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202-089
, ) Image p~oject 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. d. Oc;( - O?ll Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 9 CO (Count does include co,:? sheet) Page Count Matches Number in Scanning Preparation: V Y~S , Helen (Maria) Date:l} 7 o~ Organizing (done) o Two-sided 1111111111111111111 RESCAN ¡color Items: o Greyscale Items: DIGITAL DATA ~kettes, No. .;;L D Other, No/Type: o Poor Quality Originals: o Other: NOTES: BY: Helen C Marii) Project Proofing BY: Helen ~ Scanning Preparation BY: Helen ~ ,,=\ x 30 = c~() BY: Stage 1 If NO in stage 1, page(s) discrepancies were found: _ BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~escan Needed OVERSIZED (Scannable) D Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: + o Other:: I L 7 1,~ ~J\J~ Date: -r o~ /5/ f 1· . . 1 , :D Date: ~ t-" e5" Isl m, rf = 1;~~A;- PAGES 17 I<coun~ dyes not ·,clude cover sheet) -A A ().' Date: '1 70s /5/ VVÇ 'I I NO Isl mP YES NO Date: /5/ I III11 I I 1-1111111 Date: /5/ Quality Checked 1111111111111111111 STATE OF ALASKA ALASKA O~ND GAS CONSERVATION COMMIS N RECEIVED Jl1N 4 ~ 210 WELL COMPLETION OR RECOMPLETION REPO 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other Abandoned Suspended 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other 4 ~'~lo. of Completions Zero 1 b. Well Cla~~~~ E ry ®Deve xplorato ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 5/9/2010 Permit to Drill Number: 202-089 310-098 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 01/27/2003 .API Number: 50-029-22282-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 01/31/2003 .Well Name and Number: PBU 15-30A 1703 FNL, 1391 FWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 3731' FSL, 5263' FWL, SEC. 15, T11 N, R14E, UM g. KB (ft above MSL): 64' GL (ft above MSL): 2g.2' 15. Field !Pool s ()~ Prudhoe Bay Field / Prudhoe Bay Total Depth: 4900' FSL, 1320' FWL, SEC. 14, T11N, R14E, UM 9. Plug Back Depth (MD+TVD): 10980' 8531' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 677335 y- 5959810 Zone- ASP4 10. Total Depth (MD+TVO): 13308' 8775' 16. Property Designation: ADL 028306 & 028307 TPI: x- 681068 y- 5965335 Zone- ASP4 Total Depth: x- 682374 Y- 5966536 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, CCL 22. Re-Drill/Lateral Top Window MD/TVD: 11534' 8764' 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" -4 110' 3 ' 11 ' " K-55 / L-80 I ' - /8" 47# NT 0 1 568' 3 ' 29 ' 1 -1/4" 2543 c I 7" 2 NT 1 11534' 11 87 -1/2" 4 7 cu I 'G' 24. Open to production or injection? ^ Yes ®No 25. Tue1NG RECORD If Yes, IISt each Interval Open (MD+TVD of To & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / ND p 4-1/2", 12.6#, L-80 34' MD TVD MD TVD x 3-1/2", 9.3#, 13Cr80 34' - 11534' 11036' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ ~ ~` E (? DEPTH INTERVAL (MD AM OUNT ANO KIND OF MATERIAL USED ~'~ `'~'" "'" ~ ~ ``~ I~~ ~~;U 10980 Set Whipstock ~' 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^ 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 summarise 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 12/2009 CO TINUED ON REVERSE Submit Original Only G •G • to ~~ JUN 0 7 ~ 29. GEOLOGIC MARKERS (List all formations and ma ncountered): 30. NATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 1 B (From 15-30) 11449' 8739' None Zone 1A (From 15-30) 11796' 8784' (Kicked off in Zone 1) Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ 1~ ) h v ~ v Signed: Terrie Hubble Title: Drilling Technologist Date: I PBU 15-30A 202-089 310-098 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Eli VSzquez, 564-5918 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • ~J 15-30A, Well History (Pre Rig Sidetrack) Date Summary 4/17/2010 T/I/0=200/400/150 Temp=Sl Assist S-line (CTD prep) Pumped 37 bbls of 100° crude down TBG to lock out SSSV. Bleed TBG psi down. Final Whp's=100/400/200 4/17/2010 WELL S/1 ON ARRIVAL. TAG /BRUSH SVLN C~ 2082' SLM / 2111' MD W/2' 1 1/2", 2.85" NO-GO CENT, 3 1/2" BRUSH & BN. LOCKED OUT 3 1/2" TRDP-4A SSSV C~ 2082' SLM / 2111' MD. DRIFT TO 11013' SLM W/ 2.80" CENT / 20'x 2.75" DUMMY W HIPSTOCK. TAG ST# 3 C~ 8584' SLM (8615' MD) _ 31' CORRECTION, W/ 1.75" LIB (impression of rk latch). 4/18/2010 DRIFT TO DEPLOYMENT SLEEVE W/ 20'x 2.75" DUMMY WHIPSTOCK C«~ 11035' SLM (+ 32' CORK TO 11067' MD). WELL LEFT S/I ON DEPARTURE. 4/24/2010 T/I/0=0/500/200 Temp= S/I Load and Kill (CTD prep); Pumped 2 bbls 60/40 meth spear, 160 bbls of 120° 1% KCL down TBG to load and kill well. Pumped 22 bbls of 60/40 meth down TBG to freeze protect. FWHP=60/740/800 4/24/2010 T/I/0=140/300/200. Temp=Sl. T & IA FL's. (pre EL). TBG FL C~ 432' (<4 bbl). IA FL C«~ Surface. OA FL C~ Surface. 4/25/2010 WELL SHUT IN ON ARRIVAL. INITIAL T/ I/ 0= 0/ 370/ 200 PSI. RIH W/BAKER WHIPSTOCK; HEAD / SWIVEL / 2X CENTRALIZER / W PMOT / W PTET / W PGRT / W PST /BAKER 10 /BAKER WHIPSTOCK. MAX OD 2.78". LENGTH: 46.5'. 4/26/2010 INITIAL T/ I/ O: 0/ 370/ 200 PSI. SET 3.5" BAKER WHIPSTOCK-PACKER AT 10980' TOP OF WHIPSTOCK. RA TAG 5' BELOW TOP OF TRAY AT 10985'. REFERENCE LOG 05-SEPT-2007 SLB CNL. WHIPSTOCK SET AT 174 DEG RIGHT OF HIGH SIDE. FINAL T/I/O: 0/350/100 PSI. JOB COMPLETED. 4/27/2010 T/I/0=0/300/100 MIT T PASSED to 1000 psi (CTD) Pump 7.7 bbls 60/40 meth down tbg to test MIT T passed 2nd attempt-TP lost 50 psi 1st 15 min, 10 psi 2nd 15 min. FWHP's=0/300/100 4/28/2010 T/I/0= 10/250/70. Temp= SI. Bleed WHPs to 0 psi (rig prep). AL spool disconnected. TBG FL near surface. Bled TP from 10 psi to 0 psi in 1 min (ail gas). IA FL C«~ surface. Bled IAP from 250 psi to 0 psi in 4.5 hrs. OA FL ~ surface. Bled OAP from 70 psi to 0 psi in 15 min. Monitored for 30 min, no change in WHPs. See log for details. Final WHPs= 0/O+Nac. Job Complete. 4/28/2010 T/I/0= 0/220/0 Temo= cool PPPOT-T (PASS) pre CTD PPPOT-T: Stung into test port (0+ psi). Bled to 0 psi, Functioned all LDS all moved freely (1 1/4") torqued to 450 lbs. