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Home My WebLink About200-133 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. -~ 0 O' ~' ~'~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) // Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~~INDY Scanning Preparation I x 30 = ~ + BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: ~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREP ERE FOUND: S NO RESCANNEDBY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI410 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 A G f Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IS Exploratory ❑ r 200 -1330 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 22136 -02 -00 8. Property Designation (Lease Number) : ^ 9 . Well Name and Number: ADLO- 028288 PBU P -12B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11821 feet Plugs (measured) None feet true vertical 9032.13 feet Junk (measured) None feet Effective Depth measured 11815 feet Packer (measured) 6616 9683 10032 feet true vertical 9032.14 feet (true vertical) 6713 9006 9011 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 32 - 142 32 - 142 Surface 2665' 10 -3/4" 45.5# NT -80 31 - 2696 31 - 2696 5210 2480 Production 6982' 7 -5/8" 29.7# NT -95HS 30 - 7012 30 - 6891 8180 5120 Liner 2511' 5 -1/2" 17# L -80 6864 - 9375 6756 - 9004 7740 6280 Liner 1014' 3 -1/2" 9.3# L -80 9289 - 10303 8993 - 9016 10160 10530 Liner 1804' 2 -3/8" 4.6# L -80 10011 - 11815 9011 - 9032 Perforation depth: Measured depth: - SEE ATTACHED _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 29 - 6864 29 - 6756 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker SABL -3 Packer 6816 6713 3 -1/2" ECP Packer 1"! 9683 9006 3-1/2" ECP Packer ( - i v 10032 9011 ,IAN 1 12. Stimulation or cement squeeze summary: illgd k a o 9 ,t7/; Intervals treated (measured): ,f , G Treatment descriptions including volumes used and final pressure zf`o 01S S/00 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 91 338 247 248 Subsequent to operation: 367 1233 875 271 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na . - oe Lastufka IIIk Title Data Manager Signat e TIM% , ( Phone 564 -4091 Date 1/9/2012 RBDJwS atti12 101 7e / /11/11,-/ . • / K ,ry Form 10 -404 Revised 10/2010 Submit Original Only P -12B 200 -133 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P -126 4/11/95 SL 9,360. 9,674. 9,003.36 9,005.94 P -12B 4/11/95 SL 9,710. 10,023. 9,006.5 9,011. P -12B 4/11/95 SL 10,060. 10,281. 9,012.08 9,015.51 P -12B 11/19/95 APF 9,268. _ 9,280. 8,987.62 8,990.97 P -12B 11/19/95 APF 9,316. 9,336. 8,998.48 9,001.3 P -12B 2/28/98 APF 9,242. 9,268. 8,978.79 8,987.62 P -12B 2/28/98 APF 9,280. 9,304. 8,990.97 8,996.35 P -12B 2/28/98 APF 9,336. 9,350. 9,001.3 9,002.66 P -12B 9/29/00 SL 10,011. 11,815. 9,010.61 9,032.14 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FL 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 • • • P -12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/16/2011; T/I/0= 829/859/0 Temp =SI Pump Mud Acid Treatment (Acid) Pumped down Tbg in i 3 stages with a total of the following: 645 bbls 3 %NH4CI + F103 :187 bbls 12% HCI Acid E I183 bbls 9:1 Mud Acid ;24.7 bbls 7.5% Oilseeker 150 bbls diesel 13.4 bbls meth 'ASRC Well Testers to flowback the well. FWHP's= 404/920/0 12/16/2011 :ASRC Test Unit #4. P -12 Acid Flowback. SB for SLB pumpers ** Continued from WSR 12-15-2011** SB LRS to pump acid job, POP well, flowback main Acid Job '* *Job in Progress continue on WSR 12- 17- 2011 ** Inlet P -12, Outlet P -15 12/17/2011 ASRC Test Unit #4. P -12 Acid Flowback. ** Continued from WSR 12-16-11** Cont Acid Flowback * *Job in Progress continue on WSR 12-18-11** Outlet well P -15 12/18/2011 :ASRC Test Unit #4. P -12 Acid Flowback. * *Continue from WSR 12-17-11** Cont Acid Flowback * *Job in Progress continue on WSR 12-19-11** Outlet P -15 12/19/2011'ASRC Test Unit #4. P -12 Acid Flowback. ** Continue from WSR 12- 18 -11 ** Complete Acid Flowback, ph verified to be a 7, Divert flow to production, Stabilize well ** Job in Progress continue on WSR 12- 20 -11 ** Outlet P -15 12/20/2011; ASRC Test Unit #4. P -12 Well Test. * *Continue from WSR 12-19-11** Cont flow and ;stabilize well, Complete 6 hr test. 1923 bfpd, 83.58% WC, FTP -360, GLR -1.7 mmscf /d. RDMO. * *Job Complete ** Outlet P -15. P -12 & P -15 turned back over to i DSO and left shut in. Master VL - Open. IA & OA casing VL - Open. SSV - S /I. Swab VL - S /I. Wing VL - S /I. Final TIO S/I/1400/0. DRILLS completed FLUIDS PUMPED BBLS 645 3% NH4CL +F103 187 12% HCL ACID 183 9:1 MUD ACID 24.7 7.5% OILSEEKER 150 DIESEL 13.4 METH 1203.1 TOTAL TREE = 4" CM/ WELLHEAD = FMC P-I 2 B SAFEY : WELL ANGLE > 70° @ 9258'. *** NO ACTUATOR= 1 OTIS CEMENT AROUND PRE - DRILLED LNR.*** KB. ELEV �- 92.09' ' i F. ELEV = _ 55.49' KOP = _ 5436' Max Angle = 96° @ 11491 L I 2198' 1-14 -1/2" HES HXO SSSVN, ID = 3.813" I Datum MD = .., 9090' _ Datum ND == 8800' SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH SIZE DATE 120" CONDUCTOR I 110' i 4 3006 3006 0 MERLA DOME BK 16 08/19/11 110-3/4" CSG, 45.5 #, NT -80 BTRS, ID = 9.95 ", --) 2696' 1 L 3 4974 4974 1 MERLA SO BK 20 08/19/11 2 6286 6232 25 MERLA DMY BK 0 09/03/00 1 6727 6632 25 MERILA DMY BK 0 08/19/11 Minimum ID = 1.995" @ 10015' I I 6805' I-14 -114 HES X NIP, ID = 3.813" I TOP OF 2 -3/8" LINER LS 6816' I- 7 -5/8" X 4 -1/2" BKR SABL -3 PKR w / KEH -22 ANCHOR, ID = 3.875" i 6841' I- 14 -1/2" HES X NIP, ID = 3.813" I 6864' ' III 6852' J—I4 -112" HES XN NIP, ID = 3.725" I 4 -1/2" TBG- TDS, 12.6 #, L -80 NSCT, - 686 .0152 bpf, ID = 3.958" 17-5/8" X 5 -1/2" BKR TIEBK SLV, ID = 5.75" 1-L 6864' 1- / • 6864' I- 14 -1/2" WLEG, ID = 3.958" I 7 -5/8" X 5-1/2" BKR LNR TOP PKR —I 6872' I 6872' I—I ELMD TT LOGGED 11/18/95 I & HMC HGR, ID = 4.375" 7 -5/8" CSG, 29.7 #, NT -95HS NSCC, —I -7012' I- MILLOUT WINDOW (P -12B) 7012' - 7061' ID = 6.875" 9289' 115 112" X 3 -1/2" TM/ SS HRZ PKR/HNGR, ID = 3.00" 5 -1/2" LNR, 17 #, L -80 NSCC, -J 9375' .0232 bpf, ID = 4.892" I , PERFORATION SUMMARY I I REF LOG: MWD on 09/28/00 IN I 9683' I-13-1/2" X 4.30" ECP PKR, ID = 2.992" I ANGLE AT TOP PERF: 67° @ 9242' Note: Refer to Production DB for historical perf data , I 1 10011' I—j 2.70" BKR DEPLOY SLV, ID = 2.250" I SIZE SPF INTERVAL Opn /Sqz DATE P -12A 0 1 10032' I- 13 -1/2" X 4.30" ECP PKR, ID = 2.992" (BEHIND CT LNR) I 2 -7/8" 6 9242' -9268' 0 02/28/98 3 -3/8" 4 9268' -9280' 0 11/19/95 i 11 2 -1/2" 6 9280' -9304' 0 02/28/98 I 2 -1/2" 4 9316' -9336' 0 11/19/95 j 1 1 2 -1/2" 6 9336' -9350' 0 02/28/98 3 -1/2" SLTD 9360 - 9674 SLOT 04/09/95 ` ` 3 -1/2" SLTD 9711 - 10023 SLOT 04/09/95 3 -1/2" SLTD 10069 - 10281 SLOT 04/09/95 .. 