T~P~ CRE~T!O~ DATE: OOB D~TA JOB ~U~BER: OPERATOR WITNESS: SUR~CE LOC~T!O~ SECTIOn: R~NGE: FSL: KLEVATIO~(FT F~[]~ ~SL O) KELLY BUSHING: 9ERRIC~ ?bO0~: GROUND LEVEL: ~ELL CASI'~G ~ECORn IST STRI~'G 2ND STR!~G 93434 J.~CKSO~ BIT RUN 2 BIT RUg 3 12[< 4306 3667 92.16 (~ 66 t]PEN HOLE CASING DRILLEkS PIT SIZF (I,M) SIZE (IN) DEPT~ (FI) ~ ~00 · 10 6.n PAGE: ~I$ Ta~e Vert.,ficatlon List!nO ;chlu~berqerAlaska Co~,.',ut:ln~ Center PRODUCTIO!!~ STR I!~G ~EM~RK$: WASHDO~N FRO~ 127~4 TO 13169 BIT T[3 ~:~::U:57.25 DEN:50,31' WELL TD ~T J.!:00 ON $3-SEP93 W~SgDO':~:~J ST.tRTf::D AT 0400 ON 15-SKP-93 DO>~IOLK SO~TW{~E v4.0C LIS FGR~AT DATA PAGE~ FILE NAif: : EDIT ,001 SERVICE : FLIC VERSION : 00!C0! DAT~ : ~X REC SIZ~ : 1,024 FIbF TYPE : LO L~$T KILE : EDITED MERGED ~WD ~epth shifted and clipped curves; all bit runs merged, DEPTH INC~K~EMT: 0.5000 # LDWG TOOL B.~SKLINE CURVE FOR S~[FTS: GR C~JRVE Sg!FT oa'ra (~%:a~S~Et) DEPTH) START DEPT~{ ~2700.o J~089.0 ~3075.5 ~9~7.5 ~976.0 J2970,5 J29~9 0 STOP DEPTH 13~69,0 !3~69,0 13091.0 !307q,0 13066.0 !301.8,0 13002,0 129g~.0 ~2980.0 12975.0 ~.2953.5 12940.0 Tape Verification Listing ~chlumberg~r Alaska Comouti:no Center 1.2-NOV-19g3 I8:26 !2921.5 ~28~4,5 ~286g,0 ~2~51,0 .,.2~2!.0 1278'7.0 ~2757.o 2699,5 ~69~.0 NERGED DATA SOURCE LDWG TOOL CODM R~M~RKS: 12926,0 12898.5 12888.5 !2873.5 t~854,5 !2827,0 12793,0 ~2763,0 12704,0 12699,0 ~0~.0 THai DMPTH ADJU$.TMfINTS SHOWN ABOVE REFLECT FWD/MAD GR TO CASE[.) HOLE WlREbI~E GR OF 26-8EP-93, ORO PPOCESSMD D~TA I8 INCLUDED, ALL OTHEP CURVES WERE CARRIE[) WITH THE GR SHIFT' UNS~!~T..:D D~TA iS IN FILF P, TABLE TYPE : CONS C~ ~P MXP!~O~ATION ~'N PRUDHOE BAY WN Z - 07A APlN 50-029-22046-0! FI, 4306' FSL & 3667' FEL $~CT TnWN lin R~NG !2E' COUN ~n~TH SLOP~ NaTI USA PDAT ~EAN SEA LEVEL EPD ~T O, L~F APO ~T 92,16 EKB FT 92,!6 EDF FT 90,66 EGL PT 57.0e001 TOD PT ] 3169, TDL FT !3160, BLI ~T !3169, TL! PT 12065, DFD G/C3 10,5 Company Name Fiei, d ~ame Well Name ~Pl Serial Number Field Location Section Township RanGe County State or Province NatioD Permanent datum Elevation of Permanent Datom Log Measured From AbOve Permanent Datum Elevation of Kelly 8ushi.~ Elevation of Derric~ Eloor Elevatio~ of Ground Level Total Depth -Drlller Total Depth - Logger Bottom [,o~ Interval To~.l,o~ Iflt. erval ~riAli~g Fluid Density .