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. NOTE: LDS measured 3 1/2" IN, and 4 3/4" OUT. 5/3/2010 T/I/O = 50/40/35. Temp=S1. Bleed WHPs to 0 psi (rig prep). AL spool is dropped. IA FL near surface. OA FL ~ surface. Bled IAP from 40 psi to 0 psi in 1 hr. Bled OAP from 35 psi to 0 psi in 25 min. Monitor for 30 min. IAP increased 5 psi. OAP increased 3 psi. Re-bled IAP & OAP to 0 psi in 30 seconds each. Final WHPs=50/0/0. 5/4/2010 T/I/0= 20/0/0 Set 4-1/16" CIW "H" TWC #255 thru tree, 1-2' ext. used, tag C~ 96". Torqued studs to specs (950 ft. lbs.) Pressure tested tree to 4500 PSI, inspected tree flanges, no visible leaks. Pulled CIW TWC pre- Nordic 2, no problems. Page 1 of 1 • North America -ALASKA - BP Page 1'uf~* Operation Summary Report ___ _- __ Common Well Name: 15-30 DIMS p AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/8/2010 End Date: 5/9/2010 X3-OOVNG-C (849,654.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 5/24/2002 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'44.570"0 Long: _ 0148°33'50.290"W Active Datum: 44:30 8/4/1992 00:00 @64.Oft (above Mean Sea Level) Date From - To Hrs Task Code ~ NPT NPT Depth Phase Description of Operations __ _ (hr) (ft) ___ 5/8/2010 00:00 - 03:45 3.75 MOB N PRE RELEASE FORM WELL R-266 AT MIDNIGHT. ~ WAIT ON SECURITY TO RETURN TO RDMO OF R PAD. 03:45 - 04:15 0.50 MOB P f PRE HOLD PJSM. DISCUSS PROCEDURES, HAZARDS, AND MITIGATIONS WITH SECURITY AND CREW REGARDING RIG MOVE FROM R PAD TO DS t5. 04:15 - 14:30 10.25 MOB P PRE ` MOBILIZE RIG AND BEGIN 14 MILE MOVE TO DS 15. 14:30 - 16:00 1.50 MOB P PRE SPOT RIG MATS AND-BEGIN TESTING NEW 5100 INJ. HEAD. _____ ____ 16:00 - 16:15 0.25 MOB P PRE PJSM. DISCUSS PROCEDURES, HAZARDS, AND ~ MITIGATION FOR BACKING RIG OVER WELL. ~ 16:15 - 17:00 0.75 MOB P PRE BACK RIG OVER WELL. ACCEPT RIG AT 17:00 ~ HRS, 17:00 - 17:30 0.50 BOPSUR P PRE PJSM FOR NU BOPE. 17:30 - 18:00 0.50 BOPSUR P PRE NU BOPE. 18:00 - 18:30 0.50 BOPSUR ~ P PRE CREW CHANGE WALK AROUNDS AND PJSM FOR NU BOPE. 18:30 - 23:00 __ 4.50 BOPSUR - _ P PRE CONTINUE TO NU BOPE AND COMPLETE GENERAL RIG UP. STAB INJECTOR ONTO PACKOFF. DOUBLE-CHECKED FLANGE STUDS ON TREE AND ALL WERE TIGHT. PLACED INJECTOR OVER BUNGHOLE. _ _ 23:00 - 23:15 0.25 BOPSUR P PRE PJSM. DISCUSS PROCEDURE, HAZARDS, AND i ~ MITIGATION FOR TESTING BOPE. __ 23:15 - 00:00 ~ 0.75 BOPSUR P PRE TEST BOPE PER AOGCC REGS PERMIT TO DRILL, AND WELL PLAN. TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH. TEST ANNULAR PREVENTER TO 250 PSI LOW AND 2500 PSI HIGH. TEST WITNESS WAIVED BY CHUCK SCHEVE WITH THE AOGCC. CONTINUED ON 15-306 MOB REPORT ~ 05/09/2010. _ ___ 5/9/2010 00:00 - 06:45 6.75 BOPSUR P ~ PRE TEST BOPE PER AOGCC REGS, PERMIT TO DRILL, AND WELL PLAN. TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH. ~i TEST ANNULAR PREVENTER TO 250 PSI LOW AND 2500 PSI HIGH. TEST WITNESS WAIVED BY CHUCK SCHEVE _ ___ _ WITH THE AOGCC. 06:45 - 07:15 0.50 RIGU P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR RIGGING UP - ~ NEW INJECTER HEAD AND TESTING IT. Printed 6/1/2010 1:51:22PM ~1 r1 , North America -ALASKA - BP Page z oF~ Operation Summary Report Common Well Name: 15-30 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/8/2010 End Date: 5/9/2010 X3-OOVNG-C (849,654.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 5/24/2002 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'44.570"0 Long: 0148°33'50.290"W Active Datum: 44:30 8/4/1992 00:00 @64.Oft (above Mean Sea Level) Date -- --- -- ii From - To i ~ 07:15 - 12:30 j Hrs ---(hr) - 5.25 Task RIGU Code I P NPT NPT Depth (ft) --- i Phase PRE ~ Description of Operations - PICKUP INJECTER HEAD. RIG UP HYD HOSE BUNDLE TO NEW 5100 ~ HYDRA-RIG INJECTER HEAD. PULL COIL ACROSS AND STAB COIL AND RE-HEAD TO PULL TEST INJECTOR AND CALIBRATE WEIGHTS WITH COIL IN THE fNJ ECTER. _ ~ SNUB TEST WITH COIL. KICKOUTS WORKED. 12:30 - 13:00 _ 0.50 _____ RIGU P PRE , FILL COIL WITH WATER. __ ~ PRESS°TEST INNER REEL VALVE AND PACKOFF. _ 13:00 - 13:30 j ___ 0.50 RIGU ~ P PRE ~ PUMP SLACK. REVERSE CIRC, 2.7 BPM, 2700 PSI. SURGE TWICE. 13:30 - 13:45 0.25 RIGU P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS'AND MITIGATION FOR CUTTING COIL _ AND BEHEADING. ~ 13:45 - 15:00 1.25 _ RIGU P° PRE CUT'COIL. CUT OFF 200' OF COIL IN 5' LENGTHS. CONTINUED ON REPORT RON 05/09/2010 Printed 611/2010 1:51:22PM • North America -ALASKA - BP Page 1 oi-!;i Operation Summary Report Common Well Name: 15-30 DIMS AFE No Event Type: RE-ENTER- ONSHORE (RON) ~ Start Date: 5/9/2010 End Date: 5/23/2010 X3-OOVNG-C (1,590,056.00 ) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud DatelTime: 5/24/2002 12:0O:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'44.570"0 Long: 0148°33'50.290"W Active Datum: 44:30 8/4/1992 00:00 @64.Oft (above Mean Sea Level) Date From - To Hrs ~ Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _- _-_ 5/9/2010 ~ 15:00 - 16:00 1.00 STWHIP P ( WEXIT CONTINUED FROM MOB 05/09/2010 DAILY REPORT i M/U CTC AND PULL TEST. M/U UOC AND TEST E-LINE. 16:00 - 16:15 0.25 STWHIP P __ WEXIT SAFETY'MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR M/U WINDOW MILLING BHA. 16:15 - 17:30 1.25 STWHIP P WEXIT M/U 2.80" WINDOW MILLING BHA WITH 2.80" ~ DIAMOND WINDOW MILL, REAMER, STRAIGHT MOTOR, CENTRALIZER, 2 JTS CSH AND COICTRAK. ~ BHA OAL = 112.46'. - - - 17:30 - 21:00 3.50 - STWHIP P WEXIT RIH WITH 2:80" WINDOW MILLING BHA #1 PUMPING AT MIN. RATE. TEST INJECTOR WHILE I RIH.' 20:45 - 21:00 0.25 STWHIP P j WEXIT LOG TIE-IN PASS FROM 10,825' TO 10,861'. MAKE+20' CORRECTION. CONTINUE RIH WHILE SWAPPING WELL OVER TO GEO-VIS. 21:00 - 00:00 3.00 STWHIP P WEXIT " ""DRY TAG WHIPSTOCK AT 10975.5' MD. P/U 10' I ( AND RIH. TAG WHIPSTOCK AT 10974.7 WITH ~ PUMPS ON AT 1.60 BPM. BEGIN TIME MILLING ~ i AT 0.1' PER 6 MINUTES. FS: 2600 PSI. MW: 200-300 PSI. DHWOB: 0.7-1.2K# PVT: 253 BBLS. ECD: 10.1 PPG ~ M ILL TO 10975.9' MD. ____ _ _ 5/10/2010 ___ 00:00 - 03:45 ____ 3.75 STWHIP P' WEXIT _ CONTINUE MILLING WINDOW FROM 10975.9' MD. 2600 PSI FS AT 1.58 BPM IN/OUT. 250-350 PSI MW. DHWOB = 1.2-1.6K#. WT. AND PRESS TAKING TIME TO MILL-OFF. MILL TO 10,977' MD. _ __ 03:45 - 06:00 ' 2.25 STWHIP P WEXIT MILL AHEAD FROM 10,977 MD. ~ 2600 PSI FS AT 1.58 BPM IN/OUT. 300-350 PSI MW. DHWOB = 1.5 - 1.75K#. MILLED TO 10978'. - --- .._----- 06:00 - 10:30 ~ 4.50 STWHIP ~ P --- WEXIT ( MILL 2.80" WINDOW. ~ 1.5 BPM, 2600 FS, 200-300 PSI MOTOR WORK. 2-2.5K WOB, 0.3 FPH. MILLED TO 10979'. ~ 10:30 - 12:30 2.00 STWHIP P j __ WEXIT MILL 2.80" WINDOW. 