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201-103
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT G-14 JBR 05/14/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 2 7/8" Test Joint, FP on Pipe Rams (changed out). Precharge Bottles = 5@1000psi, 3@1050psi and 4@1100psi. Test Results TEST DATA Rig Rep:J.WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:M. Heinz-Brown Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2011330 DATE:4/26/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopBDB250427132245 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 8 MASP: 975 Sundry No: 325-225 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 2 7/8" x 5"FP #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/6"P HCR Valves 1 2 1/6"P Kill Line Valves 3 2 1/6"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2900 Pressure After Closure P1650 200 PSI Attained P16 Full Pressure Attained P53 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2363 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P8 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 99 9999 9 9 FP on Pipe Rams #1 Rams 2 7/8" x 5"FP RECEIVED STATE OF ALASKA MAR 12 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO)GCC la. Well Status 0 Oil ❑Gas ❑SPLUG 0 Other ®Abandoned ❑Suspended 1 b. Well Class 20AAC 25105 20AAC 25110 0 Exploratory 0 Stratigraphic 0 GINJ ❑WINJ ❑WAG ❑WDSPL 0 Other No.of Completions Zero ® Development ❑ Service 2. Operator Name: 5. Date Comp., Susp.,(-Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 2/20/2015 201-103 . 315-008 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage, Alaska 99519-6612 10/2/2001 50-029-20694-01-00 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number. Surface: 10/10/2001 PBU D-18A 1990' FNL, 1692' FEL, Sec.23, T11N, R13E, UM 8. KB(ft above MSL): 73.11' , 15. Field/Pool(s) Top of Productive Horizon: 2389' FNL, 804' FEL, Sec.22, T11N, R13E, UM GL(ft above MSL): 41.66' - Prudhoe Bay/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) 2354' FNL, 904' FEL, Sec. 22, T11N, R13E, UM 10255'- 8589' . 4b. Location of Well(State Base Plane Coordinates,NAD. 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 653469 • y- 5958998- Zone- ASP4 10895' . 9191' - _ ADL 028285&028284 TPI: x- 649086 y- 5958511 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:>:- 648986 y- 5958544 Zone- ASP4 None - 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): 18. Directional Survey: ❑Yes ® No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD, GR, RES, PWD, DEN, NEU, CBL 8027' - 6682' • 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20"x 30" Insulated Conductor_ 39' _ 119' 39' _ 119' , 36" _8 cu yds Concrete 13-3/8" 72# L-80 38' 2679' 38' 2679' 17-1/2" 3490 cu ft Permafrost II 9-5/8" 47# L-80 36' 8027' 36' 6682' 12-1/4" 1462 cu ft Class'G', 130 cu ft PF'C' 7-5/8" 29.7# L-80 2503' 8027' 2503' _ 6682' N/A _640 cu ft Class'G' 5-1/2" 17# L-80 7841' 10205' 6559' 8543' _ 6-3/4" 151 cu ft Class'G' 3-1/2" 9.2# L-80/13Cr80 10024' 10895' 8375' 9191' 4-3/4" 112 cu ft Class'G' 24. Open to production or injection'? ❑Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD (MD+TVD of Top&Bottom; Perforation Size and Number): ) _-, - -1 4-1/2", 12.6#, 13Cr80 10029' 9973'/8329' x 3-1/2", 9.2#, 9Cr80 '-7-1Z4.8526. ACID, FRACTURE,CEMENT SQUEEZE, ETC. 11 VE t 1 WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No SUMO APR V 2015 :. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10255' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 4 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No Sidewall Core(s)Acquired'? ❑Yes ® No If Yes to either question, list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 CONTINUED ON REVERSE RBDRASAk MAR 1 6 2219mit Original Only VU- 3//1/" 4440*r Lt.< 7. / \/CI 29. GEOLOGIC MARKERS(List all formations r iarkers encounter 30 FORMATION TESTS NAME .AD ND Well Tested? 0 Yes 0 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 10215' 8552' None Shublik A 10248' 8583' Shublik B 10270' 8603' Shublik C 10298' 8630' Sadlerochit-Zone 4 10311' 8642' Zone 3 10496' 8816' Zone 2C 10587' 8902' Zone 2B 10659' 8970' HOT 10721' 9028' Zone 2A 10752' 9057' Zone 1B 10790' 9093' 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: Nancy Hibbert 64-5535 Email: Nancy.Hibbert@bp.com Printed Name Joe Lastufk Title: Drilling Technologist Signature. k4161._, Phone 564 4091 Date 3�81.�15 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only D-18A, Well History (Pre-Rig Sidetrack) Date Summary 01/11/15 DRIFT W/3.81" CENT, 3'x1-3/4" STEM&3.84"CENT,TAG TOP OF PATCH @ 2079' SLM PULL BKR 45 KB PACKER FROM 2079' SLM/2106'MD. PULL PRONG FROM PX-PLUG BODY @ 9961'SLM. 01/12/15 PULL 3-1/2" PX PLUG BODY FROM 10,017'MD. DRIFT W/20'x2.70" DMY WHIPSTOCK, TAG BTM @ 10,742' SLM. 01/20/15 T/I/0= 750/250/0 Temp= SI ( Load and Secure) Pumped 5 bbls MEOH followed by 260 bbls 1%KCL then spaced 3 bbls MEOH &capped with 42 bbls diesel for FP. FWHP's=97/93/12 DSO notified upon departure of SWV,SSV=S/I IAV,OAV=OTG E-line moving on well. 01/20/15 INITIAL T/I/0=0/80/0. LRS PERFORMED L&K ON TBG W/FRZ PROTECT. RIH W/BAKER 3.5" KB PACKER WHIPSTOCK SET TOP OF WHIPSTOCK @10260' (1.5 DEG ROHS ORIENTATION) (TWO RA PIP TAGS INSTALLED 5.0' FROM TOP OF WHIPSTOCK PUTTING THEM @ 10265') TIED INTO SLB RST LOG DATED 08/NOV/2001. FINIAL T/I/O =0/80/0. WELL LEFT SHUT IN UPON DEPARTURE- NOTIFIED PAD OP OF WELL STATUS. LRS ON LOCATION TO PERFORM CMIT. 01/20/15 T/I/O=0/0/5 Temp=S/I Assist E-Line ( Pre CTD) RU to TBG and PT. 01/21/15 T/I/O=0/0/5 Temp=SI,Assist E-Line (Pre CTD)***CMIT TxIA @ 2400 psi***PASS"** Pump 53.57 bbls of diesel down TBG to achieve test pressure. 1st 15 min loss of 53&56 TxIA, 2nd 15 loss of 18& 18 TxIA for a total of 71 &74. Bled 4.14 bbls diesel back to reach FWHP of 300 psi. Hung tags Notify WSL& Pad-Op, SV, WV, SSV,ALV=Closed. MV=Open IA, OA=OTG FWHP=294/266/7 Well shut in upon departure. 02/05/15 T/I/0=400/400/0 Temp=Sl Circ-Out(Pre CTD) Pump 10 bbls meth, 175 bbls diesel down IA to circ-out, taking returns up TBG and FL. Pumped 7 bbls Neat McOH 60 bbls Dead Crude and 12 bbls Diesel down F/L to freeze protect. Well S/I notified Pad op upon departure. IA fluid packed with Diesel.AFE sign hung on master fluid packed annuls tags hung on IA and wing. Fluid packed IA notated on permit FWHP = 250/250/0. SV/WV/SSV= C. MV=). IA/OA= OTG. 02/15/15 SET 4-1/2"WHIDDON C. SUB (#45) ON XO @ 7708' SLM (7739' MD). PULL BK-DGLV FROM ST#3 @ 6636'SLM (6661' MD). SET BEK-CIRC VALVE IN ST#3 @ 6636' SLM (6661' MD). PULL WHIDDON C. SUB FROM 7708' SLM (7739' MD). 02/16/15 T/I/O = SSV/490/0. Temp = SI. Bleed TP & IAP to 0 psi (pre CTD). Well house and all lines removed. No scaffolding, cannot reach tree-cap to verify TP. Bled IAP to 0 psi in 30 min (2.5 bbls). Monitored for 30 min, WHPs unchanged. Final WHPs = SSV/0/0. SV, WV=?. MV= 0. SSV= C. IA, OA= OTG. 11:30 hrs. 02/16/15 T/I/O= 500/500/0 , Conduct PJSM w/crew, Pre Nordic test spool#6 install and IA piggy back#67 , RDMO Final T/I/O=500/500/0. 02/17/15 T/I/O =SSV/0+/0+. Temp= SI.WHP's(pre rig). No wellhouse, scaffold, or flowline. SV=?. WV= Blinded. SSV=Closed. MV= Open. IA&OA=OTG. NOVP. 01:50. Page 1 of 1 North America-ALASKA-BP Page 1.g.01D' Operation Summary Report Common Well Name:D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 • Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292069400 Active datum:73.11 @73.11usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/16/2015 00:00 - 05:00 5.00 MOB P PRE CONTINUE TO PREP FOR RIG MOVE CONDUCT ROUTE DRIVE AND FINE SUPPORT EQUIPMENT TO SERVICE COIL UNIT ON DS 17 IN PATH OF RIG. COORDINATE MOVING OF EQUIPMENT. COMPLETE ROUTE DRIVE AS FAR AS CH2MHILL SUPPORT YARD. PJSM ON PULLING OFF OF WELL. MOVE OFF OF DS 3-01 WITH NO ISSUES. 05:00 - 23:00 18.00 MOB P PRE BEGIN RIG MOVE TO D-PAD 23.00 - 00:00 1.00 MOB N RREP PRE STOP RIG BETWEEN E&G PAD DUE TO BLOWN RIG TIRE ON ODS,REAR,OUTSIDE - TIRE. 2/17/2015 00 0006:30 6.50 RIGU N RREP PRE PREP FOR TIRE REMOVAL.WAIT ON TIRE TECHNICIAN. 06 30 - 14:00 7.50 RIGU N RREP PRE TIRE TECHNICIAN ON RIG LOCATION. REMOVE TIRE FROM DRIVE SYSTEM. REMOVE TIRE FROM RIM. _ 14-00 - 18:00 4.00 RIGU N RREP PRE i INSTALL NEW TIRE ON RIM. AIR UP TIRE AND INSTALL ON DRIVE SYSTEM. 18.00 - 19:00 1.00 RIGU _N RREP PRE , INSTALL STEERING CONTROLS ON DRIVE SYSTEM. 19:00 - 19:30 0.50 RIGU N RREP - PRE REPAIRS COMPLETED. SECURITY CONTACTED AND ENROUTE TO RIG LOCATION TO ESCORT RIG. 19:30 - 23:30 4.00 MOB P PRE RIG MOVE FROM BETWEEN E&G PAD TO D-PAD. 123:30 - 00:00 0.50 MOB P PRE PREP WELLSITE TO PULL OVER WELL -STAGE RIG TO EDGE OF PAD -SET RIG MATS,POSITION AUXILIARY EQUIPMENT 2/18/2015 0000 - 01:30 1.50 MOB P PRE PREP WELLSITE TO PULL OVER WELL -STAGE RIG TO EDGE OF PAD -SET RIG MATS,POSITION AUXILIARY EQUIPMENT 01.30 - 02:00 0.50 MOB P PRE PJSM AND PULL RIG OVER WELL -WSL VERIFY IA=0 PSI,OA=0 PSI i-PULL OVER WELLAND SQUARE RIG OVER WELL CENTER 1-SET RIG DOWN.ACCEPT RIG AT 02:00. 02:00 - 03:30 1.50 MOB P PRE ADJUST RIG MATS,POSITION AUXILIARY EQUIPMENT RIG UP MANIFOLD IN CELLAR 03:30 - 04:30 1.00 BOPSUR P PRE •PJSM AND LEAK TIGHT TEST TREE VALVES -LINE UP MANIFOLD TO WING -LEAK TIGHT TEST TREE VALVE W/DIESEL 04:30 - 08:00 3.50 BOPSUR P PRE ND TREE CAP,NU BOPS HELD PRE-SPUD MEETING WITH DAY CREW AT PRE-TOUR. 08:00 - 10:00 2.00 BOPSUR P PRE INSPECT RAMS AND CHANGE OUT RAMS. -PJSM. LINSPECT BLIND RAMS AND CAVITIES. 1-REPLACE 1"COMBI'S WITH 2-3/8"COMBI'S. Printed 2/23/2015 12:13:O5PM • North America-ALASKA-BP Page 20fQY Operation Summary Report Common Well Name:D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor NORDIC CALISTA UWI:500292069400 Active datum:73.11 @73.11 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:30 1.50 BOPSUR P PRE PREP FOR BOP TESTING. -PJSM. -FILL STACK AND CHOKE MANIFOLD WITH WATER-CHECK FOR LEAKS. -PREP RIG FLOOR AND EQUIPMENT FOR BOPE TESTING. 11:30 - 16:30 5.00 BOPSUR P PRE STATE GIVEN NOTIFICATION OF BOPE TEST 02/16/2015 15:01 STATE INSPECTOR CHUCK SHEAVE WAIVED WITNESS 02/16/2015 15:27 PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,PTD#214181,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER ALL 2"PIPE RAMS TESTED WITH 2"TEST •JOINT 2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -BLIND RAMS TESTED ON OPEN HOLE -ANNULAR TESTED WITH BOTH 2-3/8"AND 2" TEST JOINT -TEST FULL OPENING SAFETY VALVE -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS -PERFORM DRAW DOWN TEST OF ACCUMULATOR -ALL TESTS WITNESSED BY WSL OR TOUR PUSHER 16:30 - 17:00 0.50 BOPSUR P PRE EVACUATION DRILL FOLLOWED BYAAR-ALL HANDS RESPONDED. • 17:00 - 19:00 2.00 BOPSUR P PRE FINISH PRESSURE TESTING BOP EQUIPMENT. -FAIL ON KILL LINE HCR.ABLE TO HOLD PRESSURE ON MUD SIDE.PRESSURE LEAKING THROUGH ACTUATOR AND BACK TO KOOMEY ON HYDRAULIC SIDE. 19:00 - 21:00 2.00 BOPSUR P PRE FILL COIL WITH FRESH WATER -LOAD WATER IN PITS -FILL COIL WITH WATER,TAKE MEOH CUT RETURNS OUT TO CUTTINGS BOX -SIMOPS:DRAIN STACK,PREP TO REPLACE KILL LINE HCR HELD PRE-SPUD MEETING WITH NIGHT CREW AT PRE-TOUR. 21:00 - 22:00 1.00 BOPSUR N RREP PRE PJSM AND REPLACE KILL LINE HCR -REMOVE SHOCK HOSE,BREAK HCR FLANGES,REMOVE HCR -PU NEW HCR AND MU FLANGES,ATTACH SHOCK HOSE -GREASE AND FUNCTION HCR Printed 2/23/2015 12:13:05PM • North America-ALASKA-BP Page 34£4e' Operation Summary Report Common Well Name:D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292069400 Active datum:73.11 @73.11usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:00 1.00 BOPSUR N RREP PRE PJSM AND RE-TEST KILL LINE HCR -FLOOD STACK WITH FRESH WATER -SHELL TEST BOP BODY AND KILL LINE UP TO MUD MANIFOLD,250/3500 PSI FOR 5/5 MIN -TEST KILL LINE HCR TO 250/3500 PSI FOR 5/5 MIN 23:00 - 00:00 1.00 BOPSUR P PRE 1PJSM AND TEST INNER REEL VALVE AND PACKOFFS -PU INJECTOR AND STAB ON WELL -REVERSE CIRC TO ENSURE FLUID PACKED AND PUMP BACK SLACK FOR SLACK MANAGEMENT -TEST IRVAND PACKOFFS TO 250/3500 PSI FOR 5/5 MIN 2/19/2015 00:00 - 01:00 1.00 BOPSUR P PRE PJSM AND CUT COIL FOR SLACK MANAGEMENT -POP OFF WELL,RIG UP CUTTER -CUT 250'OF COIL 01:00 - 02:00 1.00 BOPSUR P PRE INSTALL CTC -PRE COIL END AND INSTALL CTC -PULL TEST CTC TO 40K# -PRESS TEST TO 250/3500 PSI FOR 5/5 MIN 02:00 - 02:30 0.50 BOPSUR P PRE PERFORM RIG EVAC/FIRE PAST INCIPIENT STAGE DRILL -TIMELY CREW RESPONSE AND CORRECT REPSONSE FROM TRUCK DRIVES STAGED OFF EDGE OF PAD -DISCUSSED PROCESS FOR MOVING TRUCKS ON RIG TO ALLOW FIRETRUCK ACCESS TO DELUGE SYSTEM 02:30 - 04:00 1.50 BOPSUR P PRE PJSM AND HEAD UP BHI -GET ON WELL,PUMP SLACK FORWARD I- HEAD UP BHI,TEST E-LINE CONNECTIVITY -PRESS TEST UQC TO 250/3500 PSI -PRESS TEST CHECKS TO 250/3500 PSI 04:00 - 05:30 1.50 BOPSUR P PRE INSTALL NIGHT CAP AND PRESS TEST TO 250/3500 PSI TORQUE TREE BOLTS LINE UP TO TIGER TANK AND BLOW DOWN LINE 05:30 - 06:00 0.50 BOPSUR P PRE FLOWCHECK WELL -OPEN WELL TO TESTED NIGHT CAP/ CLOSED CHOKE -BUILD 15 PSI PRESSURE,BLEED OFF TO TIGER TANK -CLOSE CHOKE AND FLOW CHECK FOR 15 MIN,NO FLOW -SIMOPS:LOAD PITS WITH 130F 1%KCL 06:00 - 08:00 2.00 CLEAN P PRE DISPLACE FRESH WATER IN COIL TO KCL. -CREW CHANGE. -INSPECT ALL EQUIPMENT AND LINEUPS FOR UPCOMING CIRCULATION. **FOUND OUTSIDE CHOKE SKID HAD SEVERAL COMPONENTS THAT WERE OUT OF INSPECTION DATE. -DISPLACE FRESH WATER IN COIL TUBING TO KCL -TAKE FRESH WATER OUT TO CUTTINGS BOX. Printed 2/23/2015 12:13:05PM • North America-ALASKA-BP Page 4sae- Operation Summary Report Common Well Name:D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292069400 Active datum:73.11 @73.11 usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 12:00 4.00 CLEAN N HMAN PRE CHANGE OUT CHOKE MANIFOLD FOR PROPERLY INSPECTED EQUIPMENT. -WAIT ON WELL SUPPORT TO BRING OUT NEW CHOKE SKID. NEW CHOKE SKID ARRIVED.INSPECTED IT, BUT FOUND SEVERAL ITEMS ON THAT CHOKE SKID OUT OF INSPECTION DATE. -DISCUSSED AVAILABLE EQUIPMENT WITH WELL SUPPORT AND AGREED TO USE SINGLE CHOKE VALVE FROM IA.EQUIPMENT WAS AVAILABLE ON CH2MHILL'S EQUIPMENT TRUCK AND TRAILER. -INSTALLED NEW HARDLINE EQUIPMENT AND PRESSURE TESTED. 12:00 - 12:30 0.50 STWHIP P WEXIT PJSM FOR BHA MAKEUP. -DISCUSS CIRC OUT PROCEDURES AS WELL. 12:30 - 17:00 4.50 STWHIP P WEXIT MAKE UP MILLING BHA#1 AND RUN IN HOLE. -RUN IN HOLE AT 60-90 FPM,PUMPING AT 1.5 BPM. -AT 3400',WE ENCOUNTERED FLUID/GAS INTERFACE.SLOW DOWN TRIP SPEED TO 8-15 FPM WHILE CIRCULATING OUT INTERFACE.CIRCULATED INTERFACE FOR 20 MINUTES. -ONCE INTERFACE WAS PUMPED OUT, CONTINUE TO TRIP IN HOLE AT 0-90 FPM, PUMPING 1.5 BPM. -AT 10,190',WE ENCOUNTERED FLUID/GAS INTERFACE AGAIN.STOPPED TRIPPING AND PUMPED INTERFACE TO SURFACE FOR 15 MINUTES. -RIH FROM 10,190'TO 10,230'TO ATTEMPT TO GET GEO PDC TIE IN-UNSUCCESFUL DUE TO UNRELIABLE GAMMA READINGS. DECIDED TO FINISH CIRCULATION PROCEDURE THEN RE-ATTEMPT TIE-IN. -SAMPLES STILL SHOW 30-40%FREEZE PROTECT. -CONTINUE TO CIRCULATE TUBING CLEAN. RAISE PUMP RATE TO 2.5 BPM TO ASSIST IN CLEARING TUBING. 