~,IS TaDe Yeri. flcatlon ;chlumberoer Alaska Computin~ Center I.~-NOV-!993 !8:26 PAGEI 4 P~S O~M~ 0 282 Reslstivltv of ~ud Sample ~sT DEGF 7~ Mud..Sa~ple~Te~Perature R~:FS OH~ 0 ~05 Re$!Stivtt~ O~ MUd Filtrate S MPST ~EGF 7£~ ~ud Filtrate Sample Temperatu BHT UMGF 15~, BottOm HOle Temperature- T~,~t'_,E TYPE : CURV ~RP? Demth RMOB Bulk Density DPHn Delta RHO PMF PhotoElectric Factor CaLN Dlf~erentlai Caliper HA. RGS BHC ATTEN[ji~TIOM R,,.~S~'.,:TIVITYS RP RGS BEC PHASE SHIFT RESISTIVITY DER DIELECTRIC RE&TSIT!VTY V~P QRO VERy ENHANCED PHASE RESISITIVTY VRA OHO VERY ENHANCED A~PSITUDE ~ESISTIVITY HOP ~ATE OF PEMETRAT!O~ NCNT ~V'ERAGE ~m:a,, ~ELIUN ......... CO{}NT ~ATE FCNT AVERAGE FAR HE COUNT RATE ** DaTa FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64gE ** TYPE 2 66 3 73 64 4 66 5 66 7 65 ~ 6~ 0,5 9 65 FT 1~ 66 16 1~ 6~ 13 66 !4 65 15 66 68 ;cblumbero. er Alaska ComPutiDO Center !2-~0V-1993 18:26 PAGE: ** SET T~P~ - C~N ** NAME SERV IINIT SERVICE APl PI A I AA· P P O~p~ FT O0 000 O0 0 RHOB ~WD G/C3 00 000 00 0 D~HO .WO G/C3 O0 o00 O0 0 PRF ~Wg Ss/K O0 000 00 0 C~LN ~WD IN 00 00O 00 0 NPHI ~O Pl)-S O0 000 00 0 R~ ~Wm OU~ 00 000 00 0 RP ~WD OH~ 00 000 O0 0 D~R ~WO O~u O0 000 O0 0 VRP MWO OHM~ On O00 O0 0 VRA ~WD O}~MM 00 000 00 0 ROD ~WD F'PHR 00 O00 00 O Gn ~WD GAPI O0 O00 O0 0 ~CNT ~wO CPS O0 OOO 00 0 FCNT MWD CPS O0 000 00 0 GRC~ AWS G~PI o0 000 00 0 I I I 4 68 0000000000 I ! 1 4 68 0000000000 1 1 I 4 68 0000000000 ! I I 4 68 0000000000 1 1 1 4 68 0000000000 ! I ! 4 68 0000000000 ! l ! 4 68 0000000000 i ! ! 4 68 0000000000 1 ! t 4 68 0000000000 I ! ! 4 68 0000000000 I 1 ! 4 68 0000000000 I 1 I 4 68 0000000000 I I l 4 68 0000000000 ! 1 1 4 68 0000000000 1 1 t 4 68 0000000000 t 1 I 4 68 0000000000 ** 0aTa ** DEPT, 13170,500 RHOB,MWD -999,250 CALN,MWD -999,250 NPHi,NWO -999.250 DEO,~WD -999.250 V~p.~WD -999,~50 GR,~WD -999,250 NCNT,~W[) '999.250 DEPT 13100.000 R~OB,~WD 2.4bl CaLN:~wo 0,15o NPWI,MWD 13.300 .... , ~ . .. 5.805 nE~,~WP 6 00~ V..P Gq.~WD 35.4~0 NCNT,~WD 409,083 DEPT. 13000.000 RMOB.MWD 2.347 CALN.MWD 0.044 NPHI.NWO 23.!20 DE~,~W? 3.050 VpP,~WD 2,692 G~,~WD 36.609 NCNT,~WD 345,867 DEPT 12900,000 RttOB ~<WD .9... 