1.5 BPM, 2600 FS, 2800-3000 PSI, 2.8K WOB. ' SLOW MILLING AT 0.2 FPH. PU AND REAM BACK DOWN THRU CLEAN TO BOTTOM. P~ 2 N~ Printed 6/1/2010 1:52:10PM TREE = FMC WELLHEAD=• McEVOY ACTUA.TOF2 = OTIS 70 UH 2202 KB. ELEV BF. ELEV KOP = 1286' Max Angle - 95° @ 12281' Datum M Datum ~ 15-30 DRLG DRAFT 4-1/2" X 3-1/2" XO D = NA 120" CONDUCTOR TV D = 8800' SS 13-3/8" CSG, 68#, K-55 XO TO L-80 BTC TOP OF 7" LNR 10263' TOF OF CEMENT --r 1(}265' 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 11 3838, Minimum ID =1.78" @ 10729" 2-3/8" Liner Plug Holder Bshg 9-5/8" CSG, 47#, L-80 NSCC, ID = 8.681" 10568' 3-1/2" TBG, 9.3#, 13-CR-80, FOX, 11032' .0087 bpf, ID = 2.99" 3.5" BKR KB WHIPSTOCK (04/26/10) 10980' 7" LNR, 26#, NT-80S NSCC, 10980' .0383 bpf, ID = 6.276" I~ 117' 2111, ~~ 3-1/2" CAMCO TRDP-4A-SC SSSV NIP, ID = 2.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3405 3195 40 MMG DMY RK 0 08/29/09 2 6545 5480 44 MMG DMY RK 0 08/29/09 3 8615 6998 45 MMG DMY RK 0 4* 10024 7971 48 MMG DMY RK 5* 10147 8049 53 MMG DMY RK 'BEIiIND GMT SFiEATFi 10713' I~ 3-1 /2" KB LNR TOP PKR, ID = 1.81" I 10719' 2.70" BKR DEPLOY SLV, ID = 1.81" MILLOUT WINDOW (75-30B) 10976' - 10982' PBTD 2-3/8" LNR 4.7#, L-80 STL, .0039 bpf, ID = 1.995" PERFORATION SUMMARY REF LOG: SWS MCNL/CCL/GR ON 06/01/10 ANGLE AT TOP PERF: 90 @ 11820' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 11820 - 12020 Open 06!02/10 1.56" 6 12340 - 12990 Open 06/02/10 1,56" 6 13070 - 13640 Open 06!02/10 1.56" 6 13880 - 14040 Open 06/02110 14 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/06/92 ORIGINAL COMPLETION 09/05/93 LAST WORKOVER 06/07/02 DAC/KK SUSP. CTD SDTRK (15-30A) 02/04/03 DDW/TL CTD SIDETRACK (15-30A) 06/02/10 PJC DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 15-308 PERMIT No: x2020890 API No: 50-029-22282-02 SEC 22, T11 N, R14E, 1703' FNL & 1391' FWL BP Exploration (Alaska) • • ~~Q~[~ OCR Q~Q~~(Q /~.....~..~o....~, John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. 4~:~,r~,~,?~~;,~, ~~?~ `~ ~; ~~~~(! P.O. Box 196612 Anchorage, AK 99519-6612 ~Q Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 15-30A Sundry Number: 310-098 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel . Seamount, Jr. Chair DATED this ~ day of April, 2010. Encl. STATE OF ALASKA ~~~'~'~~ ALASKA•AND GAS CONSERVATION COMMISS• APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECEIVED ~`' ~ 2 2010's4T'/D 1. Type of Request: ~ ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Pro ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Atter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ' ^ Exploratory 202-089 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22282-01-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. WeII Name and Number: property line where ownership or landownership changes: PBU 15-30A . Spacing Exception Required? ^ Yes ®No 9. Property Designation: _ 10. Field /Pool(s): ADL 028306 & 028307 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. 'PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13308' - 8775' - 13274' • 8774' - None None Casin Len th Size MD TVD Burst Colla Structural Conductor 2 11 1 1 Surface 3801' 13-3/8" 38 8' 22' 345 19 0 Intermediate 1 - /8" 1 8299' 870 4760 Production Liner 1271' 7" 1 2 ' - 11 4' 119' - 8764' 7240 10 Liner 2241' 2-3/8" 11067 -1330 ' 8 75' - 8775' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11870' - 13250' 8782' - 8773' 4-1/2", 12.6# x 3-1/2", 9.3# L-80 / 13Cr80 11534' Packers and SSSV Type: 7" x 4-1/2" Baker'SABL-3' packer Packers and SSSV 11036' / 8559' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 11, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG Plugged ^ SPLUG Commission Representative: - ,.5.6/S~~'//I,~ / 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Eli Vaz uez 564-5918 Printed Name o M G e Title Engineering Team Leader p Prepared By Name/Number: Signature ~ L--! Phone 564-4711 Date G~ /. ~~ Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval~N ity Commission so that a representative may witness Sundry Number: l ~'~ ~~ ^ Plug Integrity LMJ BOP Test ^ Mechanical Integrity Test ^ Location Clearance 3soo psi Q ~ P Sf Other: ~ ~~ ~ / ~` 1 r Ann ~~s C._. J ~ Z $O a t c p Subsequent Form Required: ! d • Y Q APPROVED BY ~~ ` Approved By: COMMISSIONER THE COMMfSSION Date Form 10-403 ~tev~~f2/2009 ~PR ~ 4 ~ ~ ~ I Submit In Duplicate ~ G i NA L ®~ y P•!v ~~ y/~~~ • • To: Alaska Oil & Gas Conservation Commission From: Eli Vazquez CTD Engineer Date: March 25th, 2010 Re: 15-30A Sundry Approval Sundry approval is requested to abandon perforations on well 15-30A in preparation for a CTD sidetrack. The well 15-30 was originally drilled and completed in September, 1992. CTD first rigged up to drill the 15-30A sidetrack in June 2002, but did not complete it due to problems during the primary cement job. CTD returned to 15-30 in January 2003 and sidetracked the well placing 1120' of Zone 1 A/1 B perforations inside the horizontal 2- 3/8" liner. The well stayed fulltime until spring 2007 when it attained LP MGOR and. began to cycle. A neutron log from September 2007 showed the GOC to be right at the TZ1 B (8662' TVDss). The well began experiencing erratic production after the CTU MCNL logging. A November 2007 SL drift with sample bailer came back empty. The rates recovered in early 2008 and 15-30A continued cycling with decent on time until early 2009 when the GOR crept up. All attempts to swap it to the