17:00 - 20:00 3.00 STWHIP P WEXIT CIRCULATE TO CLEAR FREEZE PROTECT FROM TUBING. -AT 300 BBLS PUMPED,SAMPLES CONTINUE TO SHOW 10-15%FREEZE PROTECT(BU= 100 BBLS) -CALL ODE AND DISCUSS PLAN FORWARD -AGREE TO GO AHEAD AND DISPLACE IA, FLUSH TUBING AGAIN AFTERWARDS -SLOW PUMPS TO 0.5 BPM WHILE STAGE TRUCKS FOR IA DISPLACEMENT Printed 2/23/2015 12:13:05PM North America-ALASKA-BP Page 5 sal&' Operation Summary Report Common Well Name.D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292069400 Active datum:73.11 ©73.11usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 00:00 4.00 STWHIP P WEXIT PJSM AND DISPLACE IA TO CLEAN KCL -REVIEW SDS FOR DEEPCLEAN DURING THE PJSM -PUMP KCL W/DEEPCLEAN TO EDC AT 2.0 BPM -SHUT IN CHOKE ON TUBING SIDE,BLOW DOWN TIGER TANK LINE -LINE UP TO TAKE RETURNS OUT THE IA TO TIGER TANK -ISOLATE RIG FROM TIGER TANK LINE -CONTINUE PUMP KCL WITH DEEPCLEAN OUT EDC AND INTO IAAT 2.0 BPM AND 3500 PSI -CHASE DEEPCLEAN WITH 60 BBLS SLICK KCL(35 BBLS COIL VOLUME,25 BBL ANNULAR VOLUME FROM 10,260'TO 6661') -CIRC PRESS DROP FROM 3600 TO 1850 PSI WITH SLICK KCL IN COIL -SLOW PUMP TO 0.3-0.4 BPM FOR 30 MIN TO ALLOW DEEPCLEAN TO SOAK IN IA. -PUMP 200 BBLS AT 2.0 BPM.CIRC PRESS= 1900 PSI.WHP=0 PSI.IA=50 PSI. 2/20/2015 00:00 - 03:00 3.00 STWHIP P WEXIT CONTINUE DISPLACE IA TO CLEAN KCL -SLOW PUMP TO 0.3-0.4 BPM FOR 30 MIN TO ALLOW FLUID TO U-TUBE. -PUMP 200 BBLS AT 2.5 BPM.CIRC PRESS= 2850 PSI.WHP=100 PSI.IA=100 PSI. -SLOW PUMP TO 0.3-0.4 BPM FOR 30 MIN TO ALLOW FLUID TO U-TUBE. -PUMP 50 BBLS AT 2.5 BPM.SAMPLE RETURNS,CLEAN KCL. 03:00 - 04:00 1.00 STWHIP P WEXIT DISPLACE TUBING TO CLEAN KCL -SHUT IN CHOKE ON IA,BLOW DOWN TIGER TANK LINE -LINE UP TO TAKE RETURNS OUT THE TUBING TO TIGER TANK -SHUT IN DOUBLE IA VALVES ON WELLHEAD -PUMP 200 BBLS KCL AT 2.9 BPM AND 3900 PSI 04:00 - 05:30 1.50 STWHIP P WEXIT DISPLACE TUBING TO NEW 8.6 PPG POWERPRO -PUMP 200 BBLS MUD AT 2.7 BPM AND 3900 PSI -TAKE KCL RETURNS OUT TO TIGER TANK -BRING RETURNS BACK TO PITS WITH CLEAN MUD ALL THE WAY AROUND 05:30 - 07:30 2.00 STWHIP P WEXIT PULL UP HOLE AND TIE-IN -UNABLE TO TIE-IN NEAR WHIPSTOCK DUE TO GAMMA INTERFERENCE -PU AND ATTEMPT TO TIE-IN AT 9600'MD, CANNOT DUE TO INTERFERENCE -PU AND TIE AT 8,895'TO 8,933'(+11.5' CORRECTION) 07:30 - 08:00 0.50 STWHIP P WEXIT TAG AND TAKE SPR'S -RIH AND TAKE SPR'S AT 10,240' -RIH AND TAG TOP OF WHIPSTOCK WITH PUMPS OFF AT 10,255.3' -POH AND TURN PUMPS ON AT 1.0 BPM. -RIH AND TAG TOP OF WHIPSTOCK WITH PUMPS ON AT 10,255.1' Printed 2/23/2015 12:13:05PM North America-ALASKA-BP Page 6, Operation Summary Report Common Well Name:D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292069400 Active datum:73.11 @73.11usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 18:00 10.00 STWHIP P WEXIT START MILLING ON WNDOWAT 10,255'. ry -PUMPS AT 1.5 BPM,FREESPIN AT 2250 PSI � v` -MW IN/OUT 8.5/8.48 PPG -MM IN/OUT 1.5/1.46 BPM -START OFF TRYING TO GET 150-200 PSI MOTORWORK,BUT MOTOR WOULD STALL AFTER 120 PSI MOTORWORK(1.2-1.5 WOB). -HAD TO FEATHER THE WOB IN TO MAXIMUM 1.2 WOB WITH MAXIMUM 110 PSI MOTORWORK. -DRILLED FROM 10,255 TO 10,256'IN 6 HOURS(1400 HRS). -AFTER 10,256'WE WERE ABLE TO APPLY MORE WOB AND GET 150-200 PSI MOTORWORK WITHOUT STALLING MOTOR. -SHAKERS SHOWED CLEAN AND NO METAL FOUND ON DITCH MAGNETS WHILE DRILLING THIS SECTION. -PUMPED 20 BBL HI-VIS SWEEP WITH 'MINIMAL RETURNS OF VERY FINE CUTTINGS WITH SWEEP. DRILL TO 10,259.8'AT 18:00 18:00 PARAMETERS PUMPS MM IN/OUT 1.52/1.50 BPM MW IN/OUT 8.54/8.50 WOB 1.83K,MOTORWORK 210 PSI,PUMP PRESSURE 2260 PSI. ECD 9.29 PPG IA=99 PSI,OA=76 PSI. 18:00 - 18:30 0.50 STWHIP P WEXIT MILL WINDOW F/10,259.8'T/10,260.1'MD -FS:2300 PSI MTR WRK:100-200 PSI WOB: 0.5-1.5K# -BPM IN/OUT:1.51/1.50 PVT:342 BBLS -MW IN/OUT:8.55/8.50 PPG -ECD/IA/OA:9.30 PPG/105 PSI/75 PSI 18:30 - 23:00 4.50 STWHIP P WEXIT MILL RATHOLE F/10,260'T/10,270'MD -TIME MILL FIRST 1.5'UNTIL STRING REAMER OFF WS TRAY -FS:2300 PSI MTR WRK:200-300 PSI WOB: 1.5-2.5K# -BPM IN/OUT:1.51/1.50 PVT:341 BBLS -MW IN/OUT:8.54/8.50 PPG -ECD/IA/OA:9.31 PPG/105 PSI/74 PSI 23:00 - 00:00 1.00 STWHIP P WEXIT REAM WINDOW AS PER PLAN -REAM UP AND DOWN ATI/MIN 3 TIMES -1.5 BPM IN/OUT WITH 2300 PSI -NO MOTORWORK OR WEIGHT BOBBLES 2/21/2015 00:00 - 00:30 0.50 STWHIP P WEXIT CONTINUE REAM WINDOW AS PER PLAN -REAM UP AND DOWN AT 1'/MIN 3 TIMES -1.5 BPM IN/OUT WITH 2300 PSI -NO MOTORWORK OR WEIGHT BOBBLES -DRY DRIFT WINDOW,SMOOTH 00:30 - 03:00 2.50 STWHIP P WEXIT POOH WITH MILLING ASSEMBLY -FLOWCHECK ON BOTTOM,NO FLOW -PUMP 20 BBL HI-VIS SWEEP ON BOTTOM -100'/MIN WITH 2.06/1.65 BPM IN/OUT -FLOWCHECK ON SURFACE,NO FLOW Printed 2/23/2015 12:13:05PM North America-ALASKA-BP Page 7 qL Operation Summary Report Common Well Name:D-18 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2015 End Date: X3-016KT-C:(5,078,779.83) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/4/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292069400 Active datum:73.11 @73.11 usft(above Mean Sea Level) -- Date Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 03:45 0.75 STWHIP P WEXIT PJSM AND LD MILLING ASSEMBLY -POP OFF,STAND BACK INJECTOR -STAND BACK 2-3/8"COILTRAK -LD 2 JTS 2-1/16"CSH -LD MOTOR AND GAGE MILLS -WINDOW MILL:2.74"GO,2.73"NO-GO -STRING REAMER:2.75"GO,2.74"NO-GO BLOW DOWN AND LD COILTRACK 03:45 - 04:45 1.00 DRILL P PROD1 PJSM AND PU DRILLING ASSEMBLY -PU ULS MOTOR WITH 0.91 DEG AKO AND 3.25 BI-CENTER BIT -PU 2-3/8"COILTRAK WITH RESISTIVITY -GET ON WELL,PRESS TEST QTS 04:45 - 07:30 2.75 DRILL P PROD1 RIH WITH BUILD ASSEMBLY 100'/MIN WITH 0.54/0.88 BPM IN/OUT -TIE-IN WITH+8'CORRECTION -RIH,GET SPR'S. -TAG BOTTOM AT 10,270' 07:30 - 11:00 3.50 DRILL P PROD1 DRILL 3.25"BUILD SECTION FROM 10270' -NBI 21.27° -ROP 0-10'/HR(INITAL) TO 10-15'/HR. -BPM IN/OUT:1.55/1.57 -CIRC PSI:2425 FREE SPIN (80-120 PSI MW) -ECD:9.3 PPG(OBD) -MW IN/OUT:8.57 PPG/8.50 PPG -1A/OA/PVT:95 PSI/50 PSI/324 -DHWOB:1.0K LBS-1.6 K LBS -PREP 2OBBLS HI-VIS PILL FOR PUMPING. -DRILL TO 10,291'MD -NO LOSSES TO FORMATION WHILE DRILLING THIS SECTION. -UNABLE TO SEE RA-TAG ON GAMMA RAY AS SENSOR PASS WHIPSTOCK FROM HIGH li GAMMA INTERFERENCE. 11:00 - 18:00 7.00 DRILL P PROD1 DRILL 3.25"BUILD SECTION FROM 10291' -NBI 36.53° -ROP 15-49'/HR. -BPM IN/OUT:1.78/1.77 -CIRC PSI:2950 FREE SPIN (80-140 PSI MW) -ECD:9.4 PPG(OBD) -MW IN/OUT:8.58 PPG/8.52 PPG -IA/OA/PVT:110 PSI/71 PSI/325 -DHWOB:1.3K LBS-1.8 K LBS -DRILL TO 10,440'MD -NO LOSSES TO FORMATION WHILE DRILLING THIS SECTION. -SAMPLES AND GAMMA SHOW DEPARTING SHUBLIKAND ENTERING IVASHAKZONE4 AT 10,313' 18:00 - 00:00 6.00 DRILL P PROD1 DRILL F/10,440'T/10,554'MD -FS:2900 PSI MTR WRK:100-300 PSI WOB: 1.0-2.0K# -BPM IN/OUT:1.85/1.84 PVT:342 BBLS -MW IN/OUT:8.61/8.56 PPG -ECD/IA/OA:9.51 PPG/126 PSI/89 PSI -ROP:20-30 FPH -100'WIPERS EVERY 150'DRILLED -NO LOSSES TO FORMATION WHILE DRILLING THIS SECTION. Printed 2/23/2015 12:13:05PM TREE= 4-1/16"CNV _ WELLHEAD= MCEVOY D-18 A SAFL 8.1 8263'DTES CHROME TBG<C WELLBORE NDMAX_X DOG EG: CTU4TOR= BAKBR C @ OKB.ELEV= 76 t BF.ELEV= 40,16' KOP= 3200' Max Angle= 53°@ 6247" • 2117' -2119''HTUBNG PUNCH(10/17/14) Datum MD= 10556' Datum TVD= 8800 SS 2130' {4-1/2"HES X NP,D=3.813" CONDUCTOR, #,_..__._ ,L) H ^°r 2503' H9-5/8*X 7-5/8"BKR ZXP FKR w l 6'TEBK,D=6.890" 9-5/8"DV PKR(COLLAR) —I 2567' = 2523' —{9-5/8"X 7-5/8"BKR FLX LCK HY 0 HGR D=6.89" �.. 13-3/8"CSG,72#,L-80 BTRS,D=12.347' 2679' ilk 4-1/2"GAS LIFT MANDRELSST MD IV:) DEV TYPE VLV LATCH PORT DATE 5 2972 2972 5 KBG-2 DMY BK 0 10/14/01 Minimum ID = 2.750" @ 9951' E 4 3737 3717 20 KBG-2 DMY BK 0 08/26/11 3-1/2" X NIPPLE 3 6661 5786 52 KBG-2 FS BEK - 02/15/15 4-1/2"TBG,12.6#,13CR-80 TDS, — 7739' / --------.-'-, 7739' H4-1/2"X 3-1/2"XO,ID=2.992" .0152 bpf,ID=3.958" 7841• —{6"TACK SLV,D=? 7847' H 7-5/8"X 5-1/2"BKR ZXP PKR D=4.90" 7-5/8"BKR WHIPSTOCK — 8027' \ J 7855' —7-5/8'X 5-1/2"BKR ZXP MECH SET FKR 9-5/8"CSG,47#,L-80 BTRS,D=8.681" --I —8027' Y w/6'T1E$ACKBSEAL ASSY,D=4.870' 7-5/8"LHR 29.7#,L-80 STL H —8027' *, �� ir 7869' ID .0459 bpf,D=6.875" r. .y. 7878' H5-1/2"XO PN,D=4.892" .4 t/ ♦.'} MLLOUT WINDOW (D-18A) 8027'-8039" 3-1/2"GAS LFT MANDRELS ST MD IV') DEV TYPE VLV LATCH PORT DATE 2 8735 7245 31 KBG-2-9 DMY BK 0 10/14/01 1 9862 8228 26 KBG-2-9 DMY BK 0 10/14/01 I 9951' H 3-1/2"HES X NP,D=2.750" 5-1/2"X 4.676'BKR ZXP MECH PKR — 10024' \titi 1 9973' —{5 1/2"X 3 1/2"BKR S-3 PKR D=2.780" w/6'TACK SLV,D=4.125' I 9996' H3-1/2.HES X NIP,0=2.750" 5-1/2"LNR,17#,L-80 STL, .0232 bpf, D=4.892" — 10205' I 1001T —I 3-1/2"HES X NP,D=2.750" 3-1/2'BKR KB PKR WHIPSTOCK — 10255' t (RIG TAGGED 02/20/15) Ii 10029' -13-1/2"WLEG, D=2.992" 10039' —14.36"PBR,D=3.250" PERFORATION SUMMARY 10044' —I 5-1/2"X 3-1/2"BKR HMC HGR,0=2.930" REF LOG: MWD RES 10/09/01 ANGLE AT TOP PERE 20°@ 10652' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SI-DT CQ7 10528' —{3 1/2"MARKER JOINT 2" 6 10652-10667 C 09/23/08 I 2" 6 10674-10679 C 09/22/08 2" 6 10674-10692 C 03/30/04 2-1/4" 6 10674-10692 C 11/24/01 I 10795' H PBTD 3-1/2"LNR 9.2#,13CR-80 VAM ACE, —j 10895' .0087 bpf,D=2.992" DATE REV BY COMMENTS DATE REV BY COM 3NNTS FRUDHOE BAY UNIT 04/24/82 AUDI 3 OFTIG COMPLETION 01/21/15 JCMJMD SET WS(01/20/15) WELL: D-18A 10/14/01 0-14 SIDETRACK(D-18A) 02/18/15 VVRPYJMJ GLV C/O(02/15/15) PETRMIT No:' 011030 10/17/14 JCA'PJC SET KB PATCH 03/04/15 PJC VVHIPSTOCX RIG TAG DEPTH AR No: 50-029-20694-01 12/09/15 PJC PRE RIG CLEANUP SEC 23,T11 N,R13E,1990'FtsL&1692'FEL 01/13/15 JAMJMD PULL PATCH&RUG(01/11-12/15) 01/16/15 PJC MN ID/X NP@ 2130 UPDATE BP Exploration(Alaska) WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ;«;1/ jIJ3 Well History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. • • C6(A_ -- 1 le) 1103o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Saturday, December 22, 2012 4:51 AM c1Z4 i 'v To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad DG; Meixueiro, Paulina Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Holt, Ryan P; Climer, Laurie A Subject: NOT OPERABLE: Producer D -18A (PTD #2011030) Secured with Tubing Tail Plug and Passed CMIT -TxIA All, Producer D -18A (PTD # 2011030) has been secured with a tubing tail plug and passed a CMIT -TxIA to 2500 psi on 12/21/2012. The well is reclassified as Not Operable. Plan forward: 1. Anchorage PE: Evaluate for patching or RWO options on tubing Please call if you have any questions. Thank you, Gerald Murphy SCANNED APR 1 1 2013 BP Alaska - Well Integrity Coordinator GW Global Wells Organization WIC Office: 907.659.5102 WIC Email: AKDCWe1IIntegrCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, November 21, 2012 10:19 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team L -:d; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; • , OPS Well Pad DG; Meixueiro, Paulina; 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)' Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engin ; Walker, Greg (D &C); Clingingsmith, Mike 3 Subject: UNDER EVALUATION: Producer D -18A (PTD #2011030) Susta'• IA Casing Pressure Above MOASP All, Producer D -18A (PTD #2011030) has confirmed sustaine. • casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2430/2150/30 on 11/19/20 The well has been reclassified as Under Evaluation. Plan forward: 1. DHD: MIT -IA to 3000 psi 2. WIE: Pending MIT -IA results, eval =te for a Leak Detect Log A TIO plot and wellbore schematic h e been included for reference. 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 =x, Anchorage, Alaska 99519 -6612 March 06, 2011 103 L ©t Mr. Tom Maunder k$ Alaska Oil and Gas Conservation Commission : 08 C s 333 We st 7 Avenue Anchorage, Alaska 99501 fit oros� � ,> w %sion Subject: Corrosion Inhibitor Treatments of GPB D Pad Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal 0-01A 1970780 50029200540100 _ NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 0-05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 i 800150 50029204430000 NA 1.3 NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 . 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 �.....-. D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 D -29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 STATE OF ALASKA) 0~ ~ ~ ` ALP OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0 - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment - Exploratory ' 201-1030 3. Address: P.O. Box 196612 Stratigraphic ~ Service ' 6. API Number: Anchorage, AK 99519-6612 50-029-20694-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.11 KB PBU D-18A - 8. Property Designation: 10. Field/Pool(s): ADLO-028284 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10895 - feet Plugs (measured) None true vertical 9191.23 feet r Junk (m e a S u ed) None - ~{ ~({ 1f }S (f ( ~ 4/ W'-~~~' '~t~ ~ `~'=' ~°~' l~t ~ ~ % Effective Depth measured 10828 feet ,v bHvW ~ ~ true vertical 9128.32 - feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 34 - 113 34 - 113 1490 470 Liner 5526 7-5/8" 29.7# L-80 2500 - 8026 2500 - 6682 6890 4790 Liner 2369 5-1/2" 17# L-80 7836 - 10205 6556 - 8543 7740 6280 Liner 806 3-1/2" 9.2# 13CR80 10024 - 10830 8375 - 9130 10160 10530 Liner 65 3-1/2" 9.3# L-80 10830 - 10895 9130 - 9191 10160 10530 Production 7994 9-5/8" 47# L-80 32 - 8026 32 - 6682 6870 4760 Surface 2643 13-3/8" 72# L-80 33 - 2676 33 - 2676 4930 2670 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 31 - 7739 3-1/2" 9.2# 9-CR-80 7739 - 10029 Packers and SSSV (type and measured depth) 7-5/8" Baker ZXP Top Packer 2506 5-1/2" Baker ZXP Hydro Set Packer 7836 5-1/2" Baker ZXP Hydro Set Packer 7855 3-1/2" Baker SABL-3 Packer 9973 3-1/2" BAKER ZXP MECH SET PACKER 10024 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 526 24276 808 1595 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Developmen t ~~' Service ~~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~'' Gas ~ WAG GIN) ? WIN) WDSPL €~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre e Title Data Management Engineer ~~ ~~ I Signature Phone 564-a9QA ..,~. Date 9/26/2008 ti„J I D-18A 201-1030 PERF ATTA(:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top ~ M eas Depth Base Tvd Depth Top Tvd Depth Base D-18A 11/24/01 PER 10,674. _ 10,692. 8,983.9 9,000.83 D-18A 3/30/04 RPF 10,674. 10,692. 8,983.9 9,000.83 D-18A 9/22/08 APF 10,674. 10,679. 8,983.9 8,988.61 D-18A 9/23/08 APF 10,652. 10,667. 8,963.2 8,977.32 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 • r • • D-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY --- 9/22/2008:""**WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 2400/2300/100."`*~ ''::SWAB SHUT, IA/OA OPEN TO GAUGES. RIG UP E-LINE FOR PERFORATING ': TWO INTERVALS: PERFORATED INTERVAL FROM 10674 - 10679 FT WITH ', ', 'SLB 2" PJ HSD 2006 GUN, 6 SPF. SURFACE INDICATION OF DETONATOR FIRING. ARM AND RIH WITH GUN # 2 ''`**JOB CONTINUED ON 23-SEP-08'`'`* 9/23/2008:; T/I/0=2380/2380/130. Temp=S1. TIFL PASS (eval high IAP). AL SI @ casing :valve. ALP=1900 psi. IA has integral installed. IA FL @ 4947' (1714' above S/O @ 6661'). Bled IAP from 2380 psi to 1200 psi in 2 hr. During IA bleed TP 'decreased 10 psi, OAP decreased 10 psi. Monitor 1 hr. IA FL unchanged, IAP increased 20 psi. Final WHP=2370/1220/120. SV, WV, ALV=Closed. SSV, MV=Open. IA&OA=OTG. NOVP. 9/23/2008;.***JOB CONTINUED FROM 22-SEP-08*** CONTINUE RIH WITH 2" PJ 2006 20' GUN LOADED WITH 15' OF CHARGES. "SHOOT INTERVAL 10652'-10667' CONTINUE SEASONING CABLE STOP ERY 1000' AND PULL UP 200' ---SWAB SHUT, IA/OA OPEN TO GAUGES, ;.WELL LEFT SHUT IN NOTIFY PAD OP OF VALVE POSITIONS AND THAT s,WELL IS READY TO BE PUT BACK ON LINE ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total Schlumberger "\ ?; 1 ?OíJ7 5'Gf~~EO 0(, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# Log Description Date F-48 11846815 US IT 1'1/-- ()1 :,..., 10/12/07 G-19A 11890315 USIT 1'-1'1- to" 09/30/07 NGI-13 11890313 USIT I )"TJ' t ~ -rA / 09/30/07 MPE-30A 11855817 USIT ~ó/-O ( 10/01/07 ;:}cf-I- ¡C L(-# 15~"3 - F-11 B 11649954 MCNL 03/22/07 W-12A 11418301 MCNL J'11f-/"ìfg "¡~ç-:¡'-I 09/10/06 11-27 11637127 RST i~lo -14~ tI.: ¡":;-5""":}(,.,, 06/05/07 02-22A 11216214 MCNL ,Q/"'l'l - ,,<çD, "ft ~k""--::¡' ~ 10/02/06 01-16 11630486 RST 1~"if-OO'if "'.¡ ~!::c.- 7J.-'% 06/28/07 01-14 11801086 RST ¡'J-~- r-,--; ..':} · t~:'\ +'-1 07/07/07 L5-05 11767129 MCNL / if "':} _,..)(~c.. ., ,~~D 06/17/07 D-21 11626119 RST ¡'tr;J -/'I:~":::> .. ,~x, 09/12/07 14-15 11221550 RST 11r/ - Ó'" L( "J1 ,S-S-xc'=) 03/07/06 D-18A 11695074 RST ah/- In: 'It:- '~:'I ?5 08/28/07 14-05A 11813055 RST ¡-Do, ~ -(10 I .. 1.....'" ~ :" 06/11/07 1-23/0-15 11846802 RST U-U'_ tOt 'I , 'I::¡~ 'It 1:-::> 7fJ 08/11/07 S-03 11223120 RST 1~1 - 1&>'./'\ t 1",,~~LI 06/13/06 1-09A1L-21 11849930 RST I C\ '=}- - ()t9q it" I t\S- -+ 5" 08/04/07 P2-19A 11649963 MCNL _1/)+- ()jd ~ 1~5*d 04/22/07 OWDW-NW 11211370 RST lJTJ' ,~" -VI" $=1/'5S"9-1 02/28/06 K-01 11695073 RST 1~3 - If) / ... 5S7-ö 08/27/07 11-32 11630498 RST 1D,t...{- I~ I ". I ~5 L.,'1 09/03/07 3-25B/L-27 11630490 RST .qö~ - ():;) ¡ ... 1 -ç..s-¡;., '}{ 07/26/07 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: NO. 4459 Company: State of Alaska Alaska 011 & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne! Pt.,LisburnE BL Color 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 , AnN B'" ~ Received by: C.; . 