541 CALNi~WD O.IR~ ~,,PHI:~%,,D 20:177 OEP, ~wn b. 278 VRP, ~I') 6.573 GP.~D 49.707 NCNT.MWD 377.375 DRNO.MND -999.250 PEF,MWD ~A.MWD -999.250 RP.~WD VR~.~WD -999,250 ROP,MWD FCNT,MWD -999.250 GRC~.AW$ OPHO.MWD 0,053 PEF.M~D RA.MWD 6.324 RP.~D VRA.MWD 5.853 ROP,~WD FCNT.MWD !8.713 GRC~,AWS D~H!').MWD 0.021 PEF,MWD RA.MWD 4,461 RP,~WD VRA.MWD 3.736 POP.~WD FCNT,~WD !0,734 GRCH.AWS OPHO.~WD 0.029 PEF MWD ~A.MWO 8.093 RP$~WD VNA.~WD 12.188 ROP.~WD FCN'T,N~WD 13,088 GRCHoAWS -999,250 -999,250 53,254 -999,250 53 097 3.331 2,771 59,598 14.952 3,529 5,695 58,934 17,949 !IS Tare VerifY. cation Listi. n~ ;chlumherger Al. asEa Compt:ltiD~ Center DEPT. 12700.000 RHoB.MWD CAIiN.~.WD 0.2.89 NPgI.t~wD D~'R. 4~D -999 250 VPP. ~WD ,WE 70.047 NCNT. t.~WD GR. PET 1~600.000 .;: ,.,P .., CALN MWD -999.250 DE~' MWD -999. 250 VRP. -9 9. 250 DEPT. 12500.000 RMUB.MWD CALN'~WD -999.250 NPH!.HWD D~R.MWD -999,250 YRP,~WD G~.MWD -999,250 NCMT,~WD DEPT. 12400.000 ~HO~.M~D CRLN.~WD -999.250 ~PHI.~WD DER.~WD -999.250 VRP.~WD GP.MWD -999.250 NCNT.MWD DEPT. 12200.()00 C~bN.MWD -999,250 NPHI.~WD .~D -999. 250 VRP. GP: MWD -999. 250 NCNT. DEPT. 12000.000 RHOB.UWD CaLN.~WD -999.250 NPHI.~WD GP.~WO -999.259 NCNT.~WD DEPT. 11900.009 PHO~.MWrl) C~i,N.MWI~ -999.250 NPNI.MWD DE~.~wD -999.250 VPP.~WD GR.~WD -999.250 NCNT.~WD 12'NOV-!993 !8:26 520 R A, q W F) '999,250 VRA,MWD 381.953 FCNT.MWD '999.250 DRHf],MWD -999.~50 R~.MWD -999.250 VRA.MWD -999,250 FCNT,MWD -999.250 DRHO.:,:;.ND -999.250 PA.MWD -999.250 VRA.MWD -999.250 FCNT.MWD -999.250 DRFO.MWD -999.250 R~.MWD -999.250 VRA.~WD -999.250 FCNT.~WD 558 0 0 999 250 13.896 -999 250 - 99: 5o -999,250 -999'250 - 99 9 250 -999:250 -999 250 -999:250 -999. 250 -999. ~50 2999~50 999~R50 -999 250 -9992~50 -999. -999,250 -999. 250 -999 .~50 - 99.' 5o -999,250 -999,250 DPNO.MWO -999 250 -999,250 Ra.v~wo -999:250 -999. 250 V~ A. MWD -999. 250 -999.250 FCNT.MW[) -999.250 -999.250 D~H(J.MWD -999.250 -999.250 VRA.MWD -999.~50 FCNT.MWD 2999.250 999.250 -999.250 -999.250 -999.250 DP, NC'].:4WD :~99 ~50 -99~.2.50 ' ' ~,MWD -=99:250 -999.250 VRA.~.IWD -999.250 -990. 250 FCNT. ~WD -9gg. ~50 DEPT. 11845.009 R!iO~.!~WD i999.250 DPHO.MWD -999.250 C~LN.~WD -999.250 WP~I.~Wr) -999.250 R~.