HP system have been unsuccessful and there are currently no good wellwork options left to pursue. The present low on time of 20% is only expected to decrease due to 15-30A's lack of ability to flow in the HP system. Utility of well 15-30 will be restored by sidetracking away to maximize standoff from POGC. As part of the CST screening process, the well passed an MITIA to 3000 psi and failed the MITOA to 2000 psi on 8/29/09. The parent well had a liner lap leak / IA squeeze in April 1998 that left 1400' of a cement sheath / collar between 9600' - 11032' MD. A PDS caliper that was logged on 01/08/2010 showed the sheath to be , absent. A Cement Log run on March 23, 2010 showed top of cement behind in 3'/z" tubing x 7" liner at 10,265' MD. The caliper showed the rest of the 4.5" x 3.5" tubing to be in good to poor condition with respect to mechanical damage. The sidetrack, 15-30B, is scheduled to be drilled by Nordic 2 starting on June 1St, 2010. This horizontal lateral will target Ivishak Zone 1 A/1 B. The perforations in the parent well will be abandoned with a 3t/z" monobore packer whipstock placed inside the 3'/i' 13Cr-80 tubing at 10,980' MD. The "B" sidetrack lateral will exit the parent well at 10,980' MD in the Ivishak Zone 2 and drill a -3,120' lateral to a TD of 14,100' MD. The sidetrack will be completed with a solid, cemented and perforated 2-3/8" L-80 production liner. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summary Pre-CT Rig Work: The pre CTD work is planned to begin May 11th. 2010. 1. D MIT-IA to 3000 psi, MIT- OA to 2000 psi. 2. W Check tubing hanger LDS. 3. W PPOT-T to 5000 psi, PPOT-IA to 3500 psi. 4. V PT tree (MV,SV,WV) 5. F Freeze protect well (if not already done) and thoroughly wash the tree. 6. E Drift for 3Yz" monobore packer whipstock. 7. E Set 3'/z" monobore packer whipstock low-side at 10,980' MD. 8. E Test 3Yz" monobore packer whipstock to 1000 psi. 9. D Bleed wellhead pressures down to zero. 10. D Bleed production flow lines and GL lines down to zero and blind flange. 11. O Remove wellhouse, level pad. ~ Cd,c~'' ~~~~~~ ~~ Lv~~ ~/ ~L'~oC6i'lt 1n.l~% 1 h r~r .~u~~ ..sw~~f as a.-r- c~r•'tgf~ ~t'r~~ r< .~,~rcra~ 7~ ~a~ ra~w~ f^ ~/is~C~ ~'~ • Rig Sidetrack Operations: (Scheduled to begin on May 25'h, 2010 using Nordic Rig 2) 1. MIRU Nordic Rig 2 2 NU 7-1/16" CT Drilling BOPE and test 3. Mill 2.74" dual string window in 3'/z" 9.3# 13Cr-80 tubing and 7" 26# liner from mechanical whipstock. 4. Drill build section with 3" bicenter bit, and land well in target Ivishak Zone 1 A sand. 5. Drill lateral section to 14,100' MD. 6. Run and cement a 2-3/8" L-80 production liner string. Place liner top at 10,710' MD. 7. Cement 2-3/8" L-80 production liner. Expect 13.0 bbl of 15.8 ppg cement. 8. Make a cleanout run with mill and motor. 9. Make a MCNL run. 10. Test Liner lap to 2000 psi. 11. Perforate well. 12. Run Liner Top Packer, if needed. 13. Freeze protect well to 2000'. 14. Set BPV. ND 7-1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 15. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. RU test separator. Eli Vazquez CTD Engineer PTA ,2 l0 • ©3 ~ CC: Well File Sondra Stewman/Terrie Hubble I rctt =, rm~, WELLHEA©_ McEVOY _ ACT O = OTIS 70 UH 2202 KB.'ELEV = ~ 64' BF. ELEV = KOP = 1286' Max Angle - 94° @ 11890' Datum MD = NA Datum TV D = 8800' SS 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 13-3/8" CSG, 68#, L-80, ID = 12.415" CTOP OF 7" LNR Top of Gement fir, i"° x 3-'112° annulus 9-5/8" CSG, 47#, L-80, ID = 8.681" Minimum ID =1.92" @ 11072' TOP OF 2-3/8" LINER 3-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.99" ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" WHIPSTOCK RA TAG 3-1/2" TBG, 9.3#, 13-CR-80, .0087 bpf, ID = 2.99" 15 34' -I4-1/2" X 3-1/2" XO 111' 3-1/2" CAMCO TRDP-4A-SC SSSV NIP, ID = 2.812" C;AS I IFf MANDRELS I I 10265' 10568' I 11032' I 11534' 1~ 1539' ~ ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 3405 3195 40 MMG DMY RK 0 08/29/09 2 6544 5480 44 MMG DMY RK 0 08/29/09 3 8615 6998 45 MMG DMY RK 0 4* 10023 7971 48 MMG DMY RK 0 5* 10147 8049 53 MMG DMY RK 0 *BEHINDCMT SHEATH 9600' -TOP OF CEMENT COLLAR, ID = 2.81" 11014' 3-1/2" OTIS XN NIP, MILLED OUT ID = 2.813" 11032' 3-1/2" X 4-1/2" XO 11036' 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.930" I 11043' 4-1/2" X 3-1/2" xo 110110-67~ 3" BKR DEPLOYMENT SLV, ID = 2.250" 11070' -I3-1/2" PKR SWS NIP, ID = 2.813" (BEHIND CT LNR) 11100' TOP OF CEMENT (BEHIND CT LNR) MILLOUT WINDOW TOP @ 11534' OH SDTRCK OFF CMT @ 11610' 7170vvPO,.-.-.~ ~~ 11930' H MARKERJOINT 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ ~ s-~~~ J l 4-1/2" SLTD•SOLID LNR, 12.6#, L-80, ID = 3.958" .,,v.,., PERFORATION SUMMARY REF LOG: SWS CCL/GR ON 02/03/03 ANGLE AT TOP PERF: 92 @ 11870' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 4 11870 - 12200 O 02/05/03 1-9/16" 4 12310 - 12520 O 02!05/03 1-9/16" 4 12670 - 13250 O 02/05/03 ~~ 2-318" LNR, 4.43#, L-80, .0036 bpf, ID = 1.920" DATE REV BY COMMENTS DATE REV BY COMMENTS 09106/92 ORIGINAL COMPLETION 03/10/10 EV CEMEM' TOP 3.5" X 7" LNR 09/05/93 LAST WORKOVER 06/07/02 DAC/KK SUSP. CTD SDTRK (15-30A) 02104/03 DDWITL CTDSIDE~RACK(15-30A) 02/19/03 JB/KAK GLV C/O 09/12/03 CMO/TLP DATUM MD/TV D 8~ PERF ANGL 131 27a I 13308' PRUDHOE BAY UNff WELL: 15-30A PERMff No: `2020890 API No: 50-029-22282-01 SEC 22, T11 N, R14E, 1703' FEL & 1391' FNL BP Exploration (Alaska) jREE _ ,. FMC WELLHEAD= McEVOY ~ ~ ~ _~ O ACTUATOR = OTIS 70 UH 2202 KB~aEV = Proposed CTD Sid BF. ELEV = KOP = 10980 Max Angle = 95° @ 12,119' Datum MD = NA Datum TV D = 8800' SS 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 34' 13-3/8" CSG, 68#, L-80, ID = 12.415" 3838' TOP OF 7" LNR 10263' Top of Cement in 7" x 3-1/2" annulus 10265' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10568' o 3-1 /2" KB LTP, ID = 1.75" 10700' 2.70" BKR LNR DEPLOYMENTSLV, ID= 1.81" 10710' 3-1l2" KB Packer Whipstock 10980' 59° ' Minimum 1D =1.75" ~ 10700' TOP OF 