10/23/07 . . e e MICROFilMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_lnserts\Microfilm _ Marker.doc , r-., ,-..., " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 2. Operator Suspend 0 RepairWellD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate [!] WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 201-1030 OtherD Name: BP Exploration (Alaska), Inc. Development Œ] Stratigraphic 0 9. Well Name and Number: D-18A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50-029-20694-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 73.11 8. Property Designation: ADL-D028284 11. Present Well Condition Summary: Total Depth measured 10895 feet true vertical 9191.2 feet Effective Depth measured 10775 feet true vertical 9078.7 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 34 113 34.0 - 113.0 1490 470 Liner 5526 7-5/8" 29.7# L-80 2500 - 8026 2500.0 - 6681.5 6890 4790 Liner 2369 5-1/2" 17# L-80 7836 - 10205 6556.1 - 8542.7 7740 6280 Liner 806 3-1/2" 9.2# 13Cr80 10024 - 10830 8375.2 - 9130.2 10160 10530 Liner 65 3-1/2" 9.3# L-80 10830 - 10895 9130.2 - 9191.2 10160 10530 Production 7994 9-5/8" 47# L-80 32 - 8026 32.0 - 6681.5 6870 4760 Surface 2643 13-3/8" 72# L-80 33 - 2676 33.0 - 2676.0 4930 2670 Perforation depth: Measured depth: 10674 -10692 True vertical depth: 8983.9 - 9000.83 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# 13Cr80 3-112" 9.2# 9Cr80 3-1/2" Baker SABL-3 Packer 3-1/2" Baker ZXP Mech Set Packer 5-1/2" Baker ZXP Hydro Set Packer 5-1/2" Baker ZXP Hydro Set Packer 7-5/8" Baker ZXP Top Packer @ 31 @ 7739 7739 10029 REG @ 9973 EIVED @ 10024 @ 7836 APR .2 1 2004 @ 7855 @ 250.'aska Oil & Gas Cons- r.ommb3;C;;-, Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 12.1 345 1000 13 Prior to well operation: Subsequent to operation: Oil-Bbl 315 654 22.2 995 1080 Tubing Pressure 1228 1124 14. Attachments: 15. Well Class after proposed work: ExploratoryD Developmentl!! ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG 0 GlNJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Daily Report of Well Operations .K 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron :~::am. jj=;roë~ Form 10-404 Revised 12/2003 o~( I CINAL Pho'"_8FL Date 4/19/04 APR t 2 1ßn~ ~ ".......... ,-....., D-18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/22/04 ***WELL FLOWING UPON ARRIVAL*** ( PRE-PERF) DRIFTED WITH 2" DUMMY GUN. (TARGET DEPTH 10,692') TAGGED BOTTOM @10,751' SLM. ***BROUGHT WELL BACK ON PRODUCTION*** 03/30/04 PERFORATED INTERVAL 10,674 -10,692 FT WITH 18 FT OF 2" HSD 6 SPF 2006 PJ SHOTS. TAGGED TD AT 10,762 FT NO PROBLEMS GETTING TO DEPTH OR PULLING OUT. ALL SHOTS FIRED. FLUIDS PUMPED BBLS No Fluids Pumped 0 I TOTAL Page 1 r---. ,-....., TREE = W8..LI-EAO = AcrUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = OabJm MD = OabJm TV 0 = 4-1/16" em MCEVOY OTIS 73.1' 40.16' 3200' 53 @ 6447' 10556' 8800' SS D-18A SAFETY NOTES: PR&SDTRK WB.LBORE NOT SHOWN ON DIAGRAM BELOW 9-5/S" CSGSHOE WELL HAS CHROMETBG (4-1/2" & 3-112") AND 3- 112" 13-CR LNR. 19-5/8" r:J.J R<R(COLLAR) H 113-3/8" COO, 72#, L-80 BTRS, Ð = 12.347" H ~ ~ 2567' ~ J = 2679' -----8 I ~ I I I i 2130' 2503' 2509' 2523' H4-1/2" HES X NIP, 10= 3.813" 1 HTOPOF BKRTIEBAO< SLV.IO= 7.75" H9-5I8"X 7-5/8" BKRZXPPKR, Ð =6.89" I H9-5I8"X 7-5/8" BKRLNRHGR,IO =6.89" I - L - ST MO 5 2972 4 3737 3 6661 4-112" GAS LIFT MA.I'VR8..S TVO OEV TYÆ VLV LATOi PORT I)II.TE 2898 8 KBG-2 DOME BK 16 10127/01 3645 20 KBG-2 DOME BK 16 10127/01 5713 52 KBG-2 SO BK 20 10127/01 3-112" GAS LIFT MA.I'VR8..S TVO OEV TYÆ VLV LATOi PORT I)II.TE 7172 31 KBG-2-9 DMY BK 0 10/14/01 8155 26 KBG-2-9 RP BK SHRO 10/14/01 Minimum ID = 2.750" @ 9951' 3-1/2" H ES X NIP PLE ST MO 2 8735 1 9862 14-112" lBG,12.6#, 13-CR-80, .0152 bpf, 10 = 3.958" H 7738' , I - 7739' H4-1/2" X 3-1/2' TOO XO, ID = 2.992' I HTOPOFBKR llEBAO< SLV I HTOPOFBKRllEBAO<SLV I 17-5/8"X5-112"BKRZXPR<R,10=4.900" H 17-5/8" X 5-112" BKRZXP R<R,IO =4.892' H 17-5I8"X5-1/2'BKRLNRHGR,10=4.920" H 784T 7861' 7869' I I ~ -, ~ ië p~ 7841' 7855' TOPOFBAKERWHIPSTOCK H 8O2T 7-5/8" /9-5/8" MLLOUT WINDOW ~ / 8026' - 8O3g' (OFFWHPSTOO<) /J 9951' H3-1/2" HES X NIP, 10=2.750" I 9973' H5-112" X3-1/2"BKRSABL-3PKR, 10=2.780" 1 9996' H3-1/2" HES X NIP. 10 = 2.750" I 10017' H3-1/2'I-ESXNP.10=2.750" I 10029' H3-1/2"WLEG.ID= 2.992' I 10043' H BTM OF BKR PBR, 10 = 3.250" I 10044' HBKRI-MCLNRHGR,10=2.93" I 13-112" lBG, 92#, 9.CR-SO, .0087 bpi, Ð = 2.992" I 17-518" LNR, 29.7#, L-80 STL, 10 = 6.875" H 8130' 19-5/8" CSG, 47#, L-80 BlRS, 10 = 8.681" H 10459' I TOPOFBKRllEBAO<SLV H 10024' 15-112" X 3-1/2" BKRZXPPKR, 10=4.125" H 10030' 15-1/2' Lf\R, 17#, L-80 STL, 10 = 4.892' H 10205' PERFORATION SUMMA. RY REF LOG: MNO RES 10/09/01 ANGLEATTOP PERF: 20 @ 10674' I'bte: Refer to A'oduetion DB for historical perf data SIZE SPF INTER.! AL Opn/Sqz 1)II.1E 2-1/4" 6 10674-10692 0 11/23¡Q1 ~ 10795' 13-1/2' LNR, 9.2#, 13-CR-SO, .0087 bpf,lO =2.992" H 10895' I DATE REV BY COMMENTS 1)II.1E REV BY COMMENTS PRUOI-DE BAY LtoJIT 04/25/82 ORIG COMR. 11/28/01 CWSIKAK PERFS & GLVs WELL: [)'18A 03/08/01 SIS-MO ANAL 12/15/01 JKB/KAK TREECHA.NGE OUT PERMT I'b: 2011030 OS/28/01 CH'TP CORRECllONS 03119/02 ONSltih &Llf\E ASH AA No: 50-029-20694-01 06/21/01 ITP ClITTOO 06118/02 JMlTP &Llf\E-RJLL F6HIWlRE 6I12JU2 SEC23 T11 N R13E 1990' SN... & 1692' WEL 10/14/01 CH'KAK RIGSIDElRAO< 7/912003 CMOITLP KB ELEV ATION CORREcrlON 11/18/01 SOF/KAK MANDRELCHG BP Exploration (Alaska) Color Well Job# Log Description Date Blueline Prints 40009587 OH EDIT LWD ARC & ADN (PDC) 09/25/03 40009587 MD VISION RESISTIVITY 09/25/03 1 40009587 TVD VISION RESISTIVITY 09/25103 1 40009587 MD VISION DEN/NEUTRON 09/25/03 1 40009587 TVD VISION DEN/NEUTRON 09/25103 1 10703940 RST-SIGMA 10/25/03 1 10679041 RST-SIGMA 12/20103 1 10564487 RST -SIGMA 06/19103 1 10674406 RST-S1GMA 12/31/03 1 10728382 MCNL 12/08/03 1 10728384 PRODUCTION PROFILE 01/01104 1 Schlullbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: - to. ç-- ~r';\ ~ A N". ~~ t () (}"Q ~/~ . sr l~~~~~.~\k:r t:'t:'R 0' 20'\/1 --" ¥ ~~ - :- ~~Þv~- ~ b kl ..J:J1 ".. lJ 'i 01/23/04 NO. 3098 Company: ~tate of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CD 1 £=2 :?, q '::2. 1 :; :; :; 1 - Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth Received by: RECEIVED I ^ U -: (, f}iìU~ A vi 'I ~ ...J .. L.v .1.). Af~~ka Oil & Gas Cons. Commisskm Ar.mrøge 1 (;( ~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011030 Well Name/No. PRUDHOE BAY UNIT D-18A Operator BP EXPLORATION (ALASKA) INC Sf~ À~ ìt").ð 6 I API No. 50-029-20694-01-00 MD 10895 --- TVD 9191 / Completion Date 11/23/2001 ~ Completion Status 1-01L Current Status 1-01L UIC N ---- - ---- -- REQUIRED INFORMATION Mud Log No Samples No Directional surv:~~~-Y.~~ ----- - --- ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D 1 0645 (data taken from Logs Portion of Master Well Data Maint) ~. C Pds 10481 Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 7992 10847 Open 3/4/2002 10173 10816 Case 12/21/2001 i _____1 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Well Cored? ADDITIONAL INFORMATION y/(0 Daily History Received? '0N cVN Chips Received?---rTl\.I- Formation Tops Analysis Received? ~ ->, -- ------ -- - Comments: ¡\Ie r ~ i< r> D ("'t fZ s r S()..\-\I>-'i'eJ-p '- l'tnd J \;~ W"'v-- Mr ~- C~ r.- ß N',,, ~ \ r>fr ~. \~ ~ t N \ v ^~~ 1 ~~. ~ L---- ~ Compliance Reviewed By: Date: ~~-Mi~ ( (' WELL LOG TRANSMITTAL ~O( lo3 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 04, 2003 RE: MWD Fonnation Evaluation Logs: D-18A, AK-MW-11159 D-18A: Digital Log Images 50-029-20694-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF TH.E TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~'" /! -' q) Signed: ~~ ~ ) V ~. \) ðV\-~ { ,I' '[ !I WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas ConsetVation Comm. Attn.: Lisa Weepie 333 West 7tlt Avenue, Suite 100 Anchorage, Alaska February 26, 2002 RE: MWD Formation Evaluation Logs D-18A, AK-MM-11159 1 LDWG formatted Disc with verification listing. API#: 50-029-20694-01 aO/-/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speay-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~'LI OdO p--) Date: RECEIVED f-U pO! '/002 '. \. , t L... . Alaska Oil & Gas Cons. Commission Anchorage ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well !HI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-1 03 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20694-01 4. Location of well at surface --.''' , .. 10CA'tK>N$ 9. Unit or Lease Name -,' 1990' SNL, 1692' WEL, SEC. 23, T11 N, R13E, UM ,-. ,'" ~~ Prudhoe Bay Unit At to,P of produ~tive interval : II' ¡'~''£.L ~'.: 2898 NSL,827 WEL, SEC. 22, T11N, R13E, UMi "'I" nl~~^'~" 1 O. Well Number At total depth ..~ ':--,:- . .-:,' " 2925' NSL 904' WEL SEC. 22 T11 N R13E UM: ----"~-'"-" ";~'~'~~_r\~¡ D-18A , , , , , :"....-.--,.......,-.I:II'~ ...~,....',..' . 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field 1 Prudhoe Bay Pool KBE = 73.11' ADL 028284 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 1 0/2/2001 1 0/1 0/2001 11/23/2001 NIA MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD).119. Directional Survey 120. Depth where SSSV set 1 21. Thickness of Permafrost 10895 9191 FT 10828 9128 FT !HI Yes 0 No (Nipple) 2130' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DEN, NEU, CBL 23. CASING, liNER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Su rface 2678' 17-1/2" 3490 cu ft Permafrost II 9-518" 47# L-80 Su rface 80271 12-1/4" 1462 cu ft Class 'G' 130 cu ft PF 'C' 7 -5/8" X 7" 29.7# 1 26# L-80 2503' 80271 N/A 640 cu ft Class 'G' Inside 9-5/8" CasinQ) 5-1/2" 17# L-80 7836' 10205' 6-3/4" 151 cu ft Class 'G' 3-1/2" 9.2# L-80 / 13Cr80 10024' 10895' 4-3/4" 112 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUSING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/4" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 7739' MD TVD MD TVD 3-1/2",9.2#, 13Cr80 7739' - 10029' 9974' 10674' - 10692' 8984' - 9001' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 21, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-Bsl CHOKE SIZE 1 GAS-Oil RATIO 1/13/2002 4 TEST PERIOD 309 2461 1044 92.89 7965 Flow Tubing Casing Pressure CALCULATED OIL-BsL GAs-MCF WATER-Bsl OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 25.7 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chiQs. "~=rV;ED RE No core samples were taken. ' ">mmE 2 ¡~!~ ;~OO2 ~, Alaska Oil & Gas Cons. Commission f""\1""'"\11""1r..1 ^ I Anchorage Form 10-407 Rev. 07-01-80 Ut\ltJil\lI-\L -. . FER ? $Qft1mit In Duplicate RBDMS 8Ft I-ER ? 2nO? c,¡z (' 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Sag River 10215' 8552' Shublik A 10248' 8583' Shublik 8 10270' 8603' Shublik C 10298' 8630' Sadlerochit / Zone 4 1 0311' 8642' Zone 3 10496' 8816' Zone 2C 10587' 8902' Zone 28 10659' 8970' HOT 10721' 9028' Zone 2A 10752' 9057' Zone 1 8 10790' 9093' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys (' 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. ~:; <~: . Ò,laska Oil & Gas CGns. CommiSSion A.f1c!1oraqe 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ Title Technical Assistant D-18A Well Number 201-103 Permit No. / A roval No. INSTRUCTIONS Date OI.~3"O~ Prepared By Name/Number: Terrie Hubble, 564.4628 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 ORIGINAL Legal Name: D-18 Common Name: D-18A I TestÐâte 10/1/2001 10/9/2001 FIT FIT 8,059.0 (ft) 10,205.0 (ft) 6,698.0 (ft) 8,542.0 (ft) 10.50 (ppg) 8.40 (ppg) SÛrface Pressure 523 (psi) 520 (psi) Leak Off Pressure (BHP) 4,176 (psi) 4,247 (psi) Page 1 of 1 EMW 12.00 (ppg) 9.57 (ppg) Printed: 10/15/2001 12:39:13 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/20/2001 9/21/2001 9/22/2001 ( (' BP EXPLORATION Operations Summary Report D-18 D-18A REENTER+COMPLETE NABORS NABORS 7ES 10:00 - 12:00 From - To Hours Activity Code NPT Phase PRE 12:00 - 13:30 13:30 - 15:00 15:00 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 07:30 07:30 - 08:30 08:30 - 10:30 10:30 - 13:00 13:00 - 14:00 14:00 - 18:00 18:00 - 18:30 18:30 - 20:30 20:30 - 21 :00 21 :00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 03:30 03:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 08:00 2.00 MOB P 1.50 MOB P 1.50 RIGU P 3.00 WHSUR P 0.50 WHSUR P 1.50 KILL P 4.00 KILL P 0.50 KILL 0.50 KILL P P 6.50 KILL P 1.00 WHSUR P 2.00 WHSUR P 2.50 BOPSUr:; P 1.00 BOPSUr:; P 4.00 BOPSUr:; P 0.50 BOPSUF P 2.00 PULL P 0.50 PULL P 1.50 PULL P 1.00 PULL P 0.50 PULL P 3.00 PULL P 0.50 PULL P 2.00 PULL P 0.50 PULL P 0.50 PULL P 0.50 PULL P 1.00 PULL N PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 1 of 10 Start: Rig Release: Rig Number: Spud Date: 9/20/2001 End: 9/20/2001 Description of Operations Jack floor, move off D 19B and mats, set mats on D 18A Spot rig on well D 18A Skid rig floor to drilling position Rig accept, Install second valve on top annulus, hook up lines to wellhead for killing well, displace freeze protect, fill pits, RU rig floor Pre spud safety meeting Reverse circulate casing to displace freeze protect. Recovered app. 70 bbls. from tubing. Had small gas bubble just as diesel reached surface while taking returns up tubing. Circulate casing, down tubing, displace diesel freeze protection. Diesel strung out for app. 420 bbls. while pumping down tubing taking returns up annulus. Well taking fluid while pumping down tubing at following rates: 30 spm -1.5 40spm -2.5 50 spm -3. Circulate out diesel freeze protection Shut in well, SIDPP 50 psi, SICP 50 psi, 15 minutes, circ well Circ well, shut in well, SIDPP 0 psi, SICP 20 psi, open well, observe well for flow, flowing, circulate well to establish loss rate, pump 20 bbls at 9 ppg, monitor well, well flowing, pump 20 bbls chaser, monitor well, well flowing RIU DSM lubricator, Set TWC, RID DSM NID tree, adapter flange, tubing hanger, X/O takes 8 turns NIU BOPE RIU to test BOPE Pressure test BOPE to 250 low 3,500 high. Test witnessed by AOGCC. RID BOP test equipment RlU DSM lubricator to pull TWC, pull same, RID DSM RIU to pull tubing hanger. BOLDS and heat tubing head with steam. Attempt tp pull tubing hanger, pull free at 220 K, pull in 5 K increments on tubing cut, start at 300 K, some movement at 315 K, slight movement untill at 350 K string parted, wt indicator 109 K, - 50 K block wt = 59 K string wt Circ bottms up, establish circ rates, loss I gain, 70 spm = 80 psi = 3 bblloss in 5 min, 80 spm = 100 psi = 4 bbl loss in 5 min, 90 spm = 120 psi = 5 bblloss in 5 min RID and UD tubing hanger, NORM test Change elevators, UD 5 1/2" tubing to SSSV RID, UD Halliburton control line spool, retrieve 3 ss bands, 23 clamps UD 5 1/2" tubing, retrieve 82 full, jts plus jewelry, 83 jt 31.61 ft, total 3533.58 ft RID tubing tools, RlU to run DP Install wear bushing PIU Baker fishing tools, strap Wait on orders Prin\ed: 10/15/2001 12:39:19 PM ( (" BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 0-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/22/2001 08:00 - 10:30 2.50 PULL P DECOMP M/U Baker fishing tools 8 1/8" overshot 10:30 - 12:30 2.00 PULL P DECOMP RIH wI fishing tools, DCs, 4" DP. Wash last stand to bottom with 50 SPM @ 230 PSI. Wash over fish and observe pressure increase. Stop pumps. Pressure not bleeding off. Latch on fish at 3564 ft RKB 12:30 - 22:30 10.00 PULL P DECOMP Jar on fish with 300,000,. No movement off bottom. Attempt to break circulation with 2,000 PSI to no avail. String holding pressure. 22:30 - 23:30 1.00 PULL P DECOMP Change out bales on top drive to prepare for wireline 23:30 - 00:00 0.50 PULL P DECOMP Spot Schulmberger wireline unit 9/23/2001 00:00 - 01 :00 1.00 PULL P DECOMP RlU Schlumberger wireline sheaves 01 :00 - 05:30 4.50 PULL P DECOMP Run freepoint tool, 7 check points. 2% free @ 8713; 23% from 8120 to 7600; 40% @ 7500; 73% @ 6500; 95% @ 6100. 05:30 - 08:30 3.00 PULL P DECOMP RID freepoint tools, wait on Schlumberger to deliver perf guns 08:30 - 10:30 2.00 PULL P DECOMP PJSM, RIH wI perf guns, perf 8745 to 8750 at 9 shots per foot 10:30 - 11 :00 0.50 PULL P DECOMP RID perf guns, 100 % shot 11 :00 - 11 :30 0.50 PULL P DECOMP Attempt to establish circulation, pressure up to 3000 psi, no bled off 11 :30 - 12:30 1.00 PULL P DECOMP RIH wI perf gun # 2, perf 8155 to 8160 at 9 shoots per foot 12:30 - 13:00 0.50 PULL P DECOMP POOH wI wireline, guns 100% shot, stand back wireline in derrick 13:00 - 20:30 7.50 PULL P DECOMP Attempt to circ, pressure up to 3000 psi, bled off slowly, establish circ rate at 5 bpm 1170 psi, loss circ, pack off, work pipe, establish circ, steady loss, returns of sand and silt, 30 spm at 300 psi = 1 bbll minute, viscosity sea water, loss of 85 bbls, take on more sea water, circ loss 1.5 bbls I minute, gas bubble to surface, circ out, at 5 bbl 1 min no loss, increase spm, to 9 bbll min, circ.until shakers clean up. 20:30 - 21 :00 0.50 PULL P DECOMP RIU to shoot casing collar, put 6 turns in drill string, pull 260 K in string, set slips. Attach elevators to string. 