11780' —I 2 3/8" BKR 0-RING SUB, ID = 1,0" P -12B 2 -3/8" 2 10111'- 11780' PREDRILL 09/30/00 .. \ ` --- .. . 13-1/2" LNR, 9.3 #, L -80 EUE 8RD, .0087 bpf, ID = 2.992" I—I 10303' I I2 -318" LNR, 4.6 #, L -80 FL4S, .0039 bpf, ID = 1.995" I 11815' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/24/91 AUDI 2 ORIGINAL COMPLETION 06/03/11 DLB/ PJC PERF CORRECTION WELL: P-12B 04/11/95 N -28E SIDETRACK (P -12A) 08/22/11 SWC/ PJC GLV C/O(8/19/11) PERMIT No: '2001330 09/30/00 CRD1 CTD SIDETRACK (P -12B) 09/20/11 DLB/ PJC DRAWING CORRECTIONS AR No: 50- 029 - 22136 -02 06/02/01 CH/KAK CORRECTIONS SEC 31, TIIN, R13E, 2525' FSL & 2190' FWL 03/04/09 BSE/PJC PULL PXN PLUG @ 6852' 06/04/09 DAV/TLH GLV C/O (04/05/09) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August22, 2011 :',1 r ,V Mr. Tom Maunder rialrOSSION Alaska Oil and Gas Conservation Commission owl 01 81 6 G 333 West 7 Avenue AndOi Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB P -Pad j00 — 133 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P- 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) P -Pad Date: 07/21 /11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal P - 1920920 500292228700 0.30 NA 0.30 NA 0.85 4/24/2010 P -02A 2000840 500292237601 0.30 NA 0.30 NA 4.25 4/25/2010 P -03A 1972280 500292217601 12.70 5.0 0.30 7/12/2010 2.55 8/5/2010 P -04 1910760 500292218000 1.80 NA 1.80 NA 15.30 4/25/2010 P -05A 2000510 500292254501 0.80 NA 0.80 NA 5.95 4/25/2010 P -06B 2051380 500292216602 11.30 3.0 1.00 7/12/2010 9.35 8/5/2010 P -07A 2011960 500292253501 0.50 NA 0.50 NA 1.70 4/24/2010 P -08A 2000850 500292237701 0.10 NA 0.10 NA 0.85 4/24/2010 P -09 1930580 500292236200 0.10 NA 0.10 NA 0.85 4/24/2010 P -10 1910520 500292215800 3.00 NA 3.00 NA 28.05 4/24/2010 P -11 1910290 500292214300 3.00 NA 3.00 NA 23.80 4/23/2010 P -12B 2001330 500292213602 0.30 NA 0.30 NA 0.85 4/23/2010 P -13 1901110 500292208000 0.30 NA 0.30 NA 1.70 4/23/2010 P -14 1910070 500292212900 7.50 NA 7.50 NA 56.10 7/21/2011 P -16 1901630 500292211300 4.30 NA 4.30 NA 37.40 4/22/2010 P -17 1901550 500292210500 8.00 NA 8.00 NA 89.30 4/28/2010 P -19 1901360 500292209400 0.80 NA 0.80 NA 5.10 4/21/2010 P -20B 2001590 500292208902 0.20 NA 0.20 NA 0.85 4/21/2010 P -21B 1970640 500292214802 0.40 NA 0.40 NA 4.30 4/21/2010 P -22 1931210 500292239600 0.30 NA 0.30 NA 1.70 4/23/2010 P -23 1931120 500292239300 0.30 NA 0.30 NA 0.85 4/24/2010 P -24 1970540 500292275500 1.80 NA 1.80 NA 8.50 4/24/2010 P -25 1970260 500292274200 64.00 24.0 2.60 7/17/2011 23.80 7/20/2011 P -26 1962000 500292272700 2.60 NA 2.60 NA 22.10 4/25/2010 P -27 2040500 500292320300 1.00 NA 1.00 NA 6.80 4/25/2010 P -28 2100480 500292342500 1.20 NA 1.20 NA 10.20 8/7/2010 F:\LaserFiehe\CvrPgs _I nserts\M ierofi I m _ Marker.doe MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ...¡¡¡"-;"! ~... ";""~~'........ .Ii. ,~.. ) ') Permit to Drill 2001330 MD 11821 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 919/2002 Well Name/No. PRUDHOE BAY UNIT P-12B Operator BP EXPLORATION (ALASKA) INC 9032 - Completion Dat 9/30/2000 Completion Statu 1-OIL ---._.._ Current Status 1-OIL~--- APl No. $0-029-22136-02-00 REQUIRED INFORMATION Mud Log N_go Sample N~o Directional Survey ~ ~/-~.~ ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Interval Run No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments D D R R D D L L L L L L R R d d M/~.[~S u rvey Report .,~l~.Survey Report ,~16 ~tion 2/5 5 2/5 8945 11684 Open 10300 11808 Open FINAL FINAL 10244 11821 I OH FINAL 8945 11684 OH FINAL 10300 11821 OH FINAL 10300 11821 OH FINAL 10300 11808 CH FINAL 10300 11808 oh 10/25/2000 09816~8~5-11684 6118/2001 1015-1---10300-11808 2/2/2001 Digital Data 2/2/2001 10244-11821 Paper Copy 10/25/2000 981~;L 10/25/2000 8945-11684 6/18/2001 10300-11821 BL, Sepia 6/18/2001 10300-11821 BL, Sepia 6/1812001 10300-11808 LIS Verification 6/18/2001 t045-1--- 10300-11808 digital data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? ~ Analysis ~ R e.c~iv~.d '~ Daily History Received? ~)/N Formation Tops r~ / N Comments: Permit to Drill 2001330 MD 11821 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT P-12B Operator BP EXPLORATION (ALASKA) INC 9032 Completion Dat 9/30/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22136-02-00 UIC N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ ACID WASH Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development ~ Exploratory_ Stratigraphic._ Service_ 4. Location of well at surface 2754' FNL, 2815' FEL, Sec. 31, T11N, R13E, UM At top of productive interval 2837' FNL, 1531' FEL, Sec. 31, T11N, R13E, UM At effective depth 3097' FNL, 4323' FEL, Sec. 32, T11N, R13E, UM At total depth 3097' FNL, 4317' FEL, Sec. 32, T11N, R13E, UM (asp's 631473, 5947256) (asp's 632758, 5947196) (asp's 635251, 5946980) (asp's 635257, 5946980) 12. Present well condition summary Total depth: measured true vertical 11821 feet Plugs (measured) 9032 feet 6. Datum elevation (DF or KB feet) RKB 87 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number P-12B 9. Permitnumber/approvalnumber 200-133 10. APInumber 50-029-22136-02 11. Field/Pool Prudhoe Ba¥Oil Pool Effective depth: measured true vertical 11815 feet Junk (measured) 9032 feet Casing Length Conductor 110' Surface 2664' Production 6980' Liner 2511' Sidetrack Liner 1014' Sidetrack Liner 804' Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arcticset 142' 142' 10-3/4" 3392 c.f. Permafrost 2696' 2696' 7-5/8" 1474 c.f. Class 'G' 7012' 6891' 5-1/2" 155 sx Class 'G' 6864'- 9375' 6756'-9004' 3-1/2" Uncemented Slotted Liner 9289' - 10303' 8993' - 9016' 2-3/8" Uncemented Slotted Liner 11011' - 11815' 9046' - 9032' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 9242'- 9304', 9316' - 9350', Slotted Liner 9360' - 9674', 9710'- 10023', Slotted Liner (continued) 10060' - 10281 ', 10111' - 11780'. Open Perfs 8979' - 8996', 8998' - 9003', Slotted Liner 9003' - 9006', 9007' - 9011', Slotted Liner (continued) 9012' - 9016', 9013' - 9032' 4-1/2", 12.6#, L-80 TBG @ 6816'. 