2-3/8" LINER 3-1/2" TBG, 9.3#, 13-CR-80, Fox, 11032' 0.0087 bpf, ID = 2.99" 50~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 34' RA TAG -j 11539, 3-1/2" TBG, 9.3#, 13-CR-80, FOX, 11632' 0.0087 bpf, ID = 2.99" 17" LNR, 26#, NT-80, NSCC, 0.0383 bpf, I 12653' ID = 6.276" 4-1 /2" SLTD-SOLID LNR, 12.6#, L-80, ID = 3.958" 13000' PERFORATION SUMMARY REF LOG: SWS CCUGR ON 02/03/03 ANGLE AT TOP PERF: 92 @ 11870' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE punch 4 11002-11005 S 10/28/97 med 4 11100-11106 S 05/12/02 1-9/16" 4 11870 - 12200 O 02/05/03 1-9/16" 4 12310-12520 O 02/05/03 1-9/16" 4 12670 - 13250 O 02/05/03 ~~ PBTD 2-3/8" LNR, 4.43#, L-80, .0036 bpf, ID = 1.920" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/06/92 ORIGINAL COMPLETION 03/10/10 MSE PROPOSED CTD SIDETRACK 09/05/93 LAST WORKOVER 03/25!10 EV REVISED CTDSIDETRACK 06/07/02 DACIKK SUSP. CTD SDTRK (15-30A) 02/04/03 DDW/TL CTD SIDETRACK (15-30A) 02!19/03 JB/KAK GLV C/O 09/12/03 CMO/TLP DATUM MD/TVD 8~ PERF ANGL ~~ 13274' 1 ~?~~18' PRUDHOE BAY UNIT WELL: 15-30B PERMrr No: API No: 50-029-22282-02 SEC 22, T11N, R14E, 1703' FEL & 1391' FNL BP Exploration (Alaska) 34_ J-' 4-1 /2" X 3-1 /2" XO 2111' 3-1/2" CAMCO TRDP-4A-SC SSSV NIP, ID = 2.812" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 3405 3195 40 MMG DMY RK 0 08/29/09 2 6544 5480 44 MMG DMY RK 0 08/29/09 3 8615 6998 45 MMG DMY RK 0 4* 10023 7971 48 MMG DMY RK 0 5* 10147 8049 53 MMG DMY RK 0 *BEHIND CMT SHEATH TSGR 10480' 2-3l8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" ~-i 14100' i3-1/2" OTIS XN NIP, MILLED OUT ID = 2.813" 11036' ~7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.930" 11067' 3" BKR DEPLOYMENT SLV, ID = 2.250" 11070' -i3-1/2" PKR SWS NIP, ID = 2.813" (BEHIND CT LNR) 11100' TOP OF CEMENT (BEHIND TBG) MILLOUT WINDOW TOP @ 11534' OH SDTRCK OFF CMT @ 11610' l SchCwnb~rg~r 03/25/10 Alaska Data & Consulting Services 2525 Gambell Street, Su0e 400 Anchorage, AK 99503-2939 ATTN: Beth Well Job M Log Description Date BL 03-37 09AKA0188 OH MWD/LWD EDIT - f 02/14/10 2 1 07-238 09AKA0078 OH MWD/LWD EDR 01/10/10 2 1 V-123 04-02 O6.12A X-04 BBKA-00002 614B-00099 AP3O-00081 BBSK-00012 CH EDIT PDC SCMT - INJECTION PROFILE PRODUCTION PROFILE LDL 01/15/10 03/23/10 03/21/10 -03M4/10 1 1 1 y 1 1 1 03-28 B9RH-00017 PRODUCTION LOG - 03/19/10 1 1 14-11 A B3S0-00050 PERF RECORD & FL I G BHP /20/10 1 1 15-316 AP3O-00082 LDL - 03/22/10 1 1 03-10 14-07 03-11 12-26 89RH-00018 B148A0098 89RH-00019 ANHY-00121 INJEC ION PROFILE -d PERF RECORD & FLOWING BHP INJECTION PROFILE PRODUCTION PROFILE - 03/21/10 03/22/10 03/27!10 03/16/10 1 i 1 1 i 1 1 i P2-22 BBSK-00011 USIT CORROSION DATA - 03/11/10 1 1 P2-22 BBSK-00011 USIT CEMENT DATA r 03/11h0 1 1 03-28 B9RH-00017 CBL - j $ 03/19/10 1 1 t5-30A 85JN-00045 SCMT - - - 03/22/10 1 1 MPS-08 BBUO-00009 USIT 03/12/10 1 1 DI FASF ACKIJnWI cnne ner nor nv err_.n. v_ wun ear. ,.,.~..,.. ....~ ......., -..... _.- BP Exploration (Alaska) Inc. Petrotechnical Data Cenier LR2-1 900 E. Benson Rlvd. - NO. 5481 Company: State of Alaska (t ~ f~} ~,~ 'J f~ i) ~~ Alaska Oil & Gas Cons Comm t 1 ~ 1 e/ e_ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~'~{~ gFRn ° ', ... A' Color CD ~ .. ~y Alaska Data & Consulting Services 2525 Gambell Street, SuBe 400 Anchorage, AK 99503-2838 • i BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, ab ~~ og9 is-~aR Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-016 2042570 50029206960200 NA Sealed NA 15-028 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-04B 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11 /7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-258 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31 B 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10!2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-37B 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 1119!2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-458 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 12/19/07 Schlamberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~(~t°, DEC ~~ 2O~f Wnll .InFi i# 1 nn rlncrrin#inn NO. 4525 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Lisburne n~#e GI r•..1..~ rn 15-39A 11661174 MCNL '~ 09/24/07 1 1 14-32 11676961 RST 09/14/07 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOG~p'} ! y 10/06/07 1 03-36A 11745217 CH EDIT PDC GR (USIT) ~ ( U1'~- 05/03/07 1 15-30A 11767139 MCNL - I 09105107 2 1 18-12B 11216204 MCNL > 07/04/06 2 1 E-218 11133205 MCNL -/G~ $ 12/07/05 2 1 P2-56 11686777 RST - ~ 08/08/07 2 1 H-33 11686792 RST !7[ ~ ~ 10/20/07 2 1 06-16 11686797 RST < 11!15/07 2 1 L2-16 11626482 RST 05/10/07 2 1 D-22B 11661167 MCNL Q / ~~j 08126/07 2 1 03-14A 11212846 CH EDIT SDCL GR (USITt ~(%p ~ Q8 a"~ J ( 04/24/06 2 1 MPB-21 PROD 11628749 MCNL (MEM PPROF) tf --~~ ~`~ 4~, 01/15/07 2 1 C-22A 40013486 OH MWD/LWD EDIT (~-Q ~ '~-~ 05!10/06 2 1 E-15C 40013555 OH MWD/LWD EDIT p s (o (~ '~ "~~`(~ 06/03/06 2 1 r'LCHJC Al.n1YVVVLGUl7C KCl.t1Y1 C[ AIVNINU ANU Kt1UFCNINIi VNt IiUYY tAl:tt IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: '; ~ '~ ? "u ' ' I-1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • . . .. . \~':r!:"~' . ~ .'f . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker. doc )'"-- ('1 ~ ^ Õ'-'\j ) ~ DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2020890 Well Name/No. PRUDHOE BAY UNIT 15-30A Operator BP EXPLORATION (ALASKA) INC MD 13308 // TVD 8775 ../' Completion Date 2/5/2003-- Completion Status 1-01l Current Status 1-01l REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, CCl Well Log Information: 5~ù.¿ ;< ì JM"t Àð ~] API No. 50-029-22282-01-00 UIC N (data taken from logs Portion of Master Well Data Maint) log/ Electr Data Digital Dataset Type Med/Fnnt Number Name r: log Gamma Ray M¡) :Bl*~ Gamma Ray ,..