21 :00 - 23:00 2.00 PULL P DECOMP RIH wI CCL and string shot, log in place at collar at 8142', shoot 23:00 - 00:00 1.00 PULL P DECOMP RID wireline, confirm fish parted, rig out wireline, change bales 9/24/2001 00:00 - 00:30 0.50 PULL P DECOMP RlU elevators, pump dry job 00:30 - 02:00 1.50 PULL P DECOMP POOH wI fish, hole taking proper displacement on trip out. 02:00 - 04:30 2.50 PULL P DECOMP C/O elevators, bled off oil jars, release from fish, RID, UD fishing tools, make service breaks 04:30 - 05:30 1.00 PULL P DECOMP RlU to UD tubing, clean rig floor 05:30 - 10:00 4.50 PULL P DECOMP POOH w/5 1/2" tubing, UD tubing, recover 106 jts, 5 GLM 10:00 - 10:30 0.50 PULL P DECOMP RID tubing tools, clean rig floor 10:30 - 11 :00 0.50 PULL P DECOMP Pull wear bushing 11 :00 - 13:30 2.50 PULL P DECOMP P/U 1 jt %' DP, MIU pack off running tool, "J" in lock downs, PJSM, pull 9 5/8" pack off, broken junk ring, RID landing jt, RlU for storm packer 13:30 - 15:00 1.50 PULL P DECOMP RIH wI storm packer set at 80' below wellhead 15:00 - 16:00 1.00 PULL P DECOMP NID BOPE, change top pipe rams to 3 1/2" to 5" variable 16:00 - 21:00 5.00 PULL P DECOMP Work on 9 5/8" pack off, retrieve junk ring, install new pack off, pressure test to 5000 psi for 10 minutes, 250 psi for 5 minutes Printed: 10/15/2001 12:39:19 PM ( (' BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 0-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/24/2001 21 :00 - 22:30 1.50 BOPSUF P DECOMP NIU BOPE, pressure test top pipe rams, lower pipe rams, 3500 high, 250 low 22:30 - 23:00 0.50 WHSUR P DECOMP Set wear bushing 23:00 - 00:00 1.00 PULL P DECOMP RIU and retrieve storm packer, LID 9/25/2001 00:00 - 00:30 0.50 PULL P DECOMP Change elevators, stand back DCs, LID RTTS storm packer 00:30 - 01 :00 0.50 PULL P DECOMP Clear and clean rig floor from packer run 01 :00 - 04:00 3.00 PULL P DECOMP P/U, MIU string mills, fit sub, DCs, oil jars, PIU, M/U HWDP from pipe shed 04:00 - 09:00 5.00 PULL P DECOMP Change elevators, PIU, MIU DP from pipe shed and 11 stds from derrick 09:00 - 11 :00 2.00 PULL P DECOMP Displace well bore to 10.7 ppg mud at 11 bpm at 1325 psi 11 :00 - 15:00 4.00 PULL P DECOMP Losing returns, reduce pump to 7 bpm, returns established, losing returns, pump LCM down annulus, 10.7 ppg wI losses of 3 bpm, change to fresh water, fill annulus, pump 130 bbls away, wellbore stablilzes to 0.7 bpm loss 15:00 - 16:30 1.50 PULL P DECOMP POOH, wI flow checks 16:30 - 18:00 1.50 PULL P DECOMP Circulate and squeeze 40 bbl LCM pill at 3550', no retu rns 18:00 - 20:30 2.50 PULL P DECOMP POOH wI flow checks 20:30 - 21 :30 1.00 PULL P DECOMP LID mill run BHA, clean rig floor, change elevators 21 :30 - 22:00 0.50 PULL P DECOMP P/U, MIU RTTS, Halliburton, tools 22:00 - 23:30 1.50 PULL P DECOMP RI H wI RTTS to 2550', 23:30 - 00:00 0.50 PULL P DECOMP Unable to seat at 2550', attempt twice, pull up to 2540', seat OK 9/26/2001 00:00 - 02:00 2.00 PULL P DECOMP PT wI RTTS, at 2540', 3500 psi, 10 minutes, annlus, OK, at 3490', 1000 psi, 10 minutes, annlus, OK, at 3630', 1000 psi, 10 minutes, casing below RTTS, OK, 3630', 110 psi, 1 bpm feed rate, ann Ius 02:00 - 04:00 2.00 PULL P DECOMP POOH wI RTTS 04:00 - 04:30 0.50 PULL P DECOMP RTTS service breaks, LID RTTS 04:30 - 05:00 0.50 PULL P DECOMP P/U, M/U EZSV Halliburton packer 05:00 - 07:00 2.00 PULL P DECOMP RIH wI EZSV 07:00 - 07:30 0.50 PULL P DECOMP Set 9 5/8" EZSV at 3640', confirm wI pressure test 1000 psi, OK, pull out stinger to 3635' 07:30 - 08:00 0.50 PULL P DECOMP Circulate wellbore, 150 psi at 2.5 bpm, PJSM wI cementers 08:00 - 08:30 0.50 PULL P DECOMP Pump 10 bbl H2O to test lines to 3500 psi, OK, mix and pump 55 bbls 10.9 ppg Artic Lite Crete, balance plug wI 27 bbls H2O displacement, 100 % returns 08:30 - 09:00 0.50 PULL P DECOMP Trip out 10 stds to 2682' 09:00 - 09:30 0.50 PULL P DECOMP Circulate 200 bbls H2O at 9.5 bpm at 400 psi, loss of 8 bbls, 2 bbls cement to surface 09:30 - 10:30 1.00 PULL P DECOMP Squeeze additional 20 bbls at 1 bpm, max 410 psi, held for 10 minutes, bled to 220 psi, bled off, no returns 10:30 - 11 :30 1.00 PULL P DECOMP POOH wI EZSV running tool 11 :30 - 12:00 0.50 PULL P DECOMP LID EZSV running tools 12:00 - 13:00 1.00 PULL P DECOMP PLSM, pull wear bushing, set test plug 13:00 - 14:00 1.00 PULL P DECOMP RIU test manifold, TIW, dart valve 14:00 - 18:00 4.00 PULL P DECOMP Pressure test BOPE, 250 psi for 5 minutes, 3500 psi for 10 minutes, OK Printed: 10/15/2001 12:39:19 PM (' (" BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-18 D-18A REENTER+COMPLETE NABORS NABORS 7ES Start: Rig Release: Rig Number: 9/20/2001 Spud Date: 9/20/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 9/26/2001 18:00 - 19:00 1.00 PULL P DECOMP RID test equipment, pull test plug, run wear bushing 19:00 - 20:30 1.50 PULL P DECOMP M/U BHA #2 20:30 - 21 :30 1.00 PULL P DECOMP RIH wI BHA #2, 1900', fill pipe 21 :30 - 22:30 1.00 PULL P DECOMP Slip and cut drilling line 22:30 - 00:00 1.50 PULL P DECOMP RIH wI BHA #2, 2758', wash to 2951', slight cement stringers 9/27/2001 00:00 - 01 :00 1.00 PULL P DECOMP Wash from 2951 to 3430' 01 :00 - 01 :30 0.50 PULL P DECOMP Tag cement, drill cement from 3430 to 3479' 01 :30 - 02:30 1.00 PULL P DECOMP Circulate wellbore, all 4 shakers blinded off, cement and LCM 02:30 - 04:00 1.50 PULL P DECOMP Drill cement from 3479 to 3636' 04:00 - 04:30 0.50 PULL P DECOMP Circulate wellbore untill mud out and mud in equal, 8.7 ppg 04:30 - 05:30 1.00 PULL P DECOMP FIT, pump untill 270 psi, broke down, pump again, broke down at 230 psi, EMW 9.9 ppg 05:30 - 06:00 0.50 PULL P DECOMP Circulate wellbore, monitor losses, 4 bpm at 310 psi 06:00 - 07:00 1.00 PULL P DECOMP Displace wellbore mud to 10.7 ppg, at 10 bpm, 1040 psi losing mud, drop to 7 bpm, losses stablized, drop to 4 bpm, 320 psi 07:00 - 07:30 0.50 PULL P DECOMP Circulate LCM pill, 35 bbls 07:30 - 08:00 0.50 PULL P DECOMP Trip out 5 stds 08:00 - 08:30 0.50 PULL P DECOMP Circulate annulus, fill annulus, losing 1 bbll minute 08:30 - 09:00 0.50 PULL P DECOMP Trip in to 3636', 5 stds 09:00 - 10:00 1.00 PULL P DECOMP Fill annulus wI 80 bbl H2O, Circ hole losing 1 bbll minute 10:00 - 11 :00 1.00 PULL P DECOMP POOH wI bit. 11 :00 - 12:00 1.00 PULL P DECOMP LID drilling BHA 12:00 - 12:30 0.50 PULL P DECOMP MIU cementing BHA 12:30 - 13:30 1.00 PULL P DECOMP RIH to 3636' 13:30 - 15:00 1.50 PULL P DECOMP Circulate wellbore, change out mud for water, 8 bbll min, 560 psi, wellbore stable. 15:00 - 16:00 1.00 PULL P DECOMP PJSM, Pump 10 bbls water ahead, PT lines to 3000 psi, OK, pump 55 bbls 15.8 ppg "G" cement, pump 27 bbls water, cement at 4 bpm, wI 500 psi, water at 4 bpm, wI 200 psi, lost 15 bbls 16:00 - 17:00 1.00 PULL P DECOMP POOH 10 stds, circulate bottoms up, lost 2 bbls, 17:00 - 18:00 1.00 PULL P DECOMP Squeeze cement, 12 stages, see remarks 18:00 - 19:00 1.00 PULL P DECOMP Hold 590 psi on cement for 1 hour 19:00 - 20:30 1.50 PULL P DECOMP Bleed down pressure at 100 psi I minute, flowed 1.5 bbl back, POOH 20:30 - 21 :00 0.50 PULL P DECOMP LID cementing BHA, clear rig floor, MIU drilling BHA 21 :00 - 00:00 3.00 PULL P DECOMP RIH to 2759', wash to 3190', tag cement at 3190' 9/28/2001 00:00 - 06:30 6.50 PULL P DECOMP Drill cement from 3190' to 3622' 06:30 - 07:00 0.50 PULL P DECOMP Circulate bottoms up at 10 bpm, 1050 psi 07:00 - 07:30 0.50 PULL P DECOMP FIT test, at 480 psi cement plug leaked. EMW of 11.2 ppg Bled to EMW 9.7 ppg 07:30 - 08:00 0.50 PULL P DECOMP Circulate wellbore, monitor losses, 10 bpm at 1140 psi, no losses 08:00 - 09:30 1.50 PULL P DECOMP Drill cement from 3622' to 3640', EZSV plug 09:30 - 16:00 6.50 PULL P DECOMP Push EZSV plug to bottom, stage in 10 stds, circulate bottoms up, condition fluids, final circulation at 8134', 1220 psi at 8 bpm 16:00 - 19:30 3.50 PULL P DECOMP Pump dry job, POOH wI bit. Hole fill showing well static. 19:30 - 21 :00 1.50 PULL P DECOMP LID BHA, function blind rams Printed: 10/15/2001 12:39:19 PM ( f BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: D-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/28/2001 21 :00 - 21 :30 0.50 PULL P DECOMP Clean and clear rig floor 21 :30 - 22:00 0.50 PULL P DECOMP Pull wear bushing 22:00 - 00:00 2.00 PULL P DECOMP PJSM, Rig up to run liner, C/O bales, PIU casing tools, RIU casing tools 9/29/2001 00:00 - 01 :00 1.00 PULL P DECOMP Load 7 5/8" liner in pipe shed, strap, drift, clean and inspect threads 01 :00 - 02:00 1.00 PULL P DECOMP Make up 7" casing, 2 jts with float equipment, XIO to 7 5/8" casing, change out 7" tools to 75/8" running tools 02:00 - 13:00 11.00 PULL P DECOMP PJSM, RIH wI 75/8" casing, control running speed for surge pressure, monitor wellbore fluids, ran 138 jts, L-80, ST-L, 13:00 - 14:00 1.00 PULL P DECOMP RID slips, CIO elevators, P/U, MIU Baker packer, inspect, RIH 14:00 - 15:00 1.00 PULL P DECOMP RIH wI 5" HWDP, control running speed, as per Baker 15:00 - 16:30 1.50 PULL P DECOMP Circulate casing at 6 bpm, 440 psi, after 226 bbls, loss of 11 bbls, RID casing equipment, clear rig floor, C/O bales 16:30 - 20:00 3.50 PULL P DECOMP RIH wI 4" DP, control running speed, tag bottom at 8133', PIU single and 10' pup from pipe shed, M/U cement head, RIH to 8130' 20:00 - 22:30 2.50 PULL P DECOMP PJSM, cement wI Dowell, 89 bbls lead, 25 bbls tail, displace cement wI 10.5 ppg mud with rig pump, set hanger and packer wI cement pump, liner top 2502', landing collar 8046' 22:30 - 00:00 1.50 PULL P DECOMP WI rig pump pressure up inside casing to 400 psi, pull out of packer assembly and circulate with mud untill water displaced from wellbore, no cement returns 9/30/2001 00:00 - 03:00 3.00 PULL P DECOMP PJSM, POOH wI Baker running tool, LID HWDP 03:00 - 03:30 0.50 PULL P DECOMP Install wear bushing, clear rig floor, service rig 03:30 - 10:00 6.50 PULL P DECOMP MIU, RIH wI mule shoe and mills, break circ at 4300 ft, clean returns. No excessive drag, tagged at 8046', landing collar 10:00 - 11 :00 1.00 PULL P DECOMP Circulate bottoms up. Clean returns. 11 :00 - 11 :30 0.50 PULL P DECOMP Pressure test casing to 3500 psi for 30 minutes, OK 11 :30 - 12:00 0.50 PULL P DECOMP POOH to 6700' 12:00 - 12:30 0.50 PULL P DECOMP PJSM, rig service 12:30 - 14:30 2.00 PULL P DECOMP POOH 14:30 - 15:30 1.00 PULL P DECOMP LID BHA, function blind rams 15:30 - 17:00 1.50 PULL P DECOMP Clear rig floor, P/U BHA, MIU whipstock 17:00 - 18:30 1.50 PULL P DECOMP RIH wI BHA, DCs, HWDP, 4" DP, test MWD, OK 18:30 - 22:00 3.50 PULL P DECOMP RIH, control running speed, entry of liner top, good 22:00 - 23:00 1.00 PULL P DECOMP Slip and cut drilling line 23:00 - 00:00 1.00 PULL P DECOMP RIH wI whipstock to 6846', control running speed 10/1/2001 00:00 - 01 :30 1.50 STWHIP P INT1 Con't RIH wI 7 5/8" whipstock to 7975 ft 01 :30 - 02:30 1.00 STWHIP P INT1 Orient whipstock to 81 degrees Rt of HS. Tag LC @ 8046 ft. Confirm orientation. Trip btm anchor wI 18,000 #. Confirm anchor tripped wI 10,000 # over pull. Shear bolts wI 35,000# 02:30 - 12:30 10.00 STWHIP P INn Mill 6 3/4" window through 7 5/8" x 9 5/8" casing to 8059 ft. 12:30 - 13:30 1.00 STWHIP P INT1 Circ hole clean. POH to 8020 ft. 13:30 - 14:00 0.50 STWHIP P INT1 Perform FIT to EMW of 12.0 ppg MW. 14:00 - 17:00 3.00 STWHIP P INT1 Flow check, pump dry job. POH wI mill assy. 17:00 - 19:00 2.00 STWHIP P INT1 Change out handling equipment. LD BHA. Mills in gauge. 19:00 - 20:00 1.00 STWHIP P INT1 Clear rig floor. Jet clean BOP. Function blind rams 20:00 - 22:30 2.50 DRILL P INT1 PU & MU directional BHA. Upload MWD 22:30 - 23:30 1.00 DRILL P INT1 Change out handling equipment. Shallow test MWD. Rig Printed: 10/15/2001 12: 39: 19 PM ( ( BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: D-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/1/2001 22:30 - 23:30 1.00 DRILL P INn service 23:30 - 00:00 0.50 DRILL P INn RIH w/6 3/4" directional assy. 1 0/2/2001 00:00 - 03:00 3.00 DRILL P INn Continue RIH with drilling assembly to 7,480'. 03:00 - 04:30 1.50 DRILL P INn Tie in pass from 7,480' to 7,550' at less than 60 fph at 300 gpm. 04:30 - 05:00 0.50 DRILL P INn Conitnue RIH. Obtain baseline PWD data. Orient through window. 05:00 - 22:00 17.00 DRILL P INn Drill from 8,027' to 9,000'. Prepare for short trip. 22:00 - 22:30 0.50 DRILL P INn Obtain SPR. Flow check. Well static. 22:30 - 23:30 1.00 DRILL P INn Short trip to 8,230'. Hole in good shape. No excess drag. RIH and wash last stand to bottom from 8,904' to 9,000'. No fill. 23:30 - 00:00 0.50 DRILL P INn Drill from 9,000' to 9,096'. 10/3/2001 00:00 - 17:00 17.00 DRILL P INT1 Drill from 9,096' to the top of the Sag River at 10,205'. AST=1, ART=12. 17:00 - 18:30 1.50 DRILL P INT1 Pump weighted sweep and circulate to surface. 18:30 - 20:30 2.00 DRILL P INT1 Flow check. Well static. Short trip to 8,900'. Hole in excellent shape. No tight spots. Wash to bottom from 10,055'. No fill. 20:30 - 22:30 2.00 DRILL P INT1 Circulate weighted sweep. Flow check. Well static. Drop Sperry EMS. 22:30 - 00:00 1.50 DRILL P INT1 POH to 8,800'. 10/4/2001 00:00 - 05:00 5.00 DRILL P INT1 Con't POH w/6 3/4" bit. No drag. Flow checks I hole fill showing hole static. 05:00 - 07:00 2.00 DRILL P INn PJSM. LD BHA. Download MWD 07:00 - 07:30 0.50 CASE P INn PJSM. Clear floor, RU to run 51/2" STL casing 07:30 - 11 :00 3.50 CASE P INn RIH wI 5 1/2" liner. Check floats. Fill pipe on the fly, top off every 5 jts. MU liner hanger I packer. Circ btms up. 11 :00 - 11 :30 0.50 CASE P INT1 RD casing equipment 11 :30 - 17:00 5.50 CASE P INT1 PJSM. RIH w/5 1/2" liner on 4" DP at controlled running speed to window @ 8027 ft. Fill pipe every 10 stds. 17:00 - 17:30 0.50 CASE P INT1 MU cement head and rack back. 17:30 - 18:30 1.00 CASE P INT1 Circ btms up. Check & record all string parameters. 18:30 - 20:30 2.00 CASE P INT1 Con't RIH w/5 1/2" liner on 4" DP to 10,025 ft. Tight spot @ 9450 ft. Attempt to circ - no success. 20:30 - 22:30 2.00 CASE P INT1 Work pipe up hole, establish circ @ 9257 ft @ 4 BPM wI 800 psi. 22:30 - 00:00 1.50 CASE P INT1 Wash liner to 9642 ft @ 4 BPM wI 670 psi 10/5/2001 00:00 - 06:00 6.00 CASE P LNR1 POH w/5 1/2" liner from 9,642' to 9,350' working pipe and attempt to establish circulation. Established circulation at 9,360'. Circulate at 2 bpm, 440 psi and wash liner down slowly. Liner taking weight and packing off. Liner packed off at 10,025'. POH and establish circulation at 9,840'. 06:00 - 12:00 6.00 P LNR1 Stage circulation rate up slowly to 3.7 bpm at 770 psi. Circulate total volume of 2 times the liner x OH annulus volume. Run I wash 5 1/2" liner down to 1 0, 175' at 2 bpm and 490 psi taking small "bites". Liner packing off while RIH. Establish good circulation and weight prior to continuing to RIH. Unable to move pipe and circulate at 10,175'. Work pipe free. Continue to work pipe from 9,975' to 10,075'. Unable to establish circulation. 12:00 - 16:30 4.50 CASE N DPRB LNR1 POH wI liner. Work tight spot at 9,546'. 16:30 - 17:30 1.00 CASE P LNR1 Slip and cut drilling line at 5,030'. 17:30 - 18:30 1.00 CASE N DPRB LNR1 Continue to POH to 2,355'. 18:30 - 20:00 1.50 CASE N DPRB LNR1 LD liner top packer and hanger. RU liner handling equipment. Printed: 10/15/2001 12:39:19 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: D-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/5/2001 20:00 - 00:00 4.00 CASE N DPRB LNR1 LD 5 1/2" liner to 120'. 1 0/6/2001 00:00 - 01 :30 1.50 CASE N DPRB LNR1 Clear rig floor of casing tools. 01 :30 - 02:00 0.50 CASE N DPRB LNR1 Drain stack and pull wear bushing. 02:00 - 08:00 6.00 CASE N DPRB LNR1 Test BOP as per BP policy and AOGCC regulations to 250 psi low and 3,500 psi high. 08:00 - 08:30 0.50 CASE N DPRB LNR1 Install wear bushing. 