4-1/2" 12.6# Tubing Tail below PKR to 6872'. 7-5/8" x 4-1/2" BKR SABL-3 Packer @ 6816'. 7-5/8" x 5-1/2" BKR PKR/HNGR W/TB @ 6872'. 5-1/2" x 3-1/2" TIW SS HRZ PKR/HNGR @ 9289'. 3-1/2" x 4.30" CTC CSG, PKR 4-1/2" HES HXO SSSVN @ 2198'. _~_ _~i~lt I1"='~"~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/13/2002 Subsequent to operation 03/18/2002 OiI-Bbl 256 Representative Daily Averaqe Production or Iniectigp D. at~l~&_ - Gas-Mcf Water-B~ ~in.q Pressure 1455 230 '~ 339 235 1524 235 360 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ._X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~-,~~~.i~Jc~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date March 19, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE P-12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/15/2002 ACID: ACID TREATMENT 03/16/2002 ACID: SCALE REMOVAL EVENT SUMMARY 03/15/02 MIRU CTU #8 FOR ACID PERF WASH. WAIT ON SUPPORT EQUIPMENT AND FLUIDS. 03/16/02 KILL WELL WITH 150 BBLS OF FILTERED 2% KCL FOLLOWED BY 100 BBLS CRUDE. DISPLACE METHANOL OUT OF COIL WITH KCL. RIH TO 9200' CTMD. WELL APPEARS TO BE AT BALANCE OR ON A SLOW VAC. PUMP 74 BBLS 12/10 - HCL/XYLENE RECIPROCATING FIRST 40 BBLS FROM 9200' TO 9300', THEN LAST 34 BBLS PARKED AT 9200'. WHP REMAINED AT ZERO TO 10 PSI DURING TREATMENT. A BREAK IN PUMP PRESSURE WAS SEEN LATE IN THE TREATMENT. OVERFLUSHED ACID TO FORMATION WITH 150 BBLS OF FILTERED 2% KCL. POOH. MADE ARRANGEMENTS WITH PAD OPERATOR AND PCC TO PUT WELL BACK ON PRODUCTION ASAP AND TEST AFTER 48 HOURS. RD DS CTU #8. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 55 METHANOL 150 2% KCL WATER 100 CRUDE 74 12/10 HCL/XYLENE 379 TOTAL Page 1 Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission , . 333 West 7th Avenue, Suite 100 :'"":"'"' ' Anchorage, AK 99501 :~, Attention: Lisa Weepie Reference: Pmdhoe Bay North Slope, Alaska P-12B w~ng: .......: Contains the follo :" " .., ,' . :.. .'. , .. ... ., ., , . . .. . . Format disk'.' ' "'., ' '"' '. '. ,.. .. Film .' .' '.' , .. . .., ,. , . Depth GR,..'p:fin~::', ,,.,,.,...'' .,.'.,.:.;. '...',. "i'"::'..' i:."..:'".'...' "'"' TVD-GR print "':"'.:'" '""'"':": ...... ': ...... ,',".".'"I! ,I'"'""".','I ' ":"'"""'"?"'"". ~ .............. ":'!'/' .... ",""' ":i ': ""' ' ' '., ' ' ' ',"." '.':';"~ .. . .". ' :' ','~ "i'.: '.," ': ',"::' '.. ':: ', .:i. ',i " ': : : .... , ","'!:. ,'!. ":::':': i'~:,:i, i:'!:":','.',~:::.' ";" '~ "' . .. ':.:" .:"":, '" " ' ',":. ' "' ', ".:...' ',,.,,,:..'..,.. "' :."." :.' ':!I...' ,'::. Sent By: Josef Berg ,. Date: June 14, 2001 Received~~j ~~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER RECEIVED ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 JUN 1 8 2001 0il & O~s Cons. Comm~ Anc!lotage STATE OF ALASKA ALASIK~....,L AND GAS CONSERVATION COM~] ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Ita Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-133 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22136-02 4. Location of well at surface :' -':':': ...... ' "' -"~":- 9. Unit or Lease Name 2525' NSL, 2190' EWL, SEC. 31, T11N, R13E, UM~ b.".' - ~ '~ i'. Prudhoe Bay Unit At top of productive interval 2442' NSL, 3474' EWL, SEC. 31, T11N, R13E, U M ..-~:-~. '.0.~_. At totaldepth .. V,:.';~.:'.L-",~ 'iI~H'C~-'-'~''''~;~~'~''~~-'- 1O. WellNumber 2181' NSL, 962' EWL, SEC. 32, T11N, R13E, UM~.i ........ ..... .............. ,Z~Z::>.. . · P-12B 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sc~'A'I'N~. ......... 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 86.59' ADL 028288 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. No. of Completions I I, N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119.-~'ir~ctional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost I (Approx.) (Nipple) 2198' MDI 1900' 11821 9032 11815 9032 "~1 liaYes •No 22. Type Electdc or Other Logs Run MWD, GR, RES 23. CASING, LINER AND CEMENTING RECORD CASING SE'FrlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# NT-80 Surface 2696' 13-1/2" 3392 cuft Permafrost 7-5/8" 29.7# L-80 Surface 7012' 9-7/8" 1474 cuft Class 'G' 5-1/2" 17# L-80 6864' 9375' 6-3/4" .155 sx Class 'G' 3-1/2" 9.3# L-80 9289' 10303' 4-3/4" Jncemented Slotted Liner 2-3/8" 4.6# L-80 10011' 11815' 3" Llncemented Slotted Liner 24. Perforations pp. en to, Producti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and intervm, size ano numDer) SIZE DEPTH SET (MD) PACKER SET (MD) (P-12) Perf Intervals (P-12B) 2-3/8" Slotted Liner 4-1/2", 12.6#, L-80 6864' 6816' MD TVD MD 'rVD 9242' - 9304' 8979' - 8996' 10111' - 11780' 9013' - 9032' 9316' - 9350' 8998' - 9003' ;,',"'"",I, i?:"." .?'";i~ ~:'""':' ~', ~ '~ .'~ ........ ~'~ .......... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ;!; ........ ';i ~.~: ~! ...... '~ .";" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (P-12A) Slotted Liner Intervals 2500' Freeze Protect with 120 Bbls of MeOH 9360' - 9674' 9003' - 9006' 9710'- 10023' 9007' - 9011' 10060' - 10281' 9012' - 9016' ~"?...i i .... : ........ ". ..... :'" ,' '"",'""' :~'."': ...... 