-Rpt Directional Survey Bf')t" ~ Gamma Ray ,/' log Gamma Ray t-V ~ Rpt LIS Verification ./ ED C (../11230 Gamma Ray ¡VI. i.;.j 0 ED D Directional Survey ED 0 Directional Survey Rpt Directional Survey Rpt LIS Verification æ6 C 01578 µS,VorifiGclllon M~~ \s ~ / J),'.r ~~ £./ÉD C Tf tA'2150 LlS VCfifi~Jtiun Log Log Run Scale Media No 25 Blu 1 Interval OH/ Start Stop CH Received 11285 13101 Open 1 0/24/2002 11285 12083 Case 3/4/2003 11556 13308 Open 5/15/2003 11285 12083 Case 3/4/2003 11285 13101 Open 1 0/24/2002 11285 13101 Open 1 0/24/2002 11285 13101 Open 1 0/24/2002 11556 13308 Open 5/15/2003 11534 13083 Open 7/23/2002 11534 13083 Open 7/23/2002 11285 12083 Case 3/4/2003 11285 12083 ~ 3/4/2003 10742 13270 10/10/2003 11556 13308 Open 1/9/2004 11556 13308 Open 1/9/2004 11556 13308 Open 1/9/2004 . 11556 13308 Open 1/9/2004 Sample Set Number Comments 25 Blu C{~ C Lis ~~46 Gamma Ray C Pds 2346 Gamma Ray ,- log Gamma Ray ./ Rpt Gamma Ray Blu Well Cores/Samples Infonnation: Name Interval Start Stop Received Sent .~ Comments PB1 PB1 PB1 PB1 lDWG edit of 2-pass Memory Gamma Ray Gamma Ray - MWD Gamma Ray - MWD Gamma Ray - MWD Gamma Ray - MWD --......; Permit to Drill 2020890 MD 13308 TVD 8775 ADDITIONAL INFORMATION Y/~ Chips Received? ~ Well Cored? Analysis Received? ~ .-.--- Comments: ~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Well Name/No. PRUDHOE BAY UNIT 15-30A Operator BP EXPLORATION (ALASKA) INC Completion Date 2/5/2003 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? &/N ~ Formation Tops ~ Date: API No. 50-029-22282-01-00 '-"" ~1 ~~ ;¿.G~ 1 "-- ) ) §C1d- -O('sq Transmittal Form '&1. BAKER HUGHES INTEQ Anchorage GEOScience Center ,- To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 15-30A I I! Contains the following: I :\ I! 1 LDWG Compact Disc 1"3'1 lp (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log "I LAC Job#: 422493 Date: Dec 24, 2003 Dat8ECEIVED JAN 0 9 2004 PLEASE ACKNOWLEDGE RECEIPT BY SIGMI~~~~*","ltM.n OR FAXING YOUR COPY And\ot'a9S FAX: (907) 267-6623 Sent By: Glen Horel Received ~ì\~t.,.~ ~\ Ò't,.>--.£7'~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 [f--:':~:;:~=:=~~~: ,- I- 1n'II.(.; :,eoIoU\~~,,_"__~III_",._,.,,"~_ .,__~',3_., _ _\~(, '..........,... ...........,- .....,.... ~?§ ~ :_..~.";. ....~:'~~~,:,'..:.:.....:~ l:~~~:'~-",:·:- '~;~:S~~, : - ~ .... - ----------- -----.- 09/26/03 SChlumbepger NO. 2976 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 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 Color Date Blueline Prints CD 06/11/03 /" 1 ;J I~~ 08/26/03 1/ .-- 1 09/16/03 1 t/ 1 04/23/03 1 }~I~ 02103/03 1/ 1 01/04/03 -' MPL-01A ~~':.3. -n~Y. 23433 CH EDIT MGR (PDC) D.S. 15-28A .... .3-1 ~ 23431 MCNL K-07C ¡- i~ 10560303 RST-SIGMA C-31 B _ .... 23423 CH EDIT MGR (PDC) D.S. 15-30A ,-()7) 23422 CH EDIT MGR (PDC) . 3-25AJN-24 '"-\ ~ d- SCMT (REPLACES 3-25AJM-27 PRINTS) - 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 ~:. -- ~:.. ;; Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth :-- - --"-- ;........"...... Date Delivered: Received b~ \...N\~\O ø~~ ;.:....-::.::::<::t .._ -......¡Þ-;_--.- .-. ~.- ',_. ~- ~ ~~~(\\~ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Ia Oil 0 Gas 0 Suspended 0 Abandoned 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska I 99519-6612 4. Location of well at surface 1703' SNL, 1391' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 3733' NSL, 5258' EWL, SEC. 15, T11 N, R14E, UM X = 681063, Y = 5965337 At total depth 8~¡Z:J 7~ b9"4~7 10. Well Number 4903' NSL, 1313' EWL, SEC. 14, T11 N, R14E, UM X - (In?~f.7·. ~ - æ6C630 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool RKB = 64' ADL 028307 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/27/2003 1/31/2003 2/5/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13308 8775 FT 13274 8774 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, CCL ~"~I\"'\W~'1i"~II~'t· #.\, i,OC. ^.'~ ¡.()ili'~~. Classification of Service Well ',', YF:lttfJ,!¡!Ð..;!,. 'mo ~..··..I, o .Service,: ' I! ~?'fr:\ ~ '\'.'\"';" 1~O~f\"'''~~' 7. Permit Number l d0 3,_.. (: ~ ~"':';';:":~~"I~~:;;i 202-089 302-182 & 302-383 ~. - \¡,y ~.". '",'!:;\) l~?'"-''''''' (=::~_.,' 9. X = 677335, Y = 5959810 8. API Number 50- 029-22282-01 Unit or Lease Name Prudhoe Bay Unit 15-30A 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2111' MD 1900' (Approx.) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.5# H-40 30' 110' 30" 13-3/8" 68# K-55/ L-80 37' 3838' 16" 2880 cu ft CS III, 1326 cu ft 'G' 9-5/8" 47# NT80S 33' 10568' 12-1/4" 2543 cu ft Class 'G' 7" 26# NT80S 10263' 11534' 8-1/2" 487 cu ft Class 'G' 2-3/8" 4.43# L-80 11067' 13308' 2-3/4" 53 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 1.56" Gun Diameter, 4 spf MD TVD 11870' - 12200' 8782' - 8781' 12310' - 12520' 8778' - 8772' 12670' - 13250' 8774' - 8773' 25. TUBING RECORD SIZE DEPTH SET (MD) 4-1/2",12.6#, L-80 x 11534' 3-1/2", 9.3#, 13Cr80 (Top of Window) 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11534' Set Whipstock 2500' Freeze Protected with 22 Bbls MeOH PACKER SET (MD) 11036' MD TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 28,2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL 3/09/2003 8.1 TEST PERIOD 3,141 Flow Tubing Casing Pressure CALCULATED OIL-BBL Press. 335 24-HoUR RATE ,.28. Brief description of lithology, porosity, fractures, apparent dips a~~;~~~:: of oil, gas or water. Submit core chBE ('C J V· E ~~J<'~/ GAs-McF WATER-BBL CHOKE SIZE 70.85° OIL GRAVITY-API (CORR) GAS-OIL RATIO 94 GAs-McF 296 WATER-BBL -0- RBDMS 8FL j~ f 7 'MAI~ '1 J ~~~ul¡r~ Lth., No core samples were taken. ?nn9 ~~~,~~~(1U::!~~n.-~ t""'-I"F:~ ....,~'"" i, . .,:. "1'!'~~~,, ,. C " ~,!, ~Q;I. ·i.1l\!\}t.I;;J~ ~.~~: l~ ~~ t:t~:@:ti!J:II.l ~~~~~fkbfj~~JI"-~~ jw w;: ., '0'4 ~I'i,~"fi¡ r; r::: Form 10-407 Rev. 07-01-80 Submit In Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 1 B (From 15-30) 11449' 8739' Zone 1A (From 15-30) 117961 8784' {Kicked off in Zone 1) t~ (';i: r~\ J;. ~,.~. )) ·~E·."" 1.!1I I, I. MAf< 1 3 2U03 œ¡GlBGa,aJiDrigton I~ ~. ..' 31. List of Attachments: Summary of Non-Rig Work between sidetrack attempts and Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~J\J\Å.