~WD -999.250 DEP.UWD -999.250 VRP.M~D -999.~50 VPA.MWD -999.250 GP.MwD -999,~50 bfCMT.~.!WD -990.250 FCNT,M~D -999.250 PEF.~WD RP.MWD ROP.~WD GRCH.AWS PEF, ~WD ROP' . ~WD GRCN. PEF.MWD RP.~WD ROP,MWD GRCH,AWS PE~.MWD PEF.~WD ~P.~WD ROP.~WD GRCM.AWS RP ~WD GRCH.AWS PEF.~WD ~.P, ~WD GRC~.AW$ PEF.~WD .uwO ROP.~WD <;RCH..A%~8 PEF.MwD RP.~WD ROP.~WD GRCH.AW$ PEP.EWE RP.~WD ROP.MWD GRCM.AW$ PEF.MWD RP,~WD ~OP,~WD GRCM,AWS 54,639 16,851 4.691 -999 ' 250 999 ,, 2:50 39 '.001 -999 250 "999i250 -999 250 53 214 '999. 250 "999:"250 '999. 250 20,384 .'999 250 999:250 -999,250 6 2. ! 6 7 -999.250 -999' 250 -999.2'50 -99~ 250 -999.~50 57.007 -999.250 -999.250 -999.250 7~.~0 -999.250 -999.250 -999.250 54.437 -999.250 -999.250 -999.250 46.566 -999,250 -999,250 -999.250 0,000 ils TaPe Verification Listing ~chlumberger AlasKa ComDutiDg Center PAGE: ** ENO O? DAT~ **** F'IbE TRAILER FII~E NAgE : EDiT ,001 S~RVICE : FLIC VERSION : 00!COI DATE : 93111112 ~AX R~C $IZ~ : 1024 FILE TYPE ! bO bAST FILE **** FILE HEADER **** SERVICE : FL!C VERSION : 001C01 DATM : 93/!I/12 ~A× REC SIZE FTLE TYPE bAST FILE FIbK HEADER KIbE NL!NBER 2 RAW MAD Curves ~d loq header dat~ for each bit ru~ i~ separate B~T ~UN NU~BEP: 1 DKPTN INCRKMENT! 0.5000 FIL~ SUH~ARY LDWG TOOL CODE STANT DEPTH C~N 1 . ,0 COR ~.2700.0 I, OG HEADER DATA DATE SOFTWARE: SUPFACE SUFT~ARE DnWNHObE SOFT~RM VERSION: DATA TOP LOG I~TEPVAb (MT): mOTTO~ LOG IWTERVAL (MT): ~IT ~OTATING NOLE !NCL!M~TIO~ M?NTUU~ STt}P DEPTH !31.60.0 ].3160,0 14-SEP-9] v4,0C 13169.0 13169.0 fiies. 'IS Te~e Verification bi. stino SchlumberGer Alaska Computing Center 12-NOV-1993:18:26 PAGE{ TOOL STPlMG (TOP T[~ ~OTTOM) VESDD~ TOOl, CODE TO(IL TYPE ........... . ..... ~ ...... . . , ~'~ R I ~T I¥ t T Y CDN NEt]TRON/PDR0$IT¥ $ B[]~EHOLE AMD CASING DATA DRILLERS C~SING DEPTH (FT): TO£}L NUMBER ND$063 BO~EHO[.~E CONDIT!Ot~S ~UD TYPE: ~UD DENSITY (LB/G): ~{UD V'ISC(]SITY (S) MUD ~D C~bORIDES (PP~): ..'~" tIRE MAXI~ [I~ RECORDED RESIStIVItY (nH~) AT TEMPERATURE (DEGF): ~!JD AT ~EASURED TE~pERAT[IRE ~!UD AT ~X CIRCULRTI~;G TEMPERAT!,.iP~; ~UD FILTRATE AT NEUTRON TDOL aATRIX: aATRIX DENSITY: aObE CORRECTION (IN): # TOOL STANDOFF 8.500 !85,0 0,305 0.000 SANDSTONE 2.65 WASHDOWN F~O~ 12724, TO 13169 BIT TI] RE$:23.38' GR:33,80 BIT TO gE]U:57,25' DE~:50,31' ~ELL TD .AT il:On O~ 13-SEPg] W.~S~DOwa STARTF]D IT 0400 ON 1,5-SEP-g3 DATA FPO~ I)OWNHObF[ ~EMO~Y [>OWNHOLE SOFTWarE v4.0C S [,IS FO~T DATA 70,0 70.0 0.0 TABLF TYPE : CONS TUN! VA[,U DEF! . ........................................... ......... ................... . ........ .................... CN BP ExPLOTONaA I Company. Name F~ PRi.;DEOE BAY Field ~ame W~ Z - 07A well Name APIN 50-029-22046-01 API Serial Number FI., 4306' FSL & 3667' FEL Field Location Tape Verification Listi. ng ;Chlu~berger Alaska ComDutin~ Center 12-N~V-1993 18:26 TU~! VALU DEFI S~CT ~9 TOW~ ll~q COUN NORTH L~F RKB APD FT EKB FT 9~, ! 6 ED~ FT 90,66 EGL FT 57,0600! TDD FT ~ 3 ~ 69 TDL FT 13169 BLI FT 13169~ TLI FT DFD G/C3 10,5 Section Township Range, County State or Province Nation Per~anent datum Elevation of Per~ane~t Datum Log ~easured From Above Per~anent Datum Elevation of Kelly BUShing Elevation o~ De,ricK Floor Elevation of Ground ~eve! Total Depth - Driller Total Depth - Logger Bottom Log Interval opLog Interval tilling PlUld Dens~ty Resistivity of ~ud Sample ~ud Sample Temperature Resi. stlvit of MUd Filtrate ~ud Fl, ltra~e Sample Temperatu Bottom }{ole Temperature TABLE TYPE : Ct!aY DEFX D~PT Depth R~O~ BUlk Density Porosity DPH? Densit~H0 DRHO Delta PKF ~hotoElectric Factor DCAL Dl. fferential Caliper TNP~ Thermal Neutron Porosit v ATR RGS BHC ~TTENUATIOM RESISTIVITY PSP RGS B~!C PH~$~ SHIFT RESISTIVITY D~R DIELECTRIC RKSISITIVTy ROP~ PATE OF PE~jTRATION G~ Gam~a may i.,IS Tape Verification Listing .~chlumberoer AlasKa ComD,,lting Center' I~-NOV-1993 !8:26 PAGE: DATA FORMAT SPECIFICATION PECORD ** ** SET TYPE - 64EB ** TYPE ~ 66 0 2 66 0 66 7 65 8 68 0,5 !! 66 !2 68 t] 66 0 !4 65 FT 15 66 68 I6 66 0 66 ** MET TYPE - CHAN ** N'AMF~ SERV UNIT S~]~VTCF ~PI API ADI API FILE M{JMO Mi]MB SIZE REPR PROCESS ID O~DE~ ~ LOG TYPE CLASS MOD NUmB SAMP ELEM .CODE (HEX) wT O0 000 O0 0 2 I 1 4 68 0000000000 RNOP LWl G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 DPg~ LWl PU O0 000 O0 0 2 ! I 4 68 0000000000 D~iO t,W!. G/C] O0 000 O0 0 2 1 1 4 68 0000000000 P~F I, W1 [.~!/~ O0 000 On 0 2 ! ! 4 68 0000000000 OC.~I, LW! IN OO 000 00 O 2 1 ! 4 68 0000000000 TNPN LW! PU O0 000 OO O 2 ! 1 4 68 0000000000 AT~ [.,Wl ON~I~ O0 000 00 n 2 1 ! 4 68 0000000000 .~ L~ nO 000 O0 0 2 ! I 4 68 0000000000 P,_R .... I OFI~ ........ D~R t,w! OH~ O0 000 O0 0 2 ! I 4. 68 0000000000 ROPK Lw1 F/H~ O0 000 00 0 ~ 1 1 4 68 0000000000 G~ LW1 GAPI 00 000 OO O 2 1 ~ 4 68 0000000000 H~N~ LwI CPS O0 000 O0 0 2 1 I 4 68 0000000000 HF~ LW! CPS oo 00o O0 0 2 1 1 4 6~ 0000000000 t0 ** DATA, ** -999.250 -999.250 -999.~50 .~IS Ta~>e veri...flcati, on LiSt!hq ;c:hlu~BerOer Alaska ComputSnq Center D.EPT. t]000.000 PHOB.LW1 PEF.LWI 3.6~B DCAb. LW! HEUa.LW1 35~.000 HEFA.LWl DEPT. 12900.000 R~OB Lhl PEF.I,~i 3.481 DCAL~LWI oSg.Lwl 4.195 DER LWI HENa. LW1 350.3]3 DEBT 12800.000 ~HOB.LWI ' 1 D ' I.,Wl PEF.[,W 3;231 CAb. . PS~.LW! 7.435 DE~.LW! D~PT, 1.2700,000 RHOB.LWl PEF,LWl 4.218 DCAL,LWl PS~. LW! -999. 250 OER. LWI HEN~. L:W{. 37.4.917 F{EFA.LWl DEPT, 12666,000 RHOB,LWl PEF,LWl -999,~50 DCAL,LW1 PSR.,LW1 -999.250 DER,LWI B~NA.LW1 -999.250 ~EF~.LNI 2.516 DPHI.LW1 0.19! T~PH.LW! 5.8!2 ROPE.LWt 17.8.25 0. ! 1'2 TNPH.LW! !~,489 ROPg.bWl '2. 390 DPHI.LWl 0,1.39 T~.~PH'LWI 4 5BI. ROPg.hWl 10'6501. 2.408 DPHI,BWl 0.051 TNPH.BW! 8.151 ROP~.bWt 13.050 2.643 DPHI,LWl 0.~90 TNPH..bW1 -999. 50 Ri]BE'Dwi i3,644 -999 250 DP~4I.LW! -999~250 TNPh'bWI -990.250 ROPE.LW! 10.525 8.100 14.000 52.633 13 50 0 o: oo 60. 000 1,5. 800 24 :! 00 591800 14.700 1.9,700 54.878 0.400 I7.200 -999.250 999i250 999 250 999 250 D~HO L~.! ATR,LWl GR.LWl DRHO,LWI ATR,LW! GR,Lwl P R H O. L ~ I A. TR. LW 1 DRH. O. [,W I ATR .LWl GR.LWl DRHO. ATR.,LWl "GR'LWl DRHO. bW 1 ATR. LWI GR.. !.,W ! PAGE: !I 0,050 6.03@ 37. 439 0,0 33 087 0.014 8'119 34,962 01.025 10.778 35,019 0'.039 -999'250 87..471 -999.250 -999 250 -9991250 FILF NA~iE : EDIT ,002 SERVICE : rL!C VERSION ! 00tC01 DATF : 93111112 ~AX AEC SIZE : 1024 FIL~ TYPE : LO **** TAPE TRAILEN **** SFRVICE NA~P : EDIT D~TF : 03111112 OPI~!N : FL!C T~P~ NA~E : 93434 CONTINUATIO~ ~ : ! P~EVIOUS TAPE : COMUENT = BP EXPbORAT!r]~.,PRUOHOE gA.Y, Z-07A,50-O29-22046-01 ,!$ Tame verlficat,.~on b~ist.f, nq ;chlumberger A. laska Computing Center 12-N0¥-!993 10:~6 PAGE: **** RMEb T~ILER **** S~RVIC~ M~E : EDIT DATM OPI~!~ : FLIC REEL NA~E : 93434 CONTINUATION # PREVIOUS REML COMMENT : BP ~×PLOR~TiOM,,PRUO[~OE Z-O7A,50-029-22046-OI