27. ,-,.., ~.t,,....., .......... =,~ ',' PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 6, 2000 Flowing Date of Test ~Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing 3asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. 45N 10878' 9037' 45P 10902' 9038' ..,.-,.,~:~, ~,;~:~;.~ .~;:~,~.,. ?,..~.~' ~i ........ ~, ~' iii'.i=...'.~ i~"ii ,.!.~;~i ;' !"" .~,. ~' ' ~ i".i il .~.~ ~ '"'"'~' ~ i' :: .,...:, }{ '{;~ =[!:.-.... !.!:m."' ,'..';...?,~, ,,,[I,....:. ~t'~'.,.~; ,:"~ .... ,. · · ~' :~ ~ ~J'~ ~ ...... ~i'~ "' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble.~~lf~ ~ Title Technical^ssistant Date P-12B 200-133 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AN;) 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. ITEa 21 -' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27-' Method of Operation: Flowing, Gas Lift, Rod Pump,' Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no COreS taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: P-12B Accept: 09/22/00 Field: Prudhoe Bay Spud: 09/23/00 APl: 50-029-22136-02 Release: 09/29/00 Permit: 200-133 CTD Unit: CDR1 Date COIL TUBING DRILLING 09122/00 Move in, rig up and accept rig. Nipple up BOP stack and test. Witnessed waived by AOGCC inspector Lou Grimaldi. 09/23/00 Make up and run BHA #1. Set down at 10047' ctm. Pull out of hole for mill. Run BHA #2 with 2.8" Crayola mill. Ream 9723' and 10060'. 09/24100 Ream at 10060'. Drift to 10334' (corrected) Log tie in. Pull out of hole for bit. Run BHA #3. Drill from 10332' to 10599'. Pull out of hole for orienter. Run BHA #4. 09/25/00 Drill from 10599' to 11264'. Pull out of hole for motor. Make up BHA #5. Run in hole. 09/26/00 Drill from 11264' to 11374'. Pull out of hole for chunked motor. Run in hole with BHA #6. Drill from 11374' to 11482'. 09/27/00 Drill from 11482' to 11821' (TD). Drift hole. Lay in new Flopro. Log tie-in. Pull out of hole for log. 09/28/00 Log open hole with memory induction. Run in hole with drilling BHA, condition hole for liner. 09/29/00 Make up 56 joints of 2-3/8" FL4S pre-drilled liner. Run in hole, no shear. Pull out of hole with liner. 09/30/00 Liner at surface. Redress LBRT. Run in hole to TD, release liner. Pull out of hole, displacing to KCI. Freeze protect upper 2500' with MeOH. Nipple down and release rig. BPAmoco (' BP Amoco ( Baker Hughes INTEQ Survey Report INTEQ Company: BP Amooo Field: Prudhoe Bay Site: PB P Pad' Well: ' P-12 Wellpath: P-12B Date: .11/6/2000 'Yl~: 16:28:49 Page: 1 Co-oP; _-~__*_e(N]!:) RM'e~a~: Well: P-12, Tree No~ V~ ~)' ~~: 19: 12 ~2~19~ 00:00 ~.6 ~ ~S) ~~: ' Well (0.~E~0.00N,99.00~i) Sm~ C~n M~: Minimum ~m Db: O~e Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB P Pad TR-11-13 UNITED STATES: North Slope Site Position: No, thing: From: Map Easting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ff 5949377.17 ft Latitude: 70 16 12.612 N 623154.06 ft Longitude: 149 0 14.402 W North Reference: True Grid Convergence: 0.94 deg Well: P-12 P-12 Well Position: +NAS -2257.01 ft Northing: +E/-W 8284.06 ff Easting: Position Uncertainty: 0.00 ff Slot Name: 12 5947256.19 ft Latitude: 70 15 50.370 N 631473.25 ff Longitude: 148 56 13.320 W Wellpath: P-12B 50O292213602 Current Datum: 19: 12 3/28/1995 00:00 Magnetic Data: 9/14/2000 Field Strength: 57456 nT Vertical Section: Depth From (TVD) ff Drilled From: P-12A Tie-on Depth: 10244.08 ff Height 86.59 ff Above System Datum: Mean Sea Level Declination: 26.70 deg Mag Dip Angle: 80.72 deg +N/-S +E/-W Direction ft ft deg 0.00 0.00 0.00 99.00 Start Date: 9/27/2000 Engineer: Tied-to: Su~ey: MWD Measured While Drilling Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard From: Definitive Path Annotation ,',~%"',?,:~::q",,'.',",?,':::,?i';',.::~'"',',.,~' 'i'q,~i:~:iii.:',i'/:':':i','~':;?, %?:" =:',: 7%,,;!'., i,.h":,:"=g';';'" [i::,~,"":~'~,.'r' F'=,'~ :,,',.:"l'?";:5.i.:;~'.'=,~:?,.'!':.,F:!~J,~p;,:. !~ ,,¥ [=' :.', ~ ',.~',~ .:,':'=~., ,,:j.. ':, ,'? ,q. ',,~,~";~,:~ :: ,~ ~,,r ,.=~:= ,,,,,~: ~i,,y,..,:,=.~]:; ,.,,,,:,, =~,:, ,?,..,, ,, ~ ...,=,,j ,,::~: ~.=~,, ,..,. ~,..,,; ,,-:,, i,, ....... .q , q ,,;:.~:, ,.,,., .... !,,,i i:..,~'. :, ',~I~':'.; .I' , '~ '~:':i[:~:' :!' :' ',?!'",;: '..,, ~,: ,:.. ,? ~!' I! ::.~;i:~.,!,. i !,! :.,, '., , ;:~ . ': !,'~ ;,., ',t':,l:', ',' :"" ¢i,:: i"{;'!;! !,",,," ' "":' ','..,'h ~ h/ ,,' .,L;.,,l,,.;::, ,I',:';'~,;":': ',".'~; q",! .i,'!,:.'.','":;,'~'.,'(,;' !'"!:,'i:q'"l'." q':t:,':" : :/ ~::.'";'!':(~,',,),,!:," ""',:/' ' "~;!' .;',:~.,!t~,u¥..,",;',,,I ' "' ~ , ~;. ,, r. .... ' ...... . ~',~ ,~ ., ' ~,, , ~ '. ,~ .... f~., ~ ' . '~' .? ',~ ,' ' ~' '"~ , ':~", ..... ~, ,~ ...... ,..,, ,, , :r~I~'r ,',., ~ .... . .... ~ ,~ ,, ~,,¢....,~;,, I .; ~,.. ,,~, ' '' " ....... "'' ' '"'" ',';5[! 1' "' '"' ...... :" '' '" , ~ .... ", "~. ~ ' ,I /' x .... ' ..... '~' '" ':'d"" ' ',' ','t ,', ii :'[~;?" ' : ' ' '~' ; ..... ~,~ .... '' ' :''~'':' '; '~ '~}' : '' ,' '1 :' '; :""''. ":''' . I~ :,'~ ~ : ''I:"' ; .... , ,, ~ , ,, , , , ,, , . , ,, , , ..... ,, ..,, ..... , ,~.,h,~ ,.U,,.,,. , .-,,,,,,., ,,.~, ,,,,..~.,.. ,,.;,,.,,, ,,.~,/, ,,,.,,~. ,~ .... "~""," "h'" '~ %'":' :'"'"' "/""' ~': :'~' "":' ",',' .,,,,,h,, ~,,, ,,,,,, ,,.:~, ,,,%,,,.;:~,,",,,,::,'. ~..',/,:.,.,~ l,"~,;.h:,,~,. 