(. ~ Title Technical Assistant Date C\3. Il ~ "Q ~ 15-30A 202-089 302-182 & 302-383 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Alistair Sherwood, 564-4378 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, 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. I":"EM 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 ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5/23/2002 5/24/2002 5/25/2002 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: :'B:tom'~·..'ö:'::I·:·H6ufs,·., ··:;I·IT:åsK:<;··.:.C.Odel."':Þ,lF!i"·.'··'p'a8S@II.)...',·.·:i.:,:::.:·:::.;:I:.i"::;,·:·.···:'.';::.::,m~.$Cfiþtiøn·of.Ðþe.~tiQqs·.:.·...· .'. .. Spud Date: 5/24/2002 End: 6/6/2002 08:00 - 10:45 2.75 MOB P PRE RD on F-04a. Unstab CT. Remove gooseneck. Set injector in pipe bay. Load oout mise loads 10:45 - 11 :30 0.75 MOB P PRE Move rig off tree and to end of pad. Clean up Location. 11 :30 - 15:00 3.50 MOB P PRE Lower windwalls. Load CSH out of pipe shed. Prep floor 15:00 - 16:30 1.50 MOB P PRE Scope down derrick. Lay down derrick 16:30 - 16:45 0.25 MOB P PRE PJSM rig move. Include all parts involved, 16:45 - 23:30 6.75 MOB P PRE Leave location. Move to DS 15. 23:30 - 00:00 0.50 MOB P PRE Arrived to DS-15.. PJSM: Raise derrick 00:00 - 01 :00 1.00 RIGU P PRE Raise and scope derrick. Secure derrick 01 :00 - 02:00 1.00 RIGU P PRE Raise windwalls and secure. 02:00 - 03:00 1.00 RIGU P PRE Retract Tilt Rams. 03:00 - 07:45 4.75 RIGU P PRE RU injector, install gooseneck and stab in coil 07:45 - 08:00 0.25 RIGU P PRE Safety mtg re: move over well 08:00 - 08:30 0.50 RIGU P PRE Move rig over tree and set down 08:30 - 09:30 1.00 BOPSUR P DECOMP Accept rig for operations at 0830 hrs 5/24/02 Remove tree cap. NUBOPE 09:30 - 10:30 1.00 BOPSUR P DECOMP Grease crew service leaking wing/swab. FL had previously been depressured to zero, but pressured back up to 400 psi 10:30 -16:40 6.17 BOPSURP DECOMP Test BOPE. Witness waived by AOGCC 16:40 - 17:40 1.00 BOPSUR P DECOMP PU injector. Kinked CT at levelwind on move. Cut off 80' of CT. 17:40 - 19:00 1.33 BOPSUR P DECOMP Pump slack back (rev) w/ 56 bbls. Cut off 15' to find cable. Cut 10' of col and cable to find dry cable. 19:00 - 22:00 3.00 STWHIP P WEXIT PU. Baker tools. MU cement milling BHA 22:00 - 00:00 2.00 STWHIP P WEXIT RIH/straight motor to drill out approx 100' of cement. 00:00 - 00:15 0.25 CLEAN C WEXIT Up wt 35K#s. wt dwn 12.5k#s. Free spin 2700 psi. Tag cement stringer @11285'. See some motor work. 00:15 - 03:30 3.25 CLEAN C WEXIT Clean out cement from 11285'. 400-500 psi motor work. Tag whipstock @11517'. Had good cement returns. 03:30 - 05:30 2.00 CLEAN C WEXIT POH. EOP @11400'. 05:30 - 06:00 0.50 STWHIP C WEXIT P/U. BHA #2 for window milling. 06:00 - 07:50 1.83 STWHIP P WEXIT RIH w/2.5 Weatherford motor. 07:50 - 08:20 0.50 STWHIP N SFAL WEXIT Corr +11' to flag. Work on BHI PC. 36.5k at 11500' 08:20 - 08:45 0.42 STWHIP P WEXIT RIH w/o pump, tag WS at 11532' CTD PVT 290. PUH 37k, start pump. RIH slow at 1.5/2580 and see motor work at 11530.1'. Corr to 11534' and let it drill off 08:45 - 11: 10 2.42 STWHIP P WEXIT Begin milling by procedure at 11534' 1.5/2160/212 deg 12.5k 11:10-14:10 3.00 STWHIP P WEXIT Flag CT at 11535.5' 1.6/2600/217 10.3k PVT 286. PUH l' and begin time milling by schedule Safety mtg re: emergency resources tied up on C-07 DSM shut down moving flowback tanklhardline for same reason 14:10 - 16:45 2.58 STWHIP P WEXIT Back at flag 1.6/2630/225 10. 7k PVT 286 DSM resume RU flowback tank hardline 16:45 - 18:15 1.50 STWHIP P WEXIT 11537.5' 1.6/3000/197 7.5k PVT 282 18:15 - 18:45 0.50 STWHIP P WEXIT 11538.8' 1.6/3140/200 6.7k PVT 280 18:45 - 19:15 0.50 STWHIP P WEXIT 11539.2 1.6/3144/215 6.7k PVT 280 19:15 - 19:45 0.50 STWHIP P WEXIT 11539.71.6/3190/2107.6k PVT 280 19:45 - 20:15 0.50 STWHIP P WEXIT 11540.1 1.6/3250/220 8.0k PVT 278 20:15 - 21:00 0.75 STWHIP P WEXIT 11540.2' .1.6/32801200 8.0k PVT 277. Power source went down. No computers. 21:00 - 21:15 0.25 STWHIP P WEXIT Got ups back,11540.3.1.6/3320/205 7.6k PVT 278 21 :15 - 21 :45 0.50 STWHIP P WEXIT 11540.71.6/3350/210 7.8k PVT 277 . Printed: 7/18/2002 3:05:15 PM ) ) Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Start: 5/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 6/6/2002 Rig Name: NORDIC 1 Rig Number: ."i,' :t>..··.'.'Ø~~, :,I.I¡"',' I., ;': ,I'; :1:" ,:", ""',',' 'I (,,' ,.;. '1:, I I 1::",,: I, ',\': :11 I. ",',1 ;,".-:1,'::':: :\.: :,'1'; ""' :'I·I,/::"I:::':"::,?r.::,,,: ,;:,,:,,1:> :,1,': :I,I<:,I":,::'>:~'I': 1,1'::;: .1,':::.1<:,"'" \,:'::...':,::1 .':,".:':-,-.1:::,:.\,:,:",: :'~' ':,,:.:1, ¡',::i:':",;'(, :11':;::1:;\ 1"" I' I 'I',; ',,':",':.' "\:':·:",ï::::·I'.~:<::':'::' ':.. ::';':',~""""",,'. ,): I,,' ::,\i',,:. 'I',.", '::' ','':- .':': .:,'::' '\: :",':':.: ',,',:,,1 :',' I,': " :,:,: ::.,';, "..',1",.:,1.,1,. ,": " "::," },' 'I":' 5/25/2002 21:45-22:00 0.25 STWHIP P WEXIT 11541.01.6/3230/2207.0PVT277 22:00 - 22:30 0.50 STWHIP P WEXIT 11542.01.6/3240/210 6.9 PVT 277. Increase on ROP and WOB go down. Drilling formation. 11542.41.6/3248/205 7.6k PVT 275 11545' 1.6/3230/205. 7.5k PVT 274 Drill to 11551'. Pump 2# biozan pill. Got sand over the shakers. POH to p/u crayola mill. P/U dressing BHA RIH w/2.79" crayola mill to 11521' CTD. Attempt to ream and BHA pressured up-assume motor. Open EDC, POOH filling thru CT POOH to check BHA LD BHA. Couldn't turn motor w/ Phil on a '48'. Change out WF motor for BHI. Changeout BHI EDC due to drawing high current. Install backup DS UPS and replumb wiring in ops cab RIH wI BHA#4 Tag at 11520' CTD and corr to 11534'. Dress window 1.6/2620/210 deg PVT 270. A few stalls getting started, then relatively clean to 11535.7' Mill a burr on 7" at 11535.7' with a bunch of stalls to 11536.0' Ease into open hole from 11536' 1.5/2365/225 to another burr at 11541.4'. Clean after that to tagged TD at 11551' Ream window from 170-250 deg in 3 passes, clean. Dry tag POOH for drilling assy OOH. UD milling assy. PJSM on cutting pipe. Cut 100' of coil Re-heading. MU Build assy. RIHw/BHA #5 (2.4 Baker motor and bicenter bit). RIH to 11500'. Tie in. +14' correction. Waiting on mud. Mud on location. Swap well to mud Orient to 21 OL. Drill ahead. 