08:30 - 09:00 0.50 CASE N DPRB LNR1 MU BHA w/6 3/4" Smith porcupine reamer. 09:00 - 12:00 3.00 CASE N DPRB LNR1 RIH to window at 8,027'. 12:00 - 13:00 1.00 CASE N DPRB LNR1 Circulate bottoms up. PU=150K, SO=132K. 13:00 -14:00 1.00 CASE N DPRB LNR1 Conitnue to TIH to 10,120'. Tag up on tight spot. 14:00 - 15:00 1.00 CASE N DPRB LNR1 Wash and ream from 10,120' to 10,205'. 15:00 - 18:00 3.00 CASE N DPRB LNR1 Circulate low vis. sweep followed by high vis sweep to clean the hole. Vary RPM from 55 - 110 while circulating sweeps. 18:00 - 19:30 1.50 CASE N DPRB LNR1 POH to 7,865'. 19:30 - 20:00 0.50 CASE N DPRB LNR1 Flow check. Well static. Pump dry job. Drop 2" rabbit. 20:00 - 22:30 2.50 CASE N DPRB LNR1 POH. 22:30 - 23:30 1.00 CASE N DPRB LNR1 LD BHA. 23:30 - 00:00 0.50 CASE N DPRB LNR1 RU to run liner. 1 0/7/2001 00:00 - 01 :00 1.00 CASE N DPRB LNR1 Con't RU for 51/2" liner. PJSM. 01 :00 - 03:00 2.00 CASE N DPRB LNR1 PU & RIH 5 1/2" shoe track, check floats, con't run liner. 03:00 - 03:30 0.50 CASE N DPRB LNR1 PU & MU Baker 51/2" x 7 5/8" 'Flex Lock Hng and ZXP Packer 03:30 - 04:00 0.50 CASE N DPRB LNR1 Circ liner volume 5 BPM I 200 psi. Clear floor of casing handling equipment. 04:00 - 08:00 4.00 CASE N DPRB LNR1 Con't RIH w/5 1/2" liner on 4" DP to 8000 ft. Fill pipe every 950 ft. 08:00 - 09:00 1.00 CASE N DPRB LNR1 CBU @ 7 BPM 11050 psi. Clean returns 09:00 - 11 :00 2.00 CASE N DPRB LNR1 Con't RIH w/5 1/2" liner on 4" DP to 10,205 ft. Work pipe break circ. 11 :00 - 13:30 2.50 CASE P LNR1 Circ well. Stage pumps up to 4.5 BPM I 930 psi 13:30 - 14:30 1.00 CASE P LNR1 PJSM. Pump 5 bbls, 11.5 ppg Mud Push, test lines 4000 psi. Pump 30 bbls Mud Push, 27 bbls 15.8 ppg slurry. Drop plug. Displace wI 136 bbls mud, bump plugl set hanger wI 3500 psi. Check floats O-K. 14:30 - 16:00 1.50 CASE P LNR1 Release from 5 1/2" x 7 5/8" hanger, set ZXP packer. Nescessary to repeat steps for packer setting procedures. Surface indications of good set. 16:00 - 17:00 1.00 CASE P LNR1 CBU to ensure DP clean. 17:00 - 22:00 5.00 CASE P LNR1 PJSM RD Cement head. POH wI liner running tool. 22:00 - 23:00 1.00 CASE P LNR1 Clear floor. RU 2 7/8" handling equip. 23:00 - 00:00 1.00 CASE P LNR1 Attempt to test 5 1/2" x 7 5/8" x 95/8" casing. Test to EMW of 12.9 ppg. 10/8/2001 00:00 - 01 :30 1.50 DRILL P PROD1 PJSM. Slip & cut drlg line 01 :30 - 02:00 0.50 DRILL P PROD1 Rig Service 02:00 - 07:00 5.00 DRILL N DFAL PROD1 MU & RIH wI seal assy on 'ZXP' pkr. Tag 5 1/2" TOL @ 7855 ft. 07:00 - 08:30 1.50 DRILL N DFAL PROD1 PJSM. Sting into liner top @ 7855 ft. Test 5 1/2" liner I floats to 1000 psi. O-K. Attempt to test liner top packer I annulus. No sucess. Unsting from liner top, drop ball seat same wI 500 psi. Sting into liner top tie back, set pkr wI 3000 psi. 08:30 - 09:30 1.00 DRILL P PROD1 Test 5 1/2"x7 5/8"x9 51" csg 3500 psi 130 mins. O-K. 09:30 - 12:30 3.00 DRILL N DFAL PROD1 POH wI running tool, LD same 12:30 - 13:30 1.00 DRILL P PROD1 Clear floor. RU 2 7/8" handling equipment. 13:30 - 16:30 3.00 DRILL P PROD1 PJSM. MU BHA. Upload MWD. Surface test same. ( ( Printed: 10/15/2001 12:39:19 PM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: D-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/8/2001 16:30 - 21 :00 4.50 DRILL P PROD1 RIH w/4 3/4" bit on 2 7/8" DP from pipe shed. Circ DP volume every 500 ft 21 :00 - 00:00 3.00 DRILL P PROD1 Con't RIH w/4 3/4" bit on 4" DP 10/9/2001 00:00 - 01 :30 1.50 DRILL P PROD1 RIH W/4 3/4" BIT ON 4" DP TO LANDING COLLAR AT 10120' 01 :30 - 03:30 2.00 DRILL P PROD1 DRILL SHOE TRACK TO 10198' , 7' ABOVE FLOAT SHOE AT 10205', WHILE DISPLACING HOLE TO 8.4 PPG QUICKDRIL MUD 03:30 - 04:30 1.00 DRILL P PROD1 FINISHED DISPLACING HOLE TO 8.4 PPG QUICKDRIL MUD, TAKE SPR AND SPP 04:30 - 05:00 0.50 DRILL P PROD1 DRILL CMT AND FLOAT SHOE TO 10205', FLOW CHECK WELL, STABLE 05:00 - 06:00 1.00 DRILL P PROD1 DRLD WI .78 DEGREE MOTOR, LOG WI MWD-GR-RES FI 10205' - 10225' MD/8561, TVD 06:00 - 07:00 1.00 DRILL P PROD1 PULL INTO SHOE AT 10205' MD/8542' TVD, PERFORM FIT TO 9.6 PPG EMW WI 8.4 PPG QUICKDRIL MUD AT 520 PSI 07:00 - 23:30 16.50 DRILL P PROD1 DRLD W/.78 DEGREE MOTOR, LOG WI MWD-GR-RES FI 10225' -10765', BIT TORQUEING UP AND MOTOR STALLING OUT, TOTAL K-REVS ON BIT +1-184K, ADT 14.7 HRS, ART - 13.45 HRS, AST - 1.25 HRS, LITHOLOGY - 70% SANDSTONE, 30% CHERT 23:30 - 00:00 0.50 DRILL P PROD1 CBU 10/10/2001 00:00 - 01 :30 1.50 DRILL P PROD1 CBU, MONITOR WELL, STABLE 01 :30 - 08:00 6.50 DRILL P PROD1 POH TO BHA, NO HOLE PROBLEMS 08:00 - 09:00 1.00 DRILL P PROD1 LID JARS, PBL SUB, STD BACK DC'S, LD BIT AND MOTOR 09:00 - 10:00 1.00 DRILL P PROD1 DOWNLOAD/UPLOAD MWD-GR-RES 10:00 - 11 :00 1.00 DRILL P PROD1 MU BHA, RIH 11 :00 - 12:00 1.00 DRILL P PROD1 RIH TO 800', SHALLOW HOLE TEST MOTOR AND MWD-GR-RES 12:00 - 16:00 4.00 DRILL P PROD1 RIH F/800' - 9940' 16:00 - 17:00 1.00 DRILL P PROD1 CUT AND SLIP DRILLING LINE 17:00 - 17:30 0.50 DRILL P PROD1 RIH F/9940' - 10474' 17:30 - 18:30 1.00 DRILL P PROD1 PRECAUTIONARY REAM AND WASH F/10474' - 10765', TAGGED UNDERGAUGE HOLE AT 10560' 18:30 - 21 :00 2.50 DRILL P PROD1 DRILL W/.78 MOTOR, LOG WI MWD-GR-RES F/10765'- 10895', AVG ROP 65 FPH, ART 2 HRS 21 :00 - 00:00 3.00 DRILL P PROD1 PUMP AROUND LO-HI VIS SWEEP, SPOT LINER RUNNING PILL ON BOTTOM 10/11/2001 00:00 - 02:00 2.00 DRILL P PROD1 POH F/10895' TO 7900', MONITOR WELL, STABLE, NO HOLE PROBLEMS 02:00 - 03:30 1.50 DRILL P PROD1 OPEN PBL SUB, CIRC, ROTATE AND RECIPROCATE HOLE CLEAN AT 8 BPM, 30 RPM, DROP RABBIT 03:30 - 10:00 6.50 DRILL P PROD1 POH, LID 24 JTS OF 27/8" DP, SLM + 2.40', NO CORRECTIONS MADE 10:00 - 12:00 2.00 DRILL P PROD1 RECOVERED RABBIT, LID BHA, DOWNLOAD MWD-GR-RES 12:00 - 14:30 2.50 CASE P COMP PIU, R/U 3 1/2" HANDLING TOOLS, COMPUTER AND POWER TONGS FOR 13CR LINER 14:30 -15:00 0.50 CASE P COMP PJSM ON HANDLING AND RUNNING 31/2" 13CR LINER WI ALL INVOLVED PERSONNEL 15:00 - 18:30 3.50 CASE P COMP MIU, RIH W/31/2" 9.2#, 13CR80, NSCT SHOE TRACK, BAKERLOC ALL CONNECTIONS THROUGH THE X-O PUP JT ON TOP OF LANDING COLLAR, FILLED PIPE, CHECK FLOATS, OK, P/U, RIH W/31/2"9.2# 13CR80 VAM ACE (' (" ..J.. Printed: 10/15/2001 12:39:19 PM BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: D-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/11/2001 15:00 - 18:30 3.50 CASE P COMP LINER, MIU LINER HGR ASSY WI LINER PKRlTIEBACK SLEEVE, RIH ON 1 STD OF DP, PIU AND SIO WT AT 57K 18:30 - 00:00 5.50 CASE P COMP RIH W/3 1/2" 13CR LINER ON 2 7/8" X 4" TAPERED WORKSTRING 10/12/2001 00:00 - 03:30 3.50 CASE P COMP RIH W/3 1/2" 13CR LINER ON 2 7/8" X 4" TAPERED WORKSTRING TO 10180' 03:30 - 05:30 2.00 CASE P COMP CIRC ANNULUS VOL. AT 3.5 BPM, 800 PSI, MU CMT HD, LAY OUT ON SKATE 05:30 - 07:30 2.00 CASE P COMP RIH OPEN HOLE TO 10872', PIU CMT HD, RU CMT LINE, WSH TO BTM AT 10895', NO HOLE PROBLEMS 07:30 - 09:30 2.00 CEMT P COMP STAGED PUMPS UP F/1 TO 4 BPM AT 1080 PSI WHILE RECIPROCATING LINER, HELD PJSM WI ALL INVOLVED PERSONNEL ON CMT JOB 09:30 - 10:15 0.75 CEMT P COMP FLUSH THRU SURFACE CMT LINE, TEST SAME TO 4500 PSI, HALLIBURTON VALVE IN CMT LINE FAILED, REPLACED SAME 10: 15 - 11 :30 1.25 CEMT P COMP PUMPED CMT JOB AS FOLLOWS: TEST LINES TO 4500 PSI, PUMPED 20 BBL CW SPACER AT 3.1 BPM, 900 PSI, 20 BBLS OF MUDPUSH AT 3.1 BPM, 880 PSI, 21 BBLS OF 15.8 PPG CL "G" CMT SLURRY WI ADDITIVES AT 3.5 BPM 820-450 PSI, SHUT DOWN TO FLUSH OUT EXCESS CMT FI SURFACE LINE FI CMT TRUCK TO CMT HEAD AND DROP DP DART, PUMPED 2.1 BBLS, NO FLUID FLUSHED OUT OF CMT LINE, SHUT HALLIBURTON VALVE AT "T", SWITCHED TRIP MECHANISM ON CMT HD TO RELEASE DP DART, PUMPED 2.3 BBLS, HAD NO INDICATION OF DART LEAVING CMT HD, DROPPED SECOND DP DART, SHUTING DOWN PUMPS WHEN PLUG BUMPED AT 95 BBLS (ACTUAL COUNT FI CMT DISPLACEMENT TANKS OR 98.4 FI THE MICRO MONITOR(COMPUTER), PUMP RATE AND PRESSURE AT TIME OF BUMPING PLUG WAS 2130 PSI, INCREASED PRESSURE TO 3500 PSI TO SET LINER HANGER. CIP AT 11 :19 HRS ON 10/12/2001. TOL AT 10024', FL T SHOE AT 10895', FLT COLLAR AT 10828', LNDG COLLAR AT 10794'. NOTE: BAKER REPRESENTATIVES BROKE DOWN THE CMT HEAD AT THEIR SHOP WI ME AS A WITNESS, FOUND DP DART TRAPPED BETWEEN FLAPPER AND PLUG CARRIER OF CMT HEAD. CONFIRMS THAT 4.4 BBLS OF PERF PILL WAS PUMPED AHEAD OF SECOND DP DART, OVER DISPLACING SHOE TRACK AND 3.7 BBLS OF 31/2" X 43/4" ANNULUS 11 :30 - 12:00 0.50 CEMT P COMP RELEASE FI LINER HGR WHILE HOLDING 1000 PSI, CIRC 20 BBLS, PU WT 210K, S/O WT 145K, SET LINER TOP PKR WI SO WT OF 95K AND 80K, ALSO, SIO WHILE ROTATING AT 25 RPM AND 65K DN ON LINER PKR, HAD SURFACE INDICATION OF PKR SETING AT 130K SO WT, CONTINUED SO TO 80K 12:00 - 13:30 1.50 CEMT P COMP CBU'S WI 8.4 PPG MUD, RECOVERED 100 BBLS OF CONTAMINATED MUD WI CMT AND SPACERS, EST CMT RECOVED 10 BBLS, SWITCH OVER TO SEAWATER, DISPLACED WELL WI 8-10 BPM AT 2650-3150 PSI 13:30 -14:00 0.50 CEMT P COMP WENT THRU SETTING MOTIONS FOR LINER TOP PKR ONE MORE TIME, ROTATED AND SIO TO 80 K, OK (" ( Printed: 10/15/2001 12:39:19 PM BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 0-18 Common Well Name: D-18A Spud Date: 9/20/2001 Event Name: REENTER+COMPLETE Start: 9/20/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/12/2001 14:00 - 14:30 0.50 CEMT P COMP RD, LD CMT HD, CLEARED AND CLEANED FLOOR 14:30 - 19:30 5.00 CEMT P COMP MONITOR WELL, STABLE, POH, LD 4" DP 19:30 - 20:30 1.00 CEMT P COMP TIH WI 35 STDS OF 4" DP 20:30 - 00:00 3.50 CEMT P COMP POH, LD 4" DP 10/13/2001 00:00 - 00:30 0.50 CASE P COMP Change elevators. RU stacked tongs to LD 2 7/8" DP. 00:30 - 03:00 2.50 CASE P COMP LD 27/8" DP. 03:00 - 04:00 1.00 CASE P COMP Pressure test 3 1/2" liner and well bore above to 3,500 psi for 30 minutes. 04:00 - 05:00 1.00 CASE P COMP RU to run tapered tubing string: 3 1/2", 9.2#, 13Cr-80, Vam Ace tubing x 41/2",12.6#, 13Cr-80, TDS (Condition B). 05:00 - 05:30 0.50 CASE P COMP Pull wear bushing. 05:30 - 06:00 0.50 CASE P COMP PJSM. 06:00 - 09:30 3.50 CASE P COMP Run 3 1/2", 9.2#, 13Cr-80, Vam Ace tubing. 09:30 - 10:00 0.50 CASE P COMP Change elevators and tong dies for running 4 1/2" tubing. 10:00 - 00:00 14.00 CASE P COMP Run 41/2",12.6#, 13Cr-80, TDS condition B tubing to 7,841'. ( (' Printed: 10/15/2001 12:39:19 PM ( ( Well: D-18A Rig Accept: 09/20/01 Field: Prudhoe Bay Unit Rig Spud: 10/02/01 API: 50-029-20694-01 Rig Release: 10/14/01 Permit: 201-103 Drilling Rig: Doyon 14 ---_.._-~-,~.._._----------"-----_._~_.~_._--_._-------_.__."--,_._--_.._._-~.._._--_..~,_.._._"-_._------_.'-'.---'-"-.---------".--..---.-._u_------.----.---..-"-.'-'"'---".-"'-"-""'--"-'-"-.'.-.'-----'---. POST RIG WORK 1 0/26/01 ASSIST IN PULLING BPV. 10/27/01 PULLED RP SHEAR VALVE AND DGLV FROM ST'S # 4 &3 RESPECTIVELY. PULL RHC-M PLUG. DRIFT TO 10622' WLM W/ 2.5" X 10' DUMMY GUN (NEEDED 10,682'), POOH. 10/28/01 WORK 2.5 BAILER TO 10692' WLM. STUCK BAILER. WHILE ATTEMPTING TO GET TOOLS FREE THE WIRE BROKE @ COUNTER HEAD. COMMENCE FISHING WIRE AND TOOLSTRING. RECOVERED ALL OF THE WIRE & TOOLS. NOTIFIED PAD OP. OF WELL STATUS 11/04/01 RIH W/2.70" 3-BLADE CEMENT MILL AND 2-3/8" MHA TO 10775' CTM (LANDING COLLAR). NO OBSTRUCTIONS NOTICED. MADE SEVERAL MILL PASSES OVER PLANNED LOGGING INTERVAL (10500' - 10775') TO CLEAR ANY REMAINING DEBRIS - NO WEAR ON MILL. FREEZE PROTECTED WITH 60/40 MEOH TO 2500'. NOTIFY DSO, RDMO. 11/07/01 D/T @ 10762' SLM W/ 2.5 DUMMY GUN (TARGET = 10682'). WELL LEFT SI. 11/08/01 LOG RST SIGMA/POROSITY FROM TD @ 10800-10200, FIELD PICK GOC @ 10590. LOG GR/CCL CORRELATION FROM TD 10800-7250. LOG SCMT BOND LOG FROM TD 10800-10200, GOOD CEMENT FROM 10200' - 10480', FAIR TO POOR CEMENT FROM 10480' - 10740', NO CEMENT FROM 10740' - 10800'. 11/23/01 PERFORATED INTERVAL 18' INTERVAL (10674'-10692'), STUCK GUN POOH. .- 11/24/01 ATTEMPTED TO PULL GUN. 11/25/01 UNABLE TO PULL GUN. CABLE CUT WITH KINLEY CUTTER. 27' FISH LEFT IN HOLE + 210' CABLE. 12/04/01 RAN FINDER & WIRE GRAB TO TOP OF FISH @ 9982' BLM. NO RECOVERY. RAN 2.3" LIB TO TOP OF FISH. HAD PICTURE OF CABLE HEAD & LINE. WORK IN PROGRESS. GUN BY-PASSED 210' OF .23" E-LINE AFTER BEING SHOT, STUCK AT 9982'. 12/05/01 ATTEMPT TO FISH PERF GUN FROM 9982' BLM. WORK IN PROGRESS. 12/06/01 FISHED CABLE HEAD, SWIVEL, & CCL (4' 8" TOTAL LENGTH) OOH. PARTED @ ALLEN SCREWS (WORK IN PROGRESS). D-18A, Post Rig Sidetrack Page 2 I( ( 12/07/01 FISHED 20' OF E-LINE. SET BAITED OVERSHOT ON PERF GUN @ 10,024' SLM. MADE SEVERAL ATTEMPTS AT PULLING GUN WI .125" WIRE. RD S/L. RU BRAIDED LINE. WORK IN PROGRESS. 12/08101 ATTEMPT TO PULL PERF GUN FROM 9985' BLM. WORK IN PROGRESS. 12/09/01 JARRED FOUR+ HRS ON PERF GUN @ 9980' BLM. SAW NO MOVEMENT. RDMO. LEFT WELL SHUT-IN. NOTE: 3 1/2" G-BAIT SUB & OVERSHOT IN HOLE LATCHED ON TO FISH. 12/13/01 PERFORM WEEKLY BOP TEST. 12/14/01 RIH TO 9800 AND CIRCULATION KILL WELL TO FLOWLINE. MU AND RIH WITH FISHING TOOLS. LATCH FISH AT 10040' CTM, JAR UP Wj15-22K OVER. JARS QUIT WORKING AFTER 45 LICKS. POOH. CUT 150' OF COIL, RE-TOOL, RBIH WIFISHING ASS'Y. LATCH FISH AND JAR UP 56 LICKS AT 42K. NO MOVEMENT. PUMP OFF FISH. POOH. RIH WITH NEW FISHING STRING JOB IN PROGRESS. 12/15/01 LATCH FISH AT 10037 CTMD. JAR UP AND DOWN. PUMP AT 3 B/M WITH DEAD CRUDE. (123 BBLS), PRESSURE UP WELL TO 1000. SD PUMPS CONTINUE JARRING UP AND DOWN. NO MOVEMENT. REPEAT WITH SAME RESULTS. TOTAL OF 56 LICKS UP (32-42K) AND 55 LICKS DOW. NO MOVEMENT. RELEASE FROM FISH AND POH. FREEZE PROTECT FLOWLINE WITH 76 BBLS DEAD CRUDE AND 6 BBLS MEOH. WELL REMAINS SI FOR EVALUATION. ~ ;>"01- 10? ~Ù}-- 15;l )..0 I .. ;2'1 ""'-- 12/19/01 SchlllDberger NO. 1703 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Color Prints CD Job# Log Description Date Blueline Sepia D-18A 21480 RST-SIGMA 11/08/01 1 1 1 D.S. 1-04A 21519 PP, ARC DATA 08/28/01 1 D.S. 1-04A 21519 MD VISION RESISTIVITY 08/28/01 1 1 D.S. 1-04A 21519 TVD VISION RESISTIVITY 08/28/01 1 1 W-02A 21515 CDR DATA 11/22/01 1 W-D2A 21515 MD CDR RESISTIVITY 11/22/01 1 1 W-02A 21515 TVD CDR RESISTIVITY 11/22/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2- 1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Receive~: ú.. Qpq L'"'>, ./ I DEC 2 1 2001 Date Delivered: Ala5ka Oii & Gas CoRS. C;~mffil8SiOÇì Anchorage ~~ 17(,-030 Iq'i-~Jlp ~ol- 10, ;1.01-18Co r g ~- D,;l~ =-- 12112/01 Sc~lunJbepger NO. 1688 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Blueline Sepia Color Prints CD D.S. 4-09 INJECTION PROFILE 11/29/01 1 1 D.S. 11-38A LEAK DETECTION LOG 11/27/01 1 1 D-18A 21495 SCMT 11/08/01 2 E- 1 02 21500 USIT 10/30/01 2 D.S.4-19 21504 SCMT 11/21/01 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED SChlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AnN: Sherrie ReceiV~ {J)O¡¡~ DEC 2 1 2001 Date Delivered: Alaska Oil & Gas Cons.lÃffirruSSiO¡ . AnåRAage ( I( 06-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well D-18A a 0 J;- /0 ':), ~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,997.10' MD Window / Kickoff Survey 8,027.00' MD (if applicable) Projected Survey: 10,895.00' MD Please call me at 273-3545 if you have any questions or concerns. l1d~ ~ ~ Regards, William T. Allen Survey Manager Attachment(s) t""'~ ~r'''''''' .~. . '~qt# ~ ,§ ~ E'"'''''' 'I'. :~, ÎV á-'"'' r' rì'\ & ~ ~ "', ~~ ~>w>' ';¡, ¡¡, , '." '\,.1 I¡"",,,,. ~ ~þ!:J. 1<1 J r.f ~-Ð'J, .~ P.t.\,»~~ NOV 0 7 2001 Aï-'j~jf'~ rJ;! c""" .... ^,r..,,¡r,j~~.... ~., ,~ r;)e ~as t\)N,~~.... V\\h.i'" ,i\nl"1:;,nr"~:t~c, ..i'! V'.. «';":::1""' North Slope Alaska Alaska Drilling & Wells PBU_WOA D Pad, Slot D-18 D-18A Job No. AKMM11159, Surveyed: 10 October, 2001 DEFINITIVE ~'--- SURVEY REPORT 6 November, 2001 Your Ref: API 500292069401 Surface Coordinates: 5958998.00 N, 653469.00 E (70017' 41.7412" N, 148045' 26.3070" W) Kelly Bushing: 73. 11ft above Mean Sea Level -'. spa"""""'y-sul! DRILLING SERVICES A Halliburton Company Survey Ref: svy10991 Sperry-Sun Drilling Services . Survey Report for D-18A Your Ref: API 500292069401 Job No. AKMM11159, Surveyed: 10 October, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs. Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/i OOft) 7997.10 49.280 261.090 6589.53 6662.64 544.40S 3142.13W 5958389.56 N 650338.64 E 3177.58 Tie On Point --. MWD Magnetic 8027.00 49.310 261.240 6609.02 6682.13 547.88 S 3164.53 W 5958385.62 N 650316.31 E 0.393 3200.19 Window Point 8072.55 47.050 264.910 6639.40 6712.51 551.99 S 3198.22 W 5958380.83 N 650282.72 E 7.788 3234.11 8104.98 46.260 266.850 6661.66 6734.77 553.69 S 3221.74 W 5958378.65 N 650259.24 E 4.986 3257.69 8137.37 45.310 269.190 6684.25 6757.36 554.49 S 3244.93 W 5958377.37 N 650236.06 E 5.951 3280.87 8169.30 44.670 271.860 6706.83 6779.94 554.29 S 3267.50 W 5958377.11 N 650213.50 E 6.242 3303.33 8199.99 43.090 273.420 6728.96 6802.07 553.31 S 3288.75 W 5958377.65 N 650192.23 E 6.238 3324.41 8232.01 40.660 273.950 6752.80 6825.91 551.94 S 3310.08 W 5958378.59 N 650170.88 E 7.669 3345.54 8262.58 38.180 274.090 6776.41 6849.52 550.58 S 3329.44 W 5958379.55 N 650151.49 E 8.118 3364.71 8296.34 36.150 276.000 6803.31 6876.42 548.80 S 3349.75 W 5958380.92 N 650131.15 E 6.916 3384.79 8349.73 34.510 278.480 6846.87 6919.98 544.92 S 3380.38 W 5958384.17 N 650100.45 E 4.080 3414.96 8358.76 33.810 279.300 6854.34 6927.45 544.14 S 3385.39 W 5958384.86 N 650095.43 E 9.278 3419.89 8456.30 33.490 278.690 6935.54 7008.65 535.68 S 3438.77 W 5958392.22 N 650041.88 E 0.477 3472.33 8552.04 31.690 278.410 7016.20 7089.31 528.01 S 3489.76 W 5958398.84 N 649990.75 E 1.887 3522.46 8648.93 31.380 278.910 7098.78 7171.89 520.39 S 3539.86 W 5958405.45 N 649940.50 E 0.419 3571.71 8743.86 31.100 279.220 7179.95 7253.06 512.63 S 3588.48 W 5958412.21 N 649891.74 E 0.340 3619.47 8840.54 30.450 276.480 7263.02 7336.13 505.86 S 3637.47 W 5958417.97 N 649842.62 E 1.598 3667.68 .-.. 8937.80 31.960 276.110 7346.20 7419.31 500.34 S 3687.55 W 5958422.47 N 649792.43 E 1.565 3717.10 9032.38 31.270 275.440 7426.75 7499.86 495.35 S 3736.88 W 5958426.45 N 649743.01 E 0.819 3765.80 9127.48 30.590 275.750 7508.32 7581.43 490.59 S 3785.53 W 5958430.22 N 649694.28 E 0.734 3813.85 9225.10 30.130 275.670 7592.56 7665.67 485.68 S 3834.62 W 5958434.13 N 649645.09 E 0.4 73 3862.34 9322.36 29.600 276.800 7676.90 7750.01 480.42 S 3882.77 W 5958438.40 N 649596.85 E 0.795 3909.84 9416.34 28.890 276.310 7758.90 7832.01 475.18 S 3928.38 W 5958442.71 N 649551.14 E 0.797 3954.82 9512.53 27.750 274.250 7843.58 7916.69 470.96 S 3973.81 W 5958446.00 N 649505.64 E 1.561 3999.71 9608.40 27.000 273.810 7928.71 8001.82 467.86 S 4017.78 W 5958448.20 N 649461.61 E 0.810 4043.25 9702.95 27.4 70 278.830 8012.79 8085.90 463.09 S 4060.75 W 5958452.10 N 649418.55 E 2.479 4085.64 9802.21 26.500 280.500 8101.24 8174.35 455.54 S 4105.15W 5958458.74 N 649374.01 E 1 .240 4129.21 9898.86 25.240 280.290 8188.21 8261.32 447.93 S 4146.63 W 5958465.50 N 649332.38 E 1.307 4169.87 9992.50 24.060 279.860 8273.31 8346.42 441.09 S 4185.08 W 5958471.55 N 649293.80 E 1.275 4207.58 10088.13 22.580 279.640 8361.13 8434.24 434.68 S 4222.39 W 5958477.20 N 649256.37 E 1.550 4244.19 6 November, 2001 - 11:43 Page 2 0'4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for D-18A Your Ref: API 500292069401 Job No. AKMM11159, Surveyed: 10 October, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA D Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10144.30 21.800 280.170 8413.14 8486.25 431.03 S 4243.28 W 59584~0.42 N 649235.40 E 1.434 4264.69 --,- 10243.13 20.890 278.570 8505.19 8578.30 425.17 S 4278.77 W 5958485.56 N 649199.80 E 1.093 4299.54 10290.94 19.340 282.170 8550.08 8623.19 422.23 S 4294.94 W 5958488.17 N 649183.58 E 4.148 4315.39 10385.98 19.370 282.390 8639.75 8712.86 415.53 S 4325.72 W 5958494.24 N 649152.67 E 0.083 4345.47 10483.49 20.340 283.580 8731.46 8804.57 408.08 S 4357.99 W 5958501.03 N 649120.25 E 1.078 4376.96 10576.23 19.390 288.090 8818.69 8891.80 399.51 S 4388.29 W 5958508.97 N 649089.78 E 1.944 4406.41 10674.31 19.820 289.720 8911.08 8984.19 388.85 S 4419.42 W 5958519.00 N 649058.44 E 0.709 4436.49 10770.64 20.650 287.960 9001.47 9074.58 378.10 S 4450.95 W 5958529.10 N 649026.70 E 1.068 4466.97 10863.36 20.060 292.000 9088.40 9161.51 367.10 S 4481.25 W 5958539.48 N 648996.18 E 1.643 4496.20 10895.00 20.060 292.000 9118.12 9191.23 363.03 S 4491.31 W 5958543.34 N 648986.04 E 0.000 4505.87 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.474° (06-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). ~~. Vertical Section is from Well Reference and calculated along an Azimuth of 265.010° (True). ~, Based upon Minimum Curvature type calculations, at a Measured Depth of 10895.00ft., The Bottom Hole Displacement is 4505.96ft., in the Direction of 265.379° (True). 6 November, 2001 - 11:43 Page 30f4 DrillQuest 2.00.08.005 c,~~ ~ ~. North Slope Alaska Sperry-Sun Drilling Services Survey Report for D-18A Your Ref: API 500292069401 Job No. AKMM11159, Surveyed: 10 October, 2001 . -"" Alaska Drilling & Wells PBU_WOA D Pad Comments '-./ Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~- 7997.10 8027.00 10895.00 6662.64 6682.13 9191.23 544.40 S 547.88 S 363.03 S 3142.13 W 3164.53 W 4491.31 W Tie On Point Window Point Projected Survey Survey tool program for D-18A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 7997.10 0.00 7997.10 6662.64 10895.00 6662.64 AK-1 BP _HG (0-18) 9191.23 MWD Magnetic (0-18A) ~'" 6 November, 2001 - 11:43 Page 40'4 DrillQuest 2.00.08.005 I J ~1f~VŒ ill)~ &\~~~[K(~ 't AT1ASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit D-18A BP Exploration (Alaska) Inc. Permit No: 201-103 Sur Loc: 1990' SNL, 1692' WEL, SEC. 23, TIIN, RI3E, UM Btmhole Loc. 2913' NSL, 912' WEL, SEC. 22, TIIN, RI3E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application Prudhoe Bay Unit D-18. 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. Sincerely, ~M,~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this IV""'''; day of June, 2001 jjc/Enc1osures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. " STATE OF ALASKA- ALASKA l.~ AND GAS CONSERVATION COMML JION PERMIT TO DRILL 20 AAC 25.005 Þ (1-\ Open: 11022' - 11035', 11052' - 11068' Sqzd: 10946' - 11002', 11035' - 11042', 11068' - 11078' true vertical Open: 8957' - 8969', 8984' - 8998' Sqzd: 8891' - 8940', 8969' - 8975', 8998' - 9007' II Filing Fee 0 Property Plat 0 BOP Sketch II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis Contact Engineer Name/Number: Bil/lsaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is Á :rect to the best of my knowledge Signed Dan Stone C:;::::::::;;>....... -1'vï. Title Senior Drilling Engineer Date! J 3 () J ~ ) , '':,. .:"., :,':,'?, ':'; ',,'': ,,' '" ,:,<::,', : (':,:\; ,,i',' .,; ':' ~:,:,::¡:::<;:!'::;,<:';:'::::',:':;,\::'::¡:::::::.,<::::,:'::::_!,:'.,:;Øøm:",ì,âløii:~~,;;Ôg'ly>,;¡;.¡':',;', 'E:" :¡,: ;:{",;:,';:':';:'¡:::';' , ::,::::,. " " ',;' ¡;:,.:' ::::, ;", :,:, :¡;:,:; ,'i;;:,::';:; ':':'«':" ,.~.:> ';,:;:'~ ,.'..' ",j:',;:,,' ':' Permit Number ~. ~ API Number 1 I APprpval8atp 1 See cover letter 201-"'- ID3 50- 029-20694-01 Ii . \ J \ for other requirements Conditions of Approval: Samples Required 0 Yes ~o Mud Log Required 0 Yes R(No Hydrogen Sulfide Measures ~es 0 No Directional Survey Required .:8fÝes 0 No Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K '1Ø:.3.5K psi ~....JØJ;I Other: ~1~A!'!'~~~S~t~]v,! ["'¡ r /\ Commissioner ',Y. HWII. '"'"' T ._,,, '.) t I ~, t~\ L- 11 b. Type of well 1 a. Type of work 0 Drill IBI Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1990' SNL, 1692' WEL, SEC. 23, T11 N, R13E, UM At top of productive interval 2837' NSL, 881'WEL, SEC. 22, T11N, R13E, UM At total depth 2913' NSL, 912' WEL, SEC. 22, T11N, R13E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028285, 912' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9420' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina ]II 26# L-80 BTC-M 7" 26# L-80 BTC-M 4-1/2" 12.6# 13Cr-80 Vam Ace Hole (Tieback) 8-1/2" 6-1/8" Lenath 6770' 1154' 6043' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11425 feet 9312 feet 11382 feet 9274 feet Length Size 110' 20" x 30" 2678' 13-3/8" 10459' 9-5/8" 1462' 7" Perforation depth: measured 20. Attachments Approved By Form 10-401 Rev. 12-01-85 0 Exploratory 0 .stratigraphic Test IBI Development Oil 0 Service 0 Development Gas g'"SjJJ~le Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 71.7' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028284 t 28åk - ,(¡" 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Prudhoe Bay Unit 8. Well Number D-18A 9. Approximate spud date 06/16/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11012' MD / 9122' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 53 0 Maximum surface 2470 psig, At total depth (TVD) 8802' / 3350 psig Setting Depth TOD Bottom MD TVD MD TVD 2500' 2500' 9270' 7537' 9270' 7537' 10424' 8564' 10275' 8422' 11011' 9122' Number 2S100302630-277 Quantitv of Cement linclude staae data) 1061 cu ft Class 'G' 169 cu ft Class 'G' 135 cu ft Class 'G' Plugs (measured) Junk (measured) See Diagram. Cemented TVD MD 8 cu yds Concrete 3490 cu ft Permafrost II 1462 cu ft Class 'G', 130 cu ft PF 'C' 110' 2678' 8469' 110' 2678' 10459' 480 cu ft Class 'G' 9963' - 11425' 8066' - 9312' F E~\/E /J ¡as"G;~ f)i¡ (', Cmmr¡¡ssier , . ,. I ." '1\ ni',hrw~r:iI": 0 Diverter Sketch II Drilling Program 0 Seabed Report 0 20 AAC 25.050 Requirements by order of the commission Date I n - (10 ( Sùbmit In Triplicate ( IWell Name: ID-18A (' Drill and Complete Summary I Type of Redrill {producer or injector>-=--J Producer Surface Location: x = 653,469.00 1 Y = 5,958,998.00 3289' FSL 1692' FEL S23 T11 N R 13E Umiat Target Location: x = 649,010.55 1 Y = 5,958,456.82 2837'FSL 881' FEL S22 T11 N R13E Umiat Bottom Hole Location: x = 648,978.00 1 Y = 5,958,532.00 2913'FSL 912' FEL S22 T11N R13E Umiat I AFE Number: 4P1664 1 Rig: 1 Nabors 9ES 1 Operating days to complete: 117.0 I Estimated Start Date: 106/16/01 ~ 11,012' I I 1 TVD: 19122' I Cellar Elevation: 141.66' I 1 RKB: 171.7' I Well Design {conventional, slim hole, etc.>.J Conventional Big Bore - 9-5/8" Sidetrack ~ective: I Complete well as Zone 2B Producer to replace original wellbore. Formation Markers Formation Tops MD TVDss Comments K2/Top HRZ Not Penetrated Top Kinqak JG 7336' Not Penetrated Top Kingak (JF) 9416' 7574' Kick-off in Kingak F -- 10.8 ppg required for shale stability at hole angle and direction. Kick-off Point 9420' 7577' Kick-off Point Top Kinqak JE 9570' 7695' Top Kinqak JD 9909' 8003' Top Kingak JC 10,092' 8177' Top Kingak JB 10,255' 8332' Saq River 10,424' 8492' Estimated pore pressure 3297 psi 7.5 ppq EMW Shublik 10,457' 8524' Top Sadlerochit 1 Z4 10,545' 8607' Estimated pore pressure 3308 psi I 7.4 ppg EMW Top Z3 10,665' 8721' Estimated pore pressure 3320 psi 7.3 ppq EMW Top Z2 10,750' 8802' Estimated pore pressure 3350 psi 7.3 PPQ EMW HOT 10,906' 8950' Top Z1 10,993' 9033' TD -11,011' -9050' TD Criteria: -105 to 115' MD below top HOT to provide -20 to 30' of cased hole rat-hole. ~;~ ~ F (1: ~\ L !~., ~- t\!,iì.ifi,V :~ n 2001 \'i¡i~ ö ". v D-18A Permit to Drill 5/29/01 0 l{ ¡ r~~~ f t\ t' ,L\ L;, ¡ \1 ,-,,"[[\!/\, ,~\ j'':1~!,,,r1¡ ~.'("\~~' "~il"~ Commiss;or --, ~ r1 ~':I i\, ,,OJ' I Page 1 ( ( Casing/Tubing Program Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-Mod -1154' 9270' / 7537' 10,424' / 8564' Tie-back 7" 26# L-80 BTC-Mod -6770' 2500' / 2500' 9270'/7537' 6-1/8" 4-1 /2" 12.6# 13Cr-80 Vam Ace -6043' 10,275' / 8422' 11,011' / 9122' Tubinq 4-1/211 12.6# 13Cr-80 Vam Ace -12,710' GL 10,275' / 8422' Directional KOP: I 9,420' MD Maximum Hole Angle: -530 In original wellbore at 6300' MD -18.30 In tangent interval and through Reservoir section Close Approach Well: All wells pass BP Close Approach guidelines. The nearest close approach well is D-17A which is -1072' well-to-well at 10,523' MD and passes under Major Risk rules. Survey Program: Standard MWD Surveys from kick-off to TD. LSND PV 10-15 Whipstock Window in 9-5/8" Yield Point tauO 30 - 35 4 - 8 tauO 3-7 API FI N/C Lo 8 Y2" Intermediate: Drilling: Open Hole: Cased Hole: 6-1/8" Production: Drilling: Open Hole: Cased Hole: D-18A Permit to Drill 5/29/01 Page 2 ( ( 35 bbls NSCI Viscosified Spacer weighted to 12.8 ppg None 30 bbl I 169 ft I 147 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk, BHST 2100 I BHCT 1450 (use actual circulating temps recorded by MWD at TD , TT = Batch Mix + 4 to 4.5 hrs *See Attached Halliburton Cement Program for Details on Cement Formulation* Casing Size I 7" Tie-back Liner I Basis: Lead: Based on 6770' of 9-5/8" x 7" annulus, -10' of 7" casing below landing collar, and 300' of excess cement above liner top in 9-5/8" x 5" HWDP annulus. TOC: -2,500' MD (2500' TVD) - at liner top. Tail: None Fluid Sequence & Volumes: Pre 10 bbls Fresh water at 8.3 ppg Flush Spacer 30 bbls NSCI Viscosified Spacer weighted to 12.0 ppg Lead 189 bbl I 1061 ft" I 518 sks of Halliburton Premium 'G' at 13.1 ppg and 2.05 cf/sk, BHST 1850 I BHCT 1350 (use actual circulating temps recorded by MWD at TD), TT = 4.5 to 5 hrs Tail None *See Attached Halliburton Cement Program for Details on Cement Formulation* I Casing Size 14-1/2" Production Liner I I Basis: Lead: None Tail: Based on 82' of 4-112" shoe track, 588' of open hole with 50% excess, 150' of 7" x 4%" liner lap, and 250' of 7" x 4" DP annulus volume. Tail TOC: -10,275' MD (8422' TVD).- Liner top. I Fluid Sequence & Volumes: Pre 15 bbls Fresh water at 8.3 ppg Flush Spacer 30 bbls NSCI Viscosified Spacer weighted to 12.0 ppg Lead None Tail 24 bbl 1135 fe 1118 sks of Halliburton Premium 'G' at 15.8 ppg and 1.15 cf/sk, BHST 2250 I BHCT 1550 (use actual circulating temps recorded by MWD at TD), TT = Batch Mix + 4 to 4.5 hrs *See Attached Halliburton Cement Program for Details on Cement Formulation* D-18A Permit to Drill 5/29/01 Page 3 ( \ Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3350 psi @ 8802' TVDss - Kuparuk . Maximum surface pressure: 2470 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 6.8 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . D-18A Permit to Drill 5/29/01 Page 4 ( ( Sidetrack and Complete Procedure Summary Pre-Ria Work: 1. Rig up slickline. Dummy off any remaining live GL V's above the planned tubing cut depth at 9550' MD (the latest GLV Report shows live valves in the GLM's at 7740' and 3006' MD). Tag and document top of fill and drift tubing for upcoming tubing cut. If fill is tagged too high to allow the tubing cut at 9550' MD, contact Drilling Engineer to discuss options. NOTE: Do not bleed pressure from IA to liquid pack the well. There is a leak in the 9-5/8" casing at -3560' MD and by bleeding pressure from the lA, formation fluid and SOLIDS (sand) are allowed to enter the well and fill the 9-5/8" x 5%" annulus. Large amounts of solids were seen on prior flowbacks, which then settled out in the annulus. If any circulating is done to fluid pack the lA, be sure to hold adequate back-pressure to avoid allowing formation fluids to flow through the 9-5/8" leak. 2. Rig up E-line. Run a continuous gyro (Gyrodata) from surface to the top of fill in 5V2" tubing. Cut the 5V2" L-80 tubing at 9550' MD (this is -10' up into the first full joint above the GLM assembly at 9560' MD, as per Tubing Summary dated 4/21/82). This cut will not be fished, so the use of a jet or chemical cutter is at the discretion of the Wells Group Representative. 3. Displace the well to clean seawater by circulating down tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Hold back-pressure at all time while circulating to avoid allowing formation fluids to flow in through the 9-5/8" leak (see notes in step 1). Freeze protect top 2200' MD with diesel by circulating diesel down tubing and then bull-heading diesel down annulus (through leak in 9-5/8"). 4. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 5. Set a BPV in the tubing hanger. Secure well. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 9ES. 2. Circulate out freeze protection and displace well to kill weight brine (adequate to maintain Cretaceous pressure behind 9-5/8" casing). Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 5-1/2" tubing from E-line cut and above. 5. Bleed any pressure from 13-3/8" x 9-5/8" annulus. Change out 9-5/8" pack-off through BOP stack. Test pack- off to 5000 psi to verify integrity. 6. MU 9-5/8" whipstock window milling assembly and RIH to top of tubing stub. POOH. 7. PU 9-5/8" RTTS and RIH. Set RTTS -25' below the planned 7" liner top at -2500' MD. Test 9-5/8" casing above the RTTS to 3000 psi. Bleed pressure and POOH with RTTS. 8. RU E-line and set BP at -9444' MD (set as needed to avoid cutting casing collar). 9. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as desired and set on BP. Mill window in 9-5/8" casing at -9420' MD. POOH. 10. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag@:t10,425'MD(8564'TVD}.:ç- \\ .~ \cll~ VQS £\-\...~ ~.~., 11. Run and cement 7", 26# intermediate drilling liner to -150' back into window. POH. . Co l (,.,\ 12. Run and cement 7" 26# liner tie-back assembly with liner top at -2500' MD. POH. 13. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/DEN/NEU) to the 7" tie-back landing collar. Test 7" tie-back assembly to 3000 psi. Drill landing collar and RIH to 7" liner landing collar. ~~: 6~i~t~~1~~:~~~~~~i~~ :;~i~~ l:se~~~Xr~~~~~~1~1~~~~~nt~:t~~:~:dt~go~01~~6~~ ~D(~1u~~~TVD}. ~\~ \a~5š 16. Run and cement a 4 V2", 12.6# 13Cr-80 solid production liner throughout the 6-1/8" wellbore. Displace well to clean seawater above liner top. POOH SB DP. 17. Test the 4-1/2",7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3000 psi for 30 min. 18. Run a 4-1/2",12.6# 13Cr-80 Vam completion tying into the 4-1/2" liner top. 19. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 20. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 21. Freeze protect the well to -2200' and secure the well. 22. Rig down and move off. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below production packer. Install gas lift valves. 2. Perforate 10' to 20' of Zone 2 with E-line conveyed guns. D-18A Permit to Drill 5/29/01 Page 5 ( (' Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to 0-18. The two adjacent wells (0-17 and D-19A) are both approximately 110' from the 0-18 wellhead. Establish a minimum distance of 5' from the D-17 and D-19A wellhouse. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. If it appears the 5' distance will be crossed, the move should be stopped, the rig backed up, and the move re-attempted. ~ 0 Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: D-18 -10 ppm June 1996 (well was shut-in August of 1996) Adjacent producers at Surface: D-17 10 ppm Nov 01, 00 D-19 8 ppm 1Q 96 (well was shut-in March of 1996) D-20 10 ppm Mar 17, 01 Adjacent producers at TD: All as above: D-17,19 D-10 10 ppm Jan 17,01 The maximum recorded level of H2S on the pad was 15 ppm from D-17 on Nov 15, 1998. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Job 2: Decomplete Well Hazards and Contingencies ~ The perforations should be isolated by a plug in the tailpipe, however the well will be in communication with the Cretaceous interval via the leak in the 9-5/8" casing at -3560' MD. The maximum expected pressure in the Cretaceous interval is a 9.0 ppg EMW. Prior to pulling the completion monitor the well closely for any signs of underbalance. ~ NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 5: Drill 8Y2" Intermediate Hole Hazards and Contingencies ~ On prior D Pad wells, lost circulation in the intermediate section has been experienced while drilling shallow sandstone intervals and when crossing faults in the Kingak shales. No fault crossings are planned in the drilling of D-18A, however the planned mud weight is higher than historically used at D Pad. The original well was drilled to Top Sag with 9.7 ppg and no losses. Several incidents of lost circulation have been seen when the Sag River formation was inadvertently penetrated. Extreme care should be taken when picking the 7" casing point. ~ The well will kick-off in the Kingak Zone F, which is the most competent interval of the Kingak Shales. The weakest interval, Zone G, is above Zone F and will be avoided. D Pad has a limited history of wellbore stability problems within the Kingak shales and of the problems encountered, minor incidents of tight hole and packing off have been the main problems. No stuck pipe incidents are noted on the pad data sheet. Most situations have been handled with additional washing and reaming followed by 0-18A Permit to Drill 5/29/01 Page 6 f f increased mud weights to stabilize the shale. Problems have been encountered in both high and low angle wells, however high angle wells have been most problematic. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. ~ The kick tolerance for the 8%" open hole section would be 103 bbls assuming a kick from the Sag River at -10,424' MD. This is a worst case scenario based on an 7.8 ppg pore pressure gradient, a fracture gradient of 11.7 ppg at the 13-3/8" shoe (leak in 9-5/8" casing), and 10.7 ppg mud in the hole. );;> Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is D-17A which is -1072' well-to-well at 10,523' MD and passes under Major Risk rules. Note tolerance lines and allowable deviation from the planned D-18A well-path. Job 6: Install 7" Intermediate Liner and 7" Tie-back Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ No fault crossings are planned in the drilling of D-18A, however the given target polygon is hard. As planned, the well bore will drill between several faults. Major east-west trending faults lie -400' north and 600' south of the target polygon and have been classified as high risk for losses in Zones 4 and 3 respectively. Additionally, minor faults are present within the Zone 2 reservoir section -300' south and east of the proposed target location. These faults have been classified as low risk faults, however they should be avoided. ~ D Pad has a history of lost circulation events while drilling in the reservoir section. Losses have ranged from minor to severe (-150 bph). All cases of severe losses have been fault related and were managed by pumping fiberous LCM pills. The original D-18 well penetrated a 70' throw fault near the top of the Ivishak and no losses were encountered. As noted above, no fault crossings are planned in the drilling of D-18A, however be prepared for losses by establishing a contingency plan. ~ The kick tolerance for the 6-1/8" open hole section would be an infinite influx assuming a kick from the Ivishak at -11,012' MD. This is a worst case scenario based on an 7.8 ppg pore pressure gradient, a fracture gradient of 9.5 ppg at the 7" shoe, and 8.5 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is D-17 A which is -1072' well-to-well at 10,523' MD and passes under Major Risk rules. Note tolerance lines and allowable deviation from the planned D-18A well-path. Job 9: Install 4V2" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The 8.5 ppg Quickdril will be -540 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. D-18A Permit to Drill 5/29/01 Page 7 (- ~" Job 12: Run Completion Hazards and Contingencies )0> Diesel will be used to freeze protect the well. The diesel flash point is 1 00° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release RiQ Hazards and Contingencies )0> See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. D-18A Permit to Drill 5/29/01 Page 8 TREE = 6" CrN '(VELLHEAD= MCEVOY ':4. ëWA ï-ÒR; , , <:ins ,-" . ..,.. .. KB. ELEV = 76.01 'S'Þ:"'RBï;; , 40.16 w'"'" . '''" ,""'-"U'~""-"""'W"'~ '''...~." ,_..._~.. . -. .". ". KOP = 2800 .,,-.. - . . ..'" h .... ..- .~~~~_I~..,,~_------~~w~-~~~O Datum MD = 10929 -,-"-------,,,-"'u' n""_.."m_m..- .d", .... .--.. .n" .. .. Datum TVDss= 8800' L-18 Current StL~us (I) -15-1/2" OTIS SSSV LAND. NIP, 10=4.562 I I TOP OF 7" LNR 1 GAS LIFT MANDRELS ST MD TVD DE\! iYPE SIZE LTCH 12 3006 2939 7 OTlS-LBD 5-1/2 RA 11 4836 4510 48 OTIS-LBD 5-1/2 RA 10 6117 5384 50 OTlS-LBD 5-1/2 RA 9 6271 5478 53 OTlS-LBD 5-1/2 RA 8 7588 6319 45 OTIS-LBD 5-1/2 RA 7 7740 6424 47 OTIS-LBD 5-1/2 RA 6 8182 6715 49 OTIS-LBD 5-1/2 RA 5 8332 6815 49 OTIS-LBD 5-1/2 RA 4 8865 7178 45 OTIS-LBD 5-1/2 RA 3 9022 7289 45 OTIS-LBD 5-1/2 RA 2 9560 7685 41 OTIS-LBD 5-1/2 RA 1 9716 7804 40 OTIS-LBD 5-1/2 RA COMMENTS 113-3/8" CSG, 72#, L80, .1481 bpf, 10=12.347 I Leak in 9-5/8" casing -3560' ELM. / Fill (formation sand from Cretaceous leak at -3560' MD) in tubing up to -9600' SLM. Not sure of height of sand in the annulus. -15-1/2" SLIDING SLV, ID=4.562 I Fish #2: Catcher Sub set at 9800' SLM. Fish #1: 'XXN' Plug with -25' tool string and 4' of wire stuck in 'XN' nipple. Top at 9957' SLM. -195/8" x 4-1/2" BOT PKR, ID=3.813 I 15-1/2" TBG, 17#, L80, .0232 bpf, ID=4.892 I -14-1/2" OTIS 'X' NIP, ID=3.813 I 14-112" TAILPIPE, 12.6#,L80, .0152 bpf,ID=3.958 1 -14-1/2" OTIS 'XN' NIP, ID=3.725" I -14-1/2" TBG TAIL ID=3.8331 1--1 ELMD I 10007' 19-5/8" CSG, 47#, L80, .0732 bpf, ID=8.681 1 PERFORA TION SUMMARY REF LOG: BHCS, 4/19/82 ANGLE AT TOP PERF: 128 @ 10996 Note: Refer to Production DB for historical perf data 10820' 1-1 MARKER JOINT I SIZE SPF INTERVAL Opn/Sqz DATE 3318 4 10996' -11002' 0 03/25/95 33/8 4 11022' -11035' 0 08/12/95 1 PBTD I 17" LNR, 26#, L80, .0383 bpf, ID=6.276 I DATE REV BY COMMENTS 04/25/82 ORIGINAL COMPLETION 02/08/01 SIS-SL T CONVERTED TO CANVAS 03/08/01 SIS-MD FINAL PRUDHOE BA Y UNIT WELL: D-18 PERMIT No: 81-1880 API No: 50-029-20694-00 Sec.22,T11N,R13E BP Exploration (Alaska) TREE = 6" crw YVELLHEAD= MCEVOY ACWÁ-TÒR;" -,"' ÕTìs . - " ... ... KB. EI...EV = 76.01 .."' ". on "... . . ,- ."... m. BF. EI...EV = 40.16 "". --.-'" -- n' .._~.".. ".. "' . "",. .".--,._..~. KOP = 2800 .. . .. ". ,-." ........._-- Max Angle = 53 @ 6300 'Bat'üm'Mì5~-~---'--1-6"929 --..-..._._.._m._n_n___...n ...."'-""""'-', . ..,_.-..--.... ...... Datum 1VDss= 8800' n ,18 Planned PrL .Rig 113-3/8" CSG, 72#, L80, .1481 bpf, 10=12.347 I Leak in 9-5/8" casing -3560' ELM. / Pre-Rig Tubing Cut at 9550' MD. Fill (formation sand from Cretaceous leak at -3560' MD) in tubing up to -9600' SLM. Not sure of height of sand in the annulus. Fish #2: Catcher Sub set at 9800' SLM. Fish #1: 'XXN' Plug with -25' tool string and 4' of wire stuck in 'XN' nipple. Top at 9957' SLM. 15-1/2" TBG, 17#, L80, .0232 bpf, ID=4.892 I TOPOF 7" LNR I 14-1/2" TAILPIÆ,12.6#,L80, .0152 bpf,ID=3.958 I 8> 2050' -15-1/2" OTIS SSSV LAND. NIP, 10--4.562 I GAS LIFT MANOREI...S ST MD 1VO DEV 1YÆ SIZE LTCH 12 3006 2939 7 OTlS-LBD 5-1/2 RA 11 4836 4510 48 OTIS-LBD 5-1/2 RA 10 6117 5384 50 OTlS-LBD 5-1/2 RA 9 6271 5478 53 OTlS-LBD 5-1/2 RA 8 7588 6319 45 OTIS-LBD 5-1/2 RA 7 7740 6424 47 OTIS-LBD 5-1/2 RA 6 8182 6715 49 OTIS-LBD 5-1/2 RA 5 8332 6815 49 OTIS-LBD 5-1/2 RA 4 8865 7178 45 OTIS-LBD 5-1/2 RA 3 9022 7289 45 OTIS-LBD 5-1/2 RA 2 9560 7685 41 OTIS-LBD 5-1/2 RA 1 9716 7804 40 OTIS-LBD 5-1/2 RA COMMENTS ALL GLM's Dummied-off above GLM #2 -15-1/2" SLIDING SLV, ID=4.562 I -195/8" x 4-1/2" BOT PKR, ID=3.813 I -14-1/2" OTIS 'X' NIP, ID=3.813 I -14-1/2" OTIS 'XN' NIP, ID=3.725" I -14-1/2" TBG TAIL ID=3.8331 1-1 ELMO I 10007' 19-5/8" CSG, 47#, L80, .0732 bpf, ID=8.681 I PERFORA TION SUMMARY REF LOG: BHCS, 4/19/82 ANGLE AT TOP ÆRF: 128 @ 10996 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3318 4 10996' -11002' 0 03/25/95 3318 4 11022' -11035' 0 08/12/95 I PBTD I 17" LNR, 26#, L80, .0383 bpf, ID=6.276 I 10820' 1-1 MARKER JOINT I DATE REV BY COMMENTS 04/25/82 ORIGINAL COMPLETION 02/08/01 SIS-SL T CONVERTED TO CANVAS 03/08/01 SIS-MD FINAL PRUDHOE BA Y UNrr WELL: 0-18 PERMIT No: 81-1880 API No: 50-029-20694-00 Sec. 22, T11N, R13E BP Exploration (Alaska) ( , \ D-18A Proposed Completion TREE: 4-1/16" - SM CIW L-SO WELLHEAD: 13 5/S" - SM McEvoy SSH 13-3/8",72 #/ft, L-80, BTC 2679' Window Milled from Whipstock Top of Window at +/-9,420' MD ~ Bridge Plug set at +/-9,444' MD---- Pre-Rig Tubing Cut at +/-9,550' 7" Liner Top I 9,9631 I 9-5/8",47 #/ft, L80, BTC 110,459' I Two fish stuck in 4-1/2" Tubing with fill on top of fish up to -9600' MD. The lower fish is an 'XXN' plug with tool string and -25' of wire. The upper is a catcher sub, which could not be pulled. Perforations from 10,944' to 11,078' 7", 26 #/ft, L80, BTC-Mod I 11.425' I Date 5/29/01 Rev By WSI Proposed Completion Comments Base Flange Elevation = 40.16' Nabors 9ES RKB = 71.66' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. ~ I +/-2,500' I BAKER 7" x 9-S/S" Liner Tie Back Sleeve ,. ZXP Liner Top Packer 'Flex-Iock' Hydraulic Liner Hanger 7",26 #/ft, L-80, BTC-Mod Casing with tie-back seals to isolate leak in 9-5/8u. 4-1/2" Gas Lift Mandrels with handling pups installed. ~~t:l~:1t~r=~r~==I-_._:-.-._V._--~-:n_~_D_¡¡_e_:_:_r_:-_,., _:l- ---_J- ------ ~ -- ----- - I +1-9,270' I BAKER 7" x 9-S/S" Liner Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 4-1/2" 12.6# 13Cr-80, Vam ACE Tubing 4-1/2" 'X' Landing Nipple with 3.S13" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.S13" seal bore. 4-1/2" 'XN' Landing Nipple with 3.S13" seal bore and 3.725" No.Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +/-10,275' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 7",26 #/ft, L-80, BTC-Mod Plug Back Depth I +/-10,927' I 4-1/2" 12.6 #/ft, 13Cr-80, Vam ACE I +/-11.012' I PRUDHOE BAY UNIT WELL: D-18A API NO: 50-029-20694-01 Alaska Drilling & Wells D-18A Schlumberger Proposed Well Profile - Geodetic Report N 70 1734.470 W 1484726.872 N 70 1734.451 W 1484727.255 N 70 1734.447 W 1484727.336 N 70 1734.434 W 1484727.644 9448.00 41.66 264.48 7669.80 2419.73 -742.57 -4171.45 0.00 5958170.48 649313.89 N 70 1734.427 W 1484727.875 9500.00 38.03 267.65 7709.72 2441.55 -744.89 -4204.67 8.00 5958167.48 649280.73 N 70 1734.404 W 1484728.843 9570.09 33.31 272.83 7766.66 2470.43 -744.82 -4245.50 8.00 5958166.71 649239.91 N 70 1734.404 W 1484730.033 9600.00 31.36 275.45 7791.93 2482.50 -743.68 -4261.45 8.00 5958167.53 649223.94 N 70 1734.415 W 1484730.498 -, 9700.00 25.38 286.69 7879.94 2521.46 -735.03 -4307.96 8.00 5958175.23 649177.27 N 701734.500 W 1484731.853 9800.00 20.69 303.39 7972.04 2557.67 -719.13 -4343.30 8.00 5958190.40 649141.61 N 701734.656 W 1484732.884 9900.00 18.32 326.45 8066.43 2590.44 -696.27 -4366.77 8.00 5958212.77 649117.68 N 70 17 34.881 W 1484733.568 9908.67 18.26 328.65 8074.66 2593.09 -693.98 -4368.23 8.00 5958215.03 649116.18 N 70 1734.903 W 14847 33.611 9944.34 18.28 337.76 8108.54 2603.69 -684.02 -4373.26 8.00 5958224.89 649110.95 N 70 17 35.001 W 1484733.757 10091.90 18.28 337.76 8248.66 2646.40 -641.18 -4390.77 0.00 5958267.36 649092.57 N 70 1735.423 W 1484734.268 10423.65 18.28 337.76 8563.66 2742.41 -544.86 -4430.16 0.00 5958362.85 649051.22 N 70 1736.370 W 1484735.418 10423.75 18.28 337.76 8563.76 2742.44 -544.83 -4430.17 0.00 5958362.88 649051.21 N 70 17 36.370 W 1484735.418 10457.35 18.28 337.76 8595.66 2752.16 -535.07 -4434.16 0.00 5958372.55 649047.02 N 70 17 36.466 W 1484735.535 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: May 15, 2001 Alaska Drilling & Wells Prudhoe Bay Unit D-PAD / D-18 - WOA (Drill Pads) D-18 D-18A F IIIblllllllty It d 500292069401 el51 II U D-18A (P2) 1 Ma 136.15r 14837~ 15,2001 NAD27 Alaska St ~ ft /5.9001 0.53C ~ ~~5~~~:~¿6'ft~ ~~~~~6~;)e 4, US Feel +1.16994220° S, E 653469.000 ftUS 0.99992676 Station ID Tie-In Survey TJF Top of Window Base of Whipstock KOP 8/100 TJE TJD End Crv TJC Top Sag 7" Csg Pt Top Shublik D-18A (P2) Report.xls Page 1 of 2 Survey I DLS Computation Method: Vertical Section Azimuth: nly Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Minimum Curvature / Lubinski 315.080° N 0.000 ft, E 0.000 ft KB 71.7 ft relative to MSL Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: 26.599° 57474.287 nT 80.773° June 21, 2001 BGGM 2000 True North +26.599° Well Head - 5/15/2001-8:20 AM Station ID Top Sad I Z4B Top Z3 Top Z2C 10750.12 Top HOT 10905.99 TD I TGT 14-1/2" Lnr Pt 11011.31 337.76 8873.66 2836.89 -450.07 -4468.91 337.76 9021.66 2882.00 -404.81 -4487.42 337.76 9121.66 2912.48 -374.23 -4499.92 18.28 18.28 18.28 Leaal DescriDtion: Surface: 3289 FSL 1692 FEL S23 T11 N R13E UM Tie-In: 2550 FSL 550 FEL S22 T11N R13E UM GT 14-1/2" Lnr Pt I BHL: 2913 FSL 912 FEL S22 T11N R13E UM Northina eY) fftUSl 5958998.00 5958175.59 5958532.00 D-18A (P2) Report.xls Page 2 of 2 N 70 1736.715 W 1484735.837 N 70 1737.058 W 1484736.254 0.00 5958456.82 649010.55 N 70 1737.302 W 1484736.549 0.00 5958501.69 648991.12 N 70 1737.747 W 1484737.089 0.00 5958532.00 648978.00 N 701738.047 W 1484737.454 Eastina eX} fftUSl 653469.00 649348.22 648978.00 ~"""~) 5/15/2001-8:20 AM --- ã5:::J ~C/) o~ 0 (1) lC) > .