'P,"um,.c ' 10244.08 9015.34 Kick-off Point 11821.00 9031.96 Projected to TD 10244.08 90.10 94.50 9015.34 8928.75 -89.33 2281.24 5947206.71 633755.52 0.00 2267.13 10300.00 90.66 94.50 9014.97 8928.38 -93.72 2336.99 5947203.30 633811.33 1.00 2322.88 10339.00 87.30 94.60 9015.67 8929.08 -96.81 2375.85 5947200.89 633850.24 8.62 2361.75 10369.90 87.20 98.80 9017.15 8930.56 -100.41 2406.50 5947197.82 633880.94 13.58 2392.58 10427.70 90.20 105.40 9018.46 8931.87 -112.52 2462.96 5947186.71 633937.60 12.54 2450.24 10449.90 90.60 107.60 9018.31 8931.72 -118.82 2484.25 5947180.77 633958.99 10.07 2472.25 10494.70 87.50 112.50 9019.05 8932.46 -134.17 2526.31 5947166.16 634001.31 12.94 ' 2516.19 10527.30 85.50 115.60 9021.04 8934.45 -147.43 2556.02 5947153.43 634031.25 11.30 2547.61 10556.40 86.90 116.00 9022.97 8936.38 -160.07 2582.16 5947141.25 634057.60 5.00 2575.41 10599.00 88.90 113.50 9024.53 8937.94 -177.89 2620.82 5947124.11 634096.56 7.51 2616.38 10631.00 88.00 111.70 9025.40 8938.81 -190.18 2650.35 5947112.33 634126.30 6.29 2647.47 10683.00 88.30 107.20 9027.07 8940.48 -207.48 2699.34 5947095.89 634175.58 8.67 2698.56 10711.00 88.50 106.90 9027.86 8941.27 -215.69 2726.10 5947088.16 634202.48 1.29 2726.28 10743.00 86.70 105.11 9029.20 8942.61 -224.50 2756.83 5947079.88 634233.35 7.93 2758.01 10772.00 87.60 106.90 9030.64 8944.05 -232.49 2784.67 5947072.38 634261.33 6.90 2786.75 10801.00 85.90 111.80 9032.28 8945.69 -242.08 2811.98 5947063.27 634288.80 17.86 2815.23 10851.00 86.60 115.30 9035.55 8948.96 -262.01 2857.71 5947044.14 634334.86 7.12 2863.51 10888.00 87.60 122.30 9037.43 8950.84 -279.80 2890.07 5947026.92 634367.53 19.09 2898.26 ePArnoco BP Amoco ma. B(a er Hughes INTEQ Survey Re rt INTEQ Company: BP Amoco Date: 11/6/2000 Time: 16:28:49 Page: '2 Field: Prudhoe Bay Co-ordinate(NE) Reteron~: Well: P-12, True North Site: PB P Pad Vertical (T%,'D) Reference: 19: 12 3/28/1995 00:00 86.6 Well: P-12 Section (VS) Reference: ' Well (0.00E,0.00N,99.00Azi) Welipath: P-12B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD SSTVD N/S E/W MapN MapE DIS ¥S ft dog deg ff ff ff ff ft ff deg/100ft ft 10954.00 85.80 121.60 9041.23 8954.64 -314.67 2945.97 5946993.04 634424.03 2.93 10988.00 84.50 118.80 9044.10 8957.51 -331.71 2975.25 5946976.51 634453.60 9.05 11006.00 86.00 117.10 9045.59 8959.00 -340.11 2991.09 5946968.38 634469.59 12.57 11035.00 86.80 116.00 9047.41 8960.82 -353.05 3016.98 5946955.90 634495.70 4.68 11058.00 86.60 113.90 9048.74 8962.15 -362.74 3037.80 5946946.58 634516.68 9.16 11089.00 84.70 111.40 9051.09 8964.50 -374.64 3066.33 5946935.18 634545.40 10.11 11116.00 83.80 109.30 9053.80 8967.21 -383.98 3091.51 5946926.28 634570.74 8.43 11146.00 85.00 107.90 9056.72 8970.13 -393.50 3119.81 5946917.26 634599.20 6.13 11166.00 85.70 105.80 9058.35 8971.76 -399.28 3138.88 5946911.81 634618.37 11.04 11202.00 86.80 103.30 9060.70 8974.11 -408.30 3173.65 5946903.40 634653.29 7.57 11238.00 88.60 101.60 9062.14 8975.55 -416.06 3208.77 5946896.26 634688.54 6.87 11279.00 88.90 95.60 9063.04 8976.45 -422.18 3249.29 5946890.84 634729.15 14.65 11305.00 88.40 90.68 9063.65 8977.06 -423.61 3275.23 5946889.87 634755.11 19.02 11346.00 90.17 79.78 9064.17 8977.58 -420.20 3316.02 5946893.99 634795.84 26.93 11377.00 94.00 73.80 9063.04 8976.45 -413.13 3346.16 5946901.58 634825.85 22.89 11408.00 95.10 69.20 9060.58 8973.99 -403.33 3375.46 5946911.90 634854.97 15.21 11447.00 95.70 68.10 9056.91 8970.32 -389.19 3411.62 5946926.66 634890.87 3.20 11491.00 96.00 71.70 9052.42 8965.83 -374.15 3452.72 5946942.41 634931.70 8.17 11521.00 95.40 74.20 9049.44 8962.85 -365.40 3481.26 5946951.66 634960.08 8.53 11562.00 93.70 83.70 9046.18 8959.59 -357.58 3521.32 5946960.18 635000.00 23.47 11610.00 94.60 80.80 9042.71 8956.12 -351.13 3568.75 5946967.46 635047.30 6.31 11649.00 94.00 81.20 9039.78 8953.19 -345.04 3607.17 5946974.21 635085.60 1.85 11682.00 94.90 83.70 9037.22 8950.63 -340.72 3639.78 5946979.10 635118.13 8.03 11723.00 94.50 89.60 9033.86 8947.27 -338.33 3680.55 5946982.20 635158.85 14.37 11768.00 90.10 92.80 9032.05 8945.46 -339.28 3725.49 5946982.04 635203.79 12.09 11821.00 90.10 92.80 9031.96 8945.37 -341.87 3778.43 5946980.38 635256.76 0.00 2958.93 2990.51 3007.48 3035.07 3057.15 3087.18 3113.52 3142.95 3162.70 3198.45 3234.36 3275.33 3301.17 3340.93 3369.59 3397.00 3430.50 3468.74 3495.56 3533.91 3579.75 3616.73 3648.27 3688.17 3732.70 3785.39 BP Amoco WELLPA TH DETAILS P-12B 500292213602 Parent Wellpath: P-12A Tie on MD: 10244.08 Vertical Section Origin: Slot- 12 (0.02,0.00) Vertical Section Angle: 99.00° Rig: CDR 1 Depth Reference: 19: 12 3/28/1995 00:00 BPAmoco W¢llpalh: (P- 12/P- 12B) ~' Crcatcd By: Brij Potnis Date: 1 I/6/2000 86.59ft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: P-12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (V8) Reference: Slot - 12 (0.00,0.00) Measured Depth Reference: 19:12 3/28/1995 00:00 86.6 Calcula~n Method: Minimum Curvature ANNOTATIONS TARGET DETA]I.S 'WD MD Annotaticn ~ame ~vo +w-s +FJ-W P-'lzaPo~gonl0e.1 o.00 ~6-~ 2271.8~ 8928.75 10244.08 Kick-off Point 8945.37 11821.00 PmjectedtoTD LEGEND P-12,P-12B,Plan #103 P-12 (P-12) P-12 (P-12A) P-12 (P-12APB1) P-12 (P-12APB2) P-12B T Azimuths to True North Magnetic North: 26.70° Magnetic Field Strength: $7456nT Dip Angle: 80.72° Date: 9/14/2000 Model: BGGM2000 ~ ' . P-12 (P-12APB2) I I · ) . . . ,j Kick-off Point ] ! :. ~- .~. --~ .......... ] P-12,P-12B,Plan #103 ! ' I Preiected to TD , . ............... . . ............... i ' : ' ' . . . Conlacl Information: Direct: (907) 267-6613 E-mail: brij.potnis~,inteq.com Baker Hughes INTEO: (907) 267-6600 ~ ="~ ' --' i .......... I t"'l;~U I I ; ;.*--';~ I ,~';.~7: -500.! · i -- ~-~'=; ' -~ i=~'~., i : } ! ' I Preiected to TD 84001 ..... :...:, .....: ...... . . . ~-- . ............... I ...... i I ' '": :" :;"-"~i I ' · ' ~'":"~ -C~ !! .... - ....... ' -~" ~ I ' ~ ~:ii? · ~:~ .~% ~ · , [ ' ; ..... . . . ~.~:.. ?..--.:. : q , . ................. · ] - %, ~ .,..:~. ~?:'"'i~'-"'.:".., . : ~ I ~ ~ =" "~' ~'"' ~ ' ': ' ;' : i ' ' ' ..:1.., . ;,~-.=~ ~.'-:-'-' --";' ~!i'; '"":' '"'~:' '10001 ! ' · .':- , ~ . _ ..... ¢:~'" '"'-';~:_':: ' i ~ ! i ~ I : ~ I i I : .... F ....T ...... 1' - 7- - -i i · ¢!i~i' : . ~o ~ooo ~'oo ~ooo ~5oo 4000 4500 i - West(-)/East(+) [500ft/in] i- __ ................. i . ' ~8800 ~, i'. .... ,{ '1 P-12,P-12B, Plan #103 [-" i ................. ', i ' 1,-~,-~1' ~ ~-- ~ - - "', 9000 ': ~ ~ ~ .~ ............ ) ~;o~ i '. ........ ~ ' ~ ~ ~ : i ' ~ ~ i ~ i , : : ' ~ ; ~ ~ i : ~ ~ i ' i ....... ~ '-'; ..... J '- ' i 2200 2400 2600 2800 3000 8200 3400 8600 8BO0 4000 V~rtlcal S~ction at 99.00° [20Oft/in] H =LL LOG ,,. TRANSMITTAL P=o~c~ve Diacjnos~.~c Se~v£ces, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99508 'LOG ~ MYLAR / BLUE REPORT WELL DATE TYPE OR SEPIA LINE OR CD-ROM F~LM PmNT(S) ,, BLUEL~N[ P-l'2b 09-27.00' oPen Hole "'I 1 1 , , Res. Eval. CH I " 1' i " · ,,, Mech. CH " ' CaliPer Survey 1 Rpt or I BL Signed · Print Name: ProActive Diagnostic Services, Date' OCT ",5 ' ~ '~000 N~ Oil & Gas Cons. Commission Anchorage Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memo _rylog. com ALASKA OIL AND GAS CONSERVATION COPL~liSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas McCarty CT Drillng Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 ge~ Prudhoe Bay Unit P-12B BP Exploration (Alaska) Inc. Permit No: 200-133 SurLoc: 2525'NSL, 2190'EWL, Sec. 31, Tl lN, R13E, UM Btmhole Loc. 2191'NSL, 970'EWL, Sec. 32, T1 lN, R13E, UM Dear Mr. MeCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit'to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the 'North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION DATED this ~_ ~ ~ day of August, 2000 dlf/En¢losures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKa( ,L AND GAS CONSERVATION COMI~ir,~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work B Drill r-I Redrill 1 lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen [] Exploratory [] Stratigraphic Test [] Development Oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 86.59' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 4. Location of well at surface 7. Unit or Property Name ~'~ 11. Type Bond (See 2O AAC 25.025) 2525' NSL, 2190' EWL, SEC. 31, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2441' NSL, 3474' EWL, SEC. 31, T11N, R13E, UM P-12B Number 2S100302630-277 At total depth 9. Approximate spud date 2191' NSL, 970' EWL, SEC. 32, T11 N, R13E, UM 09/07/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028289, 2191' MDI No Close Approach 2560 11794' MD / 8933' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10244' Maximum Hole Angle 95 ° Maximum surface 2294 ps, g, At total depth (TVD) 8800' / 3350 psig 18. Casing Program "- Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casina Weiaht Grade CouplinR LenRth MD TVD MD TVD (include stere data) 3" 2-3/8" 4.6# L-80 FL4S 1494' 10300' 8928' 11794' 8933' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. ' Present well condition summary ' ~, r: .~'~ Total depth: measured 10303 feet Plugs (measured) true vertical 9016 feet Effective depth: measured 10303 feet Junk (measured) -~.~'~ ': ~'~ ''= ;,..-:~-..r, true vertical 9016 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset 110' 110' Surface 2696' 10-3/4" 3392 cuft Permafrost 2696' 2696' Intermediate 7012' 7-5/8" 1474 cuft Class 'G' 7012' 6891' Production Liner 2511' 5-1/2" 155 sx Class 'G' 6864' - 9375' 6756' - 9004' Liner 1134' 3-1/2" Uncemented Slotted Liner 9289' - 10303' 8993' - 9016' Perforation depth: measured9360'-9674', ORIGINAL true vertical 9003' - 9006', 9007' - 9011', 9012' - 9016' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas acca~-"~o....~.~ ~ ~'~ Title CT Drilling Engineer Date Permit Number APl Number AoDroval,Date See cover letter -- / 50l 029-22138102 ! I/D 3 for other requirements Conditions of Approval: Samples Required [] Yes l No Mud Log'Requ red [] Yes No Hydrogen Sulfide Measures ]~Yes [] No Directional Survey Required l~IYes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] IOK [] 15K I~3.5K psi for CTU Other: ORIGINAL $1~NED BY by order of _Approved By ,-, -,-_..,_. ¢, ....... _,. Commissioner the commission Date IZ, lJ I [IIUl Form 10-401 Rev. 12-01-85 n Triplicate BPX P-12b Sidetrack Summary of Operations: P-12a is currently on production. The P-12b sidetrack will be an extension of the existing horizontal wellbore to capture primary, EOR and Waterflood reserves in Zone 4b not accessible by the current wellbore. This sidetrack will be conducted in two phases. Phase 1: Drift & Mill out guide shoe: Planned for Sept 2, 2000. · Service coil will drift the horizontal section of the well to pbtd. · Service coil will mill the existing guide shoe at the toe of the wellbore with the KOP at approx. 10244'md (8930'tvdss). Phase 2: Drill and Complete sidetrack: Planned for Sept 7, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. The sidetrack will be completed with a slotted 2 3/8" liner that will extend from the existing 3 Y2" slotted liner. The top of 2 3/8" slotted liner planned to be approx. 10,370' MD. There will be no cement used in the completion and the existing 3 ~" slotted liner will remain open. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 3/8", L-80, Slotted liner will be run from TD to approx. 10,300' MD. There will be no cement in the completion. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A memory resistivity log will be run once td is reached. Hazards Minor lost circulation is expected, two prognosed faults will be crossed. Max. recorded H2S on P Pad in the last year is 70 ppm. The last H2S reading on P-12 was 10ppm on Aug. 5, 2000 Reservoir Pressure Res. pressure is estimated to be 3350 psi at 8800ss (based on offset pressures). Maximum surface pressure with gas (0.12 psi/ft) to surface is 2294 psi. P-12a Potential Drilling Hazards Post on Rig 1. H2S is not expected on this well. The last H2S reading on P-12 was 10ppm on Aug. 5, 2000. Maximum recorded H2S on P Pad this year is 70 ppm. 2. BHP is expected to be 3350psi@ 8800' tvdss 3. Maximum anticipated well head pressure w/full column of gas 2294psi. 4. Minor lost circulation is expected. Two prognosed faults are anticipated in the planned polygon, with a geologic risk termed "low to medium". 5. Critical to stay at least 15' above the HOT to avoid premature water influx -'E: 4" CIW FMC OTIS 10 3/4", 45.5#/ft, L-80 BTRS CMT'd SSSV LANDING: I ] 'HES "HXO" 3.81 2,198' 7 5/8", 29.7#/ft, NT-95HS, NSCC 2n } 47a X ANGLE: 91a @ 9532'~ IAngle at TD: 90~. 