1.5/3520/10R. Drill to 11600' Drill from 11600-630' 1.5/3440/5L 40-50'/hr Enter the shale above the Kavik at 10630' at 80 deg and penetration slowed to avg 10'/hr. Finish the build at 95 deg at 11670' and begin the left turn Stalled at 11700', but then back to more of the same. Drill to 11725' and P rate picked up Wiper to window from 11725'. RIH to TD Slow backream while BHI reboots PC Resume drilling from 11725' 1.5/3460/85L. Drill to 11737' Orient to right side to set up for lateral and drill from 11737' 1.5/3560/85R 5Q-70'/hr in target sand 45 api. Drill to 11770' Wiper to window. Open EDC. POOH for lateral assy OOH. UD build assy. P/U lateral assy. RIH w/1.1 motor. Tie in. Correct +20'. Problems with Baker equipment. Back on bottom drilling. 1.4/3650/150. Drill to 11850'. 22:30 - 23:00 0.50 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 5/26/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 03:30 2.00 STWHIP P WEXIT 03:30 - 04:00 0.50 STWHIP P WEXIT 04:00 - 06:30 2.50 STWHIP P WEXIT 06:30 - 08: 15 1.75 STWHIP N DFAL WEXIT 08: 15 - 09:45 1.50 STWHIP N DFAL WEXIT 09:45 - 12:00 2.25 STWHIP N DFAL WEXIT 12:00 - 13:45 1.75 STWHIP P WEXIT 13:45 - 16:30 2.75 STWHIP P WEXIT 16:30 -17:40 1.17 STWHIP P WEXIT 17:40 - 18:00 0.33 STWHIP P WEXIT 18:00 - 20:00 2.00 STWHIP P WEXIT 20:00 - 20:30 0.50 STWHIP P WEXIT 20:30 - 20:45 0.25 STWHIP P WEXIT 20:45 - 21 :15 0.50 STWHIP P WEXIT 21:15 - 23:30 2.25 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 5/27/2002 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 02:20 0.33 DRILL P PROD1 02:20 - 03:45 1.42 DRILL N WAIT PROD1 03:45 - 04:00 0.25 DRILL P PROD1 04:00 - 06:00 2.00 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:30 1.00 DRILL P PROD1 07:30 - 12:30 5.00 DRILL P PROD1 12:30 -13:50 1.33 DRILL P PROD1 13:50 - 14:05 0.25 DRILL P PROD1 14:05 - 16:00 1.92 DRILL N SFAL PROD1 16:00 - 16:20 0.33 DRILL P PROD1 16:20 - 16:50 0.50 DRILL P PROD1 16:50 - 17:00 0.17 DRILL P PROD1 17:00 - 18:45 1.75 DRILL P PROD1 18:45 - 19:45 1.00 DRILL P PROD1 19:45 - 22:00 2.25 DRILL P PROD1 22:00 - 23:00 1.00 DRILL N SFAL PROD1 23:00 - 00:00 1.00 DRILL P PROD1 Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/18/2002 3:05:15 PM ) ) Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Start: 5/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 6/6/2002 Rig Name: NORDIC 1 Rig Number: I ·':':;i:'I''''';'':''I::':::':,,:,:::<:I:,:,.:.~;,I:,,'I,II.~":':.;(I:; ':;,~:'.,'·':;';':':':""':',",':,i.,I";,,',,'~~:',::",':II::,'",~I ,:':':1:" :,"':':~:"':,,',' ,:: <.:.: ":,:',-.," :";:::,; I ,:,I"I:,,','~r,,:I:.I,:'. ,,:';'p'I',', 1,1, I ::11 I J', ~':'I': I, .,..111','.... ," :,:. ::: -:>~,'.;I:.::,I;;. I..:,:,~I,::,"::\, ("': ,.,.I'i\' ,1":,:" "',- '; "' '.: I':,; I. " ",', ,:'!,~ II:',', !I, ','., I,:,I.;,~,,~, I 5/28/2002 00:00 - 01 :00 1.00 DRILL P Drill ahead. 1.6/3000/ Drill to 11911'. Motor not giving predicted doglegs. Will deviate from plan if continue with this motor. POH to P/U a more agressive motor. OOH. Change motor bend. RIH w/2.0 deg motor. Drill from 11911' 1.6/3700/90-125R. 1:1 returns. Wiper to window from 12062' Log tie-in up from 11570', no corr RIH, begin swap to new mud Drill from 12062' in a shale. Get back into 55 api sand at 12115' 1.5/3430/90R. Drill to 12165' Orient back to left side and drill 1.5/3400/85-11 OL. Get into 35-45 api sand at 12225'. Drill to 12282' Wiper to window from 12282' Drill from 12282' 1.5/3400/95L. Took 45 min to get thru a hard spot at 12313' POOH from 12330' to change motor angle circ thru EDC. Close EDC & tag up @ surface with BHA #7. Check bit - OK. Reset motor to 1.5 degs bend. RIH BHA #8 with 1.5 deg motor & same HCC bicenter bit. RIH to 2000'. Open EDC & continue RIH @0.3bpm & 1200psi to 11550' . Log tie-in with RA marker. Added 18 ft to CTD. Closed circ sub. RIH to TD. Tagged TD at 12,331 ft. Clean hole to TD. Drilling, 1.5/1.5 bpm, 3300-3700 psi, 90 FPH, 2000# WOB, Drilled to 12,500'. Wiper trip to window. Clean Hole. RIH to TD. Drilling, 1.5/1.5 bpm, 3300-3800 psi, Drilled to 12,520 ft. Drilling, 1.5/1.5 bpm, 3300-3800 psi. Drilled to 12,552 ft. BHA not drilling directionally as it should. Appears to be 60 deg off on tool face. POH to check motor and bit. Clean in open hole. POH. Check BHA. Found motor high side to be 56 deg off. SAFETY MEETING. Review CT cutting procedure and hazards. Cut off 100 ft of CT using hydraulic cutter and hydraulic cable cutter. MIU BHI CTC and pull test. Press test eTC. M/U same BHA with 1.5 deg. motor and Bit #5. RIH to 10989' with BHA #9 with 1.5 deg. motor and bi-center Bit #6. Stop to reboot BHI surface computers - system not recording to database. Continue RIH with BHA #9 to 11550'. Log tie-in with RA marker. Added 13.75' to CTD. BHI surface computers acting up again - system crash. Re-install software & re-initialize well. Also prepare spare initializing data for quick re-initializations if bug re-occurs. Continue RIH to 12500'. Log down MAD pass from 12500' @ 210 TF & 150fph to validate BHI computer data. Drill lateral to 12600' @ 140TF, 1.5/1.5bpm, 3300/3550psi, 2k 01 :00 - 03:00 2.00 DRILL P 03:00 - 03:35 0.58 DRILL P 03:35 - 05:30 1.92 DRILL P 05:30 - 08:00 2.50 DRILL P 08:00 - 08: 15 0.25 DRILL P 08: 15 - 08:20 0.08 DRILL P 08:20 - 08:40 0.33 DRILL P 08:40 - 11 :20 2.67 DRILL P 11 :20 - 12:25 1.08 DRILL P 12:25 -13:15 0.83 DRILL P 13:15 -15:05 1.83 DRILL P 15:05 - 17:15 2.17 DRILL P 17:15 -17:45 0.50 DRILL P 17:45 - 19:45 2.00 DRILL P 19:45 - 20:00 0.25 DRILL P 20:00 - 20:30 0.50 DRILL P 20:30 - 22:20 1.83 DRILL P 22:20 - 23:15 0.92 DRILL P 23:15 - 00:00 0.75 DRILL P 5/29/2002 00:00 - 01 :00 1.00 DRILL P 01:00 - 03:10 2.17 DRILL N 03:10 - 03:30 0.33 DRILL N 03:30 - 