~ ~ 7500 ~4= -- CD ..cCD ...... . c. ~ 0)1"- 000 m~ (.) ~ 8000 1:: (1) (1)0::: > > (1) (1) 2W I- VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: D-18A (P2) Field: Prudhoe Bay Unit - WOA Structure: D-PAD Section At: 315.08 deg Date: May 15, 2001 (" Schlumberger I ! ¡ I . I ! '--------'-'--"-----r-----------.---------t-.------...,-.-.----,--....__...- --"".-.--,--- ---..-.....-----..-..--..-,.--....-,.,-. ! 6000 D-18 6500 7000 I I Tla-In SUIVay9396 MD 7631 D 41.48" 261.60' az 2399 dep rtura / Top 01 Wlndow9420 D 7649 TVD 41.46' 261.60' az 24 8 departura . Beaa of Whlpaloe 436 MD 7661 TVD - 41.66' 264.48' az 2415 departure KOP 8/1009448 MD 7670 TVD 41.66' 264.48' z 2420 daparture TJF 941() MD 7646 TVD , I TJE' 9'570' NiÓi7Ù7 TVr) I I End IV 9944 MD 8109 TVD 18.2' 337,76' az 2604 departure TJD 9909 MD 80'71 TVD T JC 1 OO~¡2 MD 82 9 TVD 7" Cag PI 10424 MD 85 4 TVD 18.28' 337.76' az 2742 eparture 8500 ", I TOp. S(:~9J °:í..24".M..f? ,?.5fj,4 T.Yf?,,,. "I". f ~::;~:¡;,~:O~;i{:~:~~VD .1 I Tor') Z2C'10750 MD 8874TVD ! I ""l+~';;::H¿::;::::::1"¿~~O~;:'~XD ~:9(~22'Tv-G:""':::~-"':::::'"''':::::''r::::''''':::::'''''::." i I I I TD I TGT I 4-1/2" Lnr PI 11011 MD 9122TVD I' 118.28' 337.76' az 2912 departure I Hold Angle 8.28° 9000 ................~................................................. ...........,..,.......,...,...............................,........,.... ". "... "'" "''' ..... ..... .... ..... ..... "'n ..... n.,.. ,,,.. ..... 9500 1500 2000 2500 3000 3500 Vertical Section Departure at 315.08 deg from (0.0, 0.0). (1 in = 500 feet) 4000 ( (' PLAN VIEW Client: Alaska Drilling & Wells Well: D-18A (P2) Field: Prudhoe Bay Unit - WOA Structure: D-PAD Scale: 1 in = 500 ft Date: ls-May-2001 Schlumberger ^ ^ ^ I I- 0::: 0 Z -1 000 I I- :J 0 ~ -1500 V V -2000 -2500 -5500 1000 -5000 -4500 -4000 -3500 -3000 1000 500 500 True North Mag Dee ( E 26.600 ) TD / TGT / -1/2" Lnr PI 11011 MD 9122 TVD 0 0 3745 45 0 W -500 I I 7" Cag PI 10424 MD 8564 TVD .. ..1- - 18.28' 337.76. az .' 5455 4430W ... I i End Cry .1./ 9944MD 8109TVD -500 0-18 . \" I ------------------ -------Fiif~~:"~::__::_------:1\~--:-;~J;~~~-l-------------------- Baso of Whlpslock I Top of Window 9436 MD 7661 TVD I 9420 MD 7649 TVD 41.66. 264.48' az I 41.46. 261.60' az 7425 4164W I 7415 4153W I ................................................................................................................................................................................................................1.......................................................................1...................................................................... I I I I I I I ---------- --------- ----------r----l-------r I I I ---"'''''-'-''''''''-'''-- '----''''''--''-'''---'''''-'---'- ---_.._...._.._._......_-_..._..._._...~_._--_.._-_.__._.._..-i..----.---..--.......-4 I i I I I -1000 -1500 -2000 -2500 -5500 -5000 -4500 -4000 «< WEST -3500 EAST »> -3000 D~ 18A Perm it Discussion , ¡IIi' ¡¡ Subject: D-18A Permit Discussion Date: Mon, 4 Jun 2001 14:11 :35 -0500 From: "Isaacson, William S" <lsaacsWS@BP.com> To: IITom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> ( Tom, Outlined below are the three issues we discussed in regards to the D-18A Permit to Drill and the planned operations. 1) Unknown height of fill behind the 4-1/211 tubing - Our current plan is to make the tubing cut as outlined in the Permit to Drill, and attempt to circulate the well to verify the annulus is clear above the cut depth. We have already dummied off all the GLM's and have verified tubing integrity above the cut. If the well circulates free, we are confident that we can pull the tubing without difficulty. If we can not establish circulation, this means fill is most likely present and we have a couple choices of logs we can run in attempt to identify the top of fill behind the tubing, and then make a cut at that depth. With the rig, we would then pull all of the tubing above the top cut and make the necessary fishing runs to recover the remaining tubing (dependant upon length of tubing, and if any GLM's are present). 2) Formation Integrity Test for 8-1/2" hole section Mearly an oversight that this was left out of the Permit verbage. We plan to do an FIT to 12.0 ppg EMW, regardless of the leak in the 9-5/8" casing. For kick tolerance, we will assume that whatever FIT we get will be at the leak in the 9..5/8" casing. 3) Formation Integrity Test for 6-1/8" hole section Also an oversight that this was left out of the Permit verbage. We plan to do an FIT to 9.8 ppg EMW. Expected ECD's will be in the 9.5 to 9.6 ppg range, so we just want to verify our shoe is strong enough for the expected ECD without going too high and risking breaking down the formation and creating losses. Kick tolerance is obviously not an issue. Let me know if there any additional questions. Thanks!! William S. Isaacson Alaska Drilling & Wells Phone: (907) 564..5521 Fax: (907) 564-4040 E-mail: IsaacsWS@BP.com 1 of 1 6/4/01 11 :43 AM ~ ( OICE I CREDIT MEMO DESCRIPTION GROSS 4-0iC TS: 6T: 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 D-\ 9 r; (MENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ DATE 05/16/01 CHECK NO. 00189910 VENDOR DISCOUNT ALASKAOILA NET 00 100. 00 H ~IQN (ALASKA) INC. FIRST NATIONALBANKOEASHLAND . . A~AFt=ILlATEOF . NATIONAL~crrY BANK Ci:.EVElAND. .oHIO No~'H 1,88910 ASKA 99519-6612 CONSOLIDATED, ÇOMIv'ERCIAL ACCOUNT, 001899tO . ,. ',' ,..:...: " . . . .. . .. .' " . fJ,:HUNDRED & OOllOO~**~t********:***i}***it:~;~~'**~'~********** " ,"" '. .DATE, . qiji/ ä;¡ 01¡~!//.¡.1 NQIVALlQAFfER'120, DAYS' , ." _AS~ OIL AND, GA:8 , J~SERVATI QN<;;OMMlSS:rON ,""'" 38>"ItJEST< 7TH AVENVE StJITE NCHORAGJi: III ~ B g g ~ 0 III I: 0 ~ ~ 2 0 ~ B g 51: 0 0 8 ~ ~ ~ 'ì III ¿é OMPANY WELL NAME Þ -/g: INITCLASS ~V /D/L 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate:*.~ .JrrI '~~ / /ç.- .c/o. /. 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . AP R DA TJ;: 12. Permit can be issued without administrative approval.. . . . . 5'~ t. 0 I 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; testto .~~a::J psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AP8-R DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~ 5'.3 (D I 34. Contact name/phone for weekly progress reports [explo~ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~~B~ fgW W~ "" 9g~ ~['t- WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION ENGINEERING mn~J; -- GEOLOGY APPR DATE -- -- c:\msoffice\wordian\diana\checklist (rev. 11/01//00) PROGRAM: exp - dev - redrll- serv - wellbore seg _ann. disposal para req - GEOL AREA BC;() UNIT# () / / (;;, .s~ ON/OFF SHORE ~ Y N ~ ¿SCJ?-u- c 0 Z 0 -4 :e ;xl (: -4 m . N Cw~üc.~~~ cU~\""t;. \~M~ \~~\;~ \-\~ ~"-\~\~\~V\.~ ~~\ \'tl~\ç N ~ ~ ~ ~\? f'~~\ \I'"'(~cl ~ õ>. 4.. ~a \(: " Y @ ~~F \\~S \S~\>\'\.' Q~~ \~ ~c:y~\\>~ \..v!~..&:§..~S;.f::Q '-o..\"~~ Y N .--TL- .2J-f7 Iò-L/¡ c> d L.h!.!. e.../ / S? V,1l /;'; 5 t.~ ~ V - ~ /9'Jg' Z -4 :I: CJ) » ::0 m :Þ ( Y N Y N '--'''''-''''''... Commentsll nstructions: ( l ~ 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. ( aO}.., J03 (' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 22 15:50:01 2002 Reel Header Service name.............LISTPE Date.....................02/02/22 Origin...................STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................02/02/22 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA D-18A 500292069401 BP Exploration Sperry Sun 21-FEB-02 (Alaska) Inc. JOB NUMBER: -o/LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-11159 B. HENNINGSE L. VAUGHN MWD RUN 3 AK-MM-11159 J. MARTIN L. VAUGHN MWD RUN 4 AK-MM-11159 J. MARTIN R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSH!NG: DERRICK FLOOR: GROUND LEVEL: 23 UN 13E 3289 1692 .00 73.11 40.16 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 6.750 6.750 4.750 CASING SIZE (TN) 9.625 7.625 5.500 DRILLERS DEPTH (FT) 8027.0 8027.0 10205.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. D-18A KICKS OFF FROM D-18 AT WHIPSTOCK WITH TOP SET ( (' AT 8027' MD, 6682' TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO SET THE WHIPSTOCK AND MILL THE WINDOW. 5. MWD RUNS 2-4 ARE DIRECTIONAL WITH DUAL GAMMA PROBE (DGR) UTILIZING GEIGER-MULLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. DIGITAL AND LOG DATA SHIFTED TO THE CPNL RUN 11/8/2001 PER THE E-MAIL OF 2/5/2002 OF D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 7. MWD RUNS 2-4 REPRESENT THE MWD DATA FOR WELL D-18A WITH API# 50-029-20694-01. THIS WELL REACHED A TOTAL DEPTH (TD) 'OF 10900' MD, 9191' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY- GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 Fi Ie Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPS RPX RPD RPM Rap $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 7992..5 8000.0 8000.0 8000.0 8019.5 8020.0 8042.0 STOP DEPTH 1084.7.0 10858.0 10858.0 10858.0 10858.0 10858.0 10900.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 7992.5 8001. 0 8025.5 8055.0 8078.5 8086.0 8101. 5 8124.0 DEPTH GR 7991.0 7999.5 8024.0 8053.5 8077.0 8085.0 8100.0 8122.0 IÝ ( (' 8211. 0 8208.0 8240.5 8237.5 8260.5 8257.5 8277.0 8274.0 8289.5 8287.0 8319.5 8317.0 8360.5 8358.0 8396.0 8394.5 8409.0 8405.0 8456.0 8452.5 8472.0 8469.5 8508.0 8504.0 8546.5 8542.5 8579.5 8576.0 8636.5 8632.5 8643.5 8640.0 8656.5 8653.5 8660.0 8656.5 8668.5 8665.0 8679.5 8674.5 8696.5 8692.0 8713.5 8710.0 8719.5 8715.5 8727.0 8723.5 8743.5 8739.5 8770.5 8767.0 8779.0 8775.5 8791. 5 8787.5 8819.0 8815.5 8849.0 8845.0 8857.5 8853.5 8866.5 8863.5 8875.0 8871. 5 8881.0 8878.0 8895.0 8891.0 8901.5 8897.5 8904.0 8900.0 8910.5 8908.0 8929.5 8925.5 8945.0 8941. 0 8974.0 8969.5 8992.0 8987.0 9014 .5 9009.5 9037.5 9032.5 9073.0 9068.5 9099.5 9094.0 9113.0 9107.5 9147.0 9141.0 917 3.0 9167.0 9188.0 9182.0 9209.5 9203.5 9320.0 9313.0 9336.0 9331.5 9350.5 9347 . 0 9492.5 9488.5 9571. 5 9565.5 9597.5 9591. 5 9661. 5 9655.5 9722.5 971 7 . 0 9756.0 9749. 0 9781. 5 9776.5 9813.0 9807.5 9867.5 9861. 5 9939.0 9933.0 10008.5 10001.5 10041. 5 10034.5 10181. 5 10176.0 10205.0 10198.5 10224.0 10219.0 10247.0 10242.0 10280.5 10274.5 10306.5 10301. 5 10319.0 10314.5 10334.5 10329.5 10366.0 10360.5 (" (" 10394.5 10410.0 10451. 5 10459.5 10481.0 10489.0 10516.0 10550.0 10668.5 10694.5 10755.5 10847.0 $ 10388.0 10405.0 10446.0 10454.0 10475.5 10483.0 10510.0 10544.0 10660.5 10686.0 10750.0 10841.5 # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 7991.0 3 10205.5 4 10765.5 MERGE BASE 10205.0 10765.0 10895.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sUb-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7992.5 10900.5 9446.5 5817 7992.5 10900.5 ROP MWD FPH 0 344.04 95.6588 5718 8042 10900.5 GR MWD API 12.06 524.5 117. 08 5710 7992.5 10847 RPX MWD OHMM 0.68 2000 14.8305 5717 8000 10858 RPS MWD ORt'1M 0.83 2000 18.673 5717 8000 10858 RPM MWD OHMM 0.68 2000 28.6254 5677 8020 10858 RPD MWD OHMM 0.13 2000 29.2002 5678 8019.5 10858 FET MWD HR 0.2048 134.819 3.70039 5717 8000 10858 First Readi.ng For Entire File.......... 7992.5 Last Reading For Entire File__......__.l0900.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Nurober...........1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 File Type.... -""""" .LO Next File Name...........STSLIB.002 ( Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX FET RPD RPM ROP $ 2 (" header data for each bit run in separate files. 2 .5000 START DEPTH 7 991. 0 7 998.5 7998.5 7998..5 8018.0 8018.5 8040.5 STOP DEPTH 10156.5 10163.5 10163.5 10163.5 10163.5 10163.5 10205.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL~TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM. LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLtJIDLOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 03-0CT-01 Insite 66.16 MemQry 10205.0 8059.0 10205.0 21.8 49.3 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 6.750 LSND 10.50 10.5 9.3 900 4.2 1. 050 .520 1.040 2.100 72.0 152.0 70.0 68.0 (' (~' REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.................... - . -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7991 10205 9098 4429 7991 10205 ROP MWD020 FPH 0 344.04 107.326 4330 8040.5 10205 GR MWD020 API 27.33 361. 65 139.22 4332 7991 10156.5 RPX MWD020 OHMM 0.84 1714.33 2.99999 4331 7998.5 10163.5 RPS MWD020 OHMM 0.83 1780.75 3.43729 4331 7998.5 10163.5 RPM MWD020 OHMM 0.68 1703.58 3.34495 4291 8018.5 10163.5 RPD MWD020 OHMM 0.13 1958.8 3.,71665 4292 8018 10163.5 FET MWD020 HR 0.2048 32.7444 L 49498 4331 7998.5 10163.5 First Reading For Entire File..........7991 Last Reading For Entire File...........10205 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name............ ..STSLIB.OO3 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH 3 header data for each bit run in separate files. 3 .5000 STOP DEPTH (' GR FET RPD RPM RPS RPX ROP $ 10157.0 10164.0 10164.0 10164.0 10164.0 10164.0 10205.5 10712.0 10722.5 10722.5 10722.5 10722.5 10722.5 10765.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBI G) : MUD VISCOSITY (S): MUD PH:. MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....... .... . . .. . . . .. . . . Datum Specification Block sub-type...O C." 09-0CT-01 Insite 66.16 Memory 10765.0 10205.0 10765.0 19.3 20.9 TOOL NUMBER PB02100HWRG6 PB021 0 0 HWRG 6 4.750 Quikdril n 8.40 40.0 9.3 200 22.0 4.000 1. 640 4.750 5.000 73.0 188.0 73.0 73.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 ( ('n RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10157 10765 10461 1217 10157 10765 ROP MWD030 FPH 1.93 140.24 50.1186 1120 10205.5 10765 GR MWD030 API 12.75 524.5 53.423 1111 10157 10712 RPX MWD030 OHMM 0.68 2000 62.0218 1118 10164 10722.5 RPS MWD030 OHMM 0.85 2000 78.9255 1118 10164 10722.5 RPM MWD030 OHMM 1. 01 2000 128.586 1118 10164 10722.5 RPD MWD030 OHMM 0.48 2000 130.045 1118 10164 10722.5 FET MWD030 HR 0.6022 134.819 11.3587 1118 10164 10722.5 First Reading For Entire Fi1e..........10157 Last Reading For Entire File...........10765 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OO4 Physical EOF File Header Service name............ ..STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/22 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPM RPS RPX RPD ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 10712.5 10723.0 10723.0 10723.0 1.0723. 0 10723.0 10765.5 STOP DEPTH 10841.5 10852.5 10852.5 10852.5 10852.5 10852.5 10895.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT):. BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 10-0CT-0l Insite 66.16 Memory 10895.0 10765.0 10895.0 20.1 ( MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 It BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): It BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: It NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units... ... . . . . . . . . .. . . . . . . . Datum Specification Block sub-type...O (" 20.6 TOOL NUMBER PB02100HWRG6 PB02100HWRG6 4.750 Quikdril n 8.50 41. 0 8.8 300 10.9 4.000 1. 810 3.700 4.200 70.0 162.7 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 FET MWD040 OHMM 4 1 68 24 7 RPD MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10712.5 10895 10803.8 366 10712.5 10895 ROP MWD040 FPH 9.79 211.39 97.173 260 10765.5 10895 GR MWD040 API 12.06 51.05 21.5627 259 10712.5 10841. 5 RPX MWD040 OHMM 1. 95 20.95 4.98746 260 10723 10852.5 RPS MWDO 40 OHMM 1.9 17 . 03 4.63204 260 10723 10852.5 RPM MWD040 OHMM 1.86 14.1 4.40069 260 10723 10852.5 FET MWD040 OHMM 0.3392 20.3682 7.28871 260 10723 10852.5 RPD MWD040 HR 1. 88 10.28 4.19669 260 10723 10852.5 First Reading For Entire File..........l0712.5 Last Reading For Entire File...........10895 ( (' File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/02/22 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO5 Physical EOF Tape Trailer Service name.............LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 02/ 02/ 22 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name..-........UNKNOWN Comments.................STS LIS .Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................02/02/22 Origin...................STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