1/2", 12.6#/ft, L-80, TDS TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT Top of TIW Tie Back Sleeve ~ 6,860' 75/8" x 5 1/2" LINER PKR. 7 5/8", 29.7#/ft. NT-95HS, NSCC Section Cut 7012'-7061' PI; INTERVAL OPEN/SQZ'D 9316-9336 4 spf 90 degree 9268-9280 4 spf 90 degree 9336-9350 6 spf 60 degree 9280-9304 6 spf 60 degree 9242-9268 6 spf 60 degree SLOTTED LINER 10jts. 31/2" Slotted Liner 9,360' - 9674' CTC 31/2" x 4.30" ESP 9,683' - 9,706' 10 jts. 31/2" Slotted Liner 9,710'- 10,023' CTC 31/2" X 4.30" ESP 10,032' - 10,055' 7 jts. 31/2" Slotted Liner 10,060'- 10,281' 3 1/2" TIW Centralizer Guide Shoe DATE 4-11-95 11/19/95 2-28-98 REV. BY MIJ MDO PJC DDW ( Meda w/1" BK-5 LATCH) 3,006' 4,974' 6,286' 6,727' 41/2" HES X-Nipple 3.813" ID 6,805' BAKER" KBH-22" Anchor I 7 5/8" BAKER" SABL-3 PKR. 6,816' 41/2" HES X-Nipple 3.813" ID I 6,841' 41/2" HES XN-Nipple 3.725" ID I 6,852' 41/2" WLEG I 6,864' ELMD I 6,872' Open 11/19/95 Open 11/19/95 Open 2/27/98 Open 2/27/98 Open 2/27/98 PBTD I 10.30-~' I I COMMENTS SIDETRACK / COMPLETION ELMD,Perfs Add Perfs 51/2" x 31/2" TIW Horizontal [ 9,289' PKR. I ELMD 9295' 51/2" 17# L-80 NSCC I 9,375' Shoe PRUDHOE BAY UNIT WELL: P-12a (43-31-11-13) APl NO: 50-029-22136 SEC 31; T11N; RG13E BP EXPLORATION TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS ,, ( ,12b Proposed Completion ( KB. ELEV = 86.59' BF. ELEV = 55.49' 10 3/4", 45.5#/ft, L-80 BTRS 12696'1 CMT'd SSSV LANDING NIPPLE I ( HES "HXO" 3.813" ID) 2,198' ( Merla w/1" BK-5 LATCH) 7 5/8", 29.7#/ft, NT-95HS, NSCC 1st. KOP: 5000' 2nd KOP: 9140' @ 47-o MAX ANGLE: 91-o @ 9532' Angle at TD · 90-o. 3,006' 3,006' 4,974' 4,974' 6,286' 6,231' 6,727' 6,631' 4 1/2", 12.6#/ft, L-80, TDS TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT Top of TIW Tie Back Sleeve I 6,860' 75/8" x 5 1/2" LINER PKR. 7 5/8", 29.7#/ft. NT-95HS, NSCC Section Cut PERFORATION SUMMARY INTERVAL OPEN/SQZ'D 9316-9336 4 spf 90 degree Open 11/19/95 9268-9280 4 spf 90 degree Open 11/19/95 9336-9350 6 spf 60 degree Open 2/27/98 9280-9304 6 spf 60 degree Open 2/27/98 9242-9268 6 spf 60 degree Open 2/27/98 SLOTTED LINER 10 jts. 31/2" Slotted Liner 9,360'- 9674' CTC 31/2" x 4.30" ESP 9,683'- 9,706' 10 jts. 31/2" Slotted Liner 9,710' - 10,023' CTC 31/2" X 4.30" ESP 10,032' - 10,055' 7 jts. 31/2" Slotted Liner 10,060' - 10,281' 41/2" HES X-Nipple 3.813" ID BAKER" KBH-22" Anchor I 7 5/8" BAKER" SABL-3 PKR. 41/2" HES X-Nipple 3.813" ID I 41/2" HES XN-Nipple 3.725" ID I 41/2" WLEG I ELMD I 6,805' 6~816' I 6~841' J 6~852' I 6~864' I 6,872' J H/2" x 31/2" TIW Horizontal PKR. ELMD 51/2" 17# L-80 NSCC Shoe 9,289' 9295' 9,375' 10,303'I : 10~303' PBTD 3 1/2" TIW Centralizer Guide Shoe ~-~2 3/8" Slotted Liner P-12A Vertical Section 8750 8800 8850 8900 8950 - 8,935 Path Distance (Feet) 1,000 1,500 2,000 I I I P-12b Case 103b Toe drill-out. 3 1/2" slotted liner in original well. Will complete P-12b with slotted liner. Angle @ K.O.= 90 deg MD:10244 2,500 3,000 Tot Drld: 1550 ft 11794 TD Marker Depths ~Orig Wellbore TSA I 8,77SIff'TVD Ts,u I 8,9771 8,9?71fl-TVD TSAD J 8,891Jfl TVD IKick Off I 8,9291ft TVD i o,:up, lff MD IDeprlr eKO 2,298 ff I MD KO Pt lo,244I MD New Hole 1~I I Total MD 11,794I TVD TD 8,933J DLS deg/100 Tool Face Length Curve 1 1 89 Curve 2 8 103 265 Curve 3 8 -90 259 Curve 4 8 90 159 Curve 5 8 -90 209 Curve 6 8 0 i 10 Curve 7 8 -90 180 Curve 8 8 90 279 1,550 Drawn: 3/24/2000 9:11 Plan Name: Case 103b 1,000 500 E -500 1,000 P-12A P-12b Case 103b Toe drill-out. 3 1/2" slotted liner in original well. Will complete P-12b with slotted liner. 1,500 2,000 2,500 3,000 3,500 4,1:]00 4,500 X distance from Sfc Loc IWell Name P-12A I CLOSURE IDistance 3,801 ft Az 94 de~l ~IEW HOLE E~/V (X) N/S (Y) Kick Off 2,282 -50 TD 3,792 -266 State Plane 635,265 5,946,990 Surface Loc 631,473 5,947,256 DLS deg/lO0 Tool Face Length Curve ! 1 0 89 Curve 2 8 103 265 Curve 3 8 -90 259 Curve 4 8 90 159 Curve 5 8 -90 209 Curve 6 8 0 I ! 0 Curve 7 8 -90 180 Curve 8 8 90 279 1,550 Drawn: 3/24/2000 9:11 Plan Name: Case 103b (' C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol injection ~ I'-- 7' Riser I I nnect ' I I I I I ~}..~ Annular BOP {Hydril},7-1/16' ID 5,000 psi working pressure Alignment Guide Flange .. .t, ,~~5') ! ~ ~ Cutters or 7-1/16',_5M Ram Type Dual ~ ~ ! ~ ! F=I ' Combination Cutter/Blinds Gate BOPE . '____J ~ I _ . _. Ranged Fire Resistant Man~~l~e ,[~ ~ SIip/~',perams Kelly Hose to Dual HCR Choke Manifold Manual Valves Drilling spool 7-1/16", 5M ~ by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic ~" 7-1/16" ID witli Pipe/Slip Rams Manual Master Valve · 0.458' (5.5') 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus ' 13-3/8" Annulus J DATE / CHECK NO. 'oo I I ~po1.7257o VENDOR i~t'l z SK ,ASTAT. 10 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~10~00 ,~KO~IO~OON !00. O0 100. O0 HANDLII40 INST: TERR CE X4&28 ! ,., lie ATTACHED CHECK IS IN PAWiENT FO. ITEm DESCRIBED ABOVE. ~ ~, 00. O0 100. 00' "' ;i, ? ii 5 ?O,' '.'O ~, t, ;~O :t,ci q 5': OOP, [, t, 1, ~,' .... WELL PERMIT CHECKLIST FIELD & POOL COMPANY WELL NAME ,; Z..~' PROGRAM: exp ADMINISTRATION 1. 2. . 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....... Lease number appropriate.'~. ~.' ~ ~,~~,~i ;/0.' .-.',:/~"~ ! Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be appr6ved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for'G, T, ~ 'per.[herr, eM,, ...... 20. Adequate tankage or reserve pit ................. 21. Ifa re-drill, has a 10-403 for abandonment been approved...' 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... dev ~ redrll "' 4/ serv wellbore seg ann. disposal para req GEOL AREA ~ ~;)~_~ UNIT# ~)//'~,~-~.~ ON/OFF SHORE N ~N N 24. ' 25. AP.~R DATE 26. . ._~..~ ~/.3,% 27. 28. 29. ~G~ ' 30. 31. 32. APP. R DAT~ 33. ~ ~,~4.~,~ 34. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Drilling fluid program schematic & equip list adequate ..... (~ N . ' BOPEs, do they meet regulation ................ ~ N ' , . ' BOPE press rating appropriate; test to ~,.~t,~ Dsig. Choke manifold complies w/APl RP-53 (May 84) ........ ~.~ N -- · ' Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Permit can be issued wlo hydrogen sulfide measures ..... Y~_ ~Da!a p. resen!ed, on.po, te.n.t,al overpressure zones ....... . ~e~sm~c ana~ys~s o~ sna.ow gas zones.' ......... ' .... IA ~' Y N (I Seabed condition survey (if off-shore) ....... ' .... .~/./~//"~ Y N · Contact name/phone for weekly progress reports [expl.~tory only] Y N ' Y N Y N Y N GEOL~ ENGINEERING: UlC/Annular COMMISSION: CO .~..~%.~,__ Commentsllnstrucfions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process 'but is part of the history file. .. T° improve the readability of the Well History file and to simplify finding information, information'of this. nature' is accumulated at the end of the 'file under APPEN. DIX~ .. No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 01/06/12 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 06/12/21 80655 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.FT 10300.0000: Starting Depth STOP.FT 11808.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Alaska WELL. WELL: P-12B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 2525 FSL, 2190' FWL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 27-Sep-00 API. API NYUMBER: 500292132602 ~Parameter Information Block $MNEM.UNIT Value Description SECT. 31 : Section TOWN.N liN : Township RANG. 13E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 86.59 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 86.59 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OSl . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well P-12B was drilled to TD @ 11812' MD (8945' SSTVD) on Run 6. Final Tie-in adjusts TD to 11821' MD (8945' SSTVD). (5) Well P-112B was kicked off @ 10332' MD (8929' SSTVD) on Run 3. (6) The interval from 11780' MD (8945' SSTVD) to 11821" MD (8945' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX(PDS 27-Sep-00) (8) A Magnetic Declination correction of 26.70 degrees has been applied to the Directional Surveys. MNEMONICS: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR 10300.0000 55. 10300.5000 56. 10400.0000 24. 10500.0000 47 10600.0000 21 10700.0000 24 10800,0000 22 10900.0000 22 11000.0000 25 11100.0000 38 11200.0000 22. 11300.0000 23. 11400.0000 22. 11500.0000 32. 11600.0000 24. 11700.0000 28. 11800.0000 -999. 11808.0000 -999. ROP 4457 -999.2500 6004 -999.2500 7397 143.0888 9814 97.2751 4450 112.8781 0586 97.7025 1570 153.7350 5907 94,2075 5628 112.0427 8995 134.0357 4316 148.0725 2986 121.9607 2922 78.7927 9779 99.6745 2541 87.8797 2976 29.1958 2500 28.2367 2500 -999.2500 Tape File Start Depth = 10300.000000 Tape File End Depth = 11808.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 10300.0000 10300 5000 10400 0000 10500 0000 10600 0000 10700 0000 10800 0000 10900 0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11808.0000 GRAX 59 60 23 29 21 20 27 21 50 30 22 21 38 46. 26. 22. -999. -999. ROPS 4610 -999.2500 8030 -999.2500 6620 127.5030 4290 130,3100 2120 124.8430 2110 150.0960 7270 107,9150 6950 98.2200 2380 129.8570 1220 78.6130 9630 103.8000 9040 126.2830 0790 83.9980 0650 58.8850 7890 105.7470 6700 22.6870 2500 51.6270 2500 26.4670 Tape File Start Depth = 10300.000000 Tape File End Depth = 11808.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Alaska P-12B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!]!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a PDS Ga~a Ray log dated 27-Sep-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAXl2 0.0 2 ROP ROPSl2 0.0 * FORMAT RECORD (TYPE$ 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Total Data Records: 36 Size 4 4 Length 4 4 8 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: 10300.000000 11808.000000 0.500000 feet 45 records... 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Alaska WN P-12B FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !l!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 ROPS 0.0 2 ROPS * FORMAT RECORD (TYPE% 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 i API 2 ROPS MWD 68 i F/HR Size 4 4 Total Data Records: 36 Tape File Start Depth = 10300.000000 Tape File End Depth = 11808.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Length 4 4 8 **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 06/12/21 80655 01 45 records... 54 bytes 4124 bytes **** REEL TRAILER **** MWD 01/06/12 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 10300.0000 55.4457 -999.2500 10300.5000 56.6004 -999.2500 10400.0000 24.7397 143.0888 10500.0000 47.9814 97.2751 10600.0000 21.4450 112.8781 10700.0000 24.0586 97.7025 10800.0000 22.1570 153.7350 10900.0000 22.5907 94.2075 11000.0000 25.5628 112.0427 11100.0000 38.8995 134.0357 11200.0000 22.4316 148.0725 11300.0000 23.2986 121.9607 11400.0000 22.2922 78.7927 11500,0000 32,9779 99.6745 11600.0000 24,2541 87.8797 11700.0000 28.2976 29,1958 11800.0000 -999.2500 28.2367 11808.0000 -999.2500 -999.2500 Tape File Start Depth = 10300.000000 Tape File End Depth = 11808.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 10300.0000 59.4610 -999.2500 10300.5000 60.8030 -999.2500 10400,0000 23.6620 127.5030 10500.0000 29.4290 130.3100 10600.0000 21.2120 124.8430 10700.0000 20.2110 150.0960 10800.0000 27.7270 107.9150 10900.0000 21.6950 98.2200 11000.0000 50.2380 129.8570 11100.0000 30.1220 78.6130 11200.0000 22.9630 103.8000 11300.0000 21.9040 126.2830 11400.0000 38.0790 83.9980 11500.0000 46.0650 58,8850 11600.0000 26.7890 105.7470 11700.0000 22.6700 22.6870 11800.0000 -999.2500 51.6270 11808.0000 -999.2500 26.4670 Tape File Start Depth = 10300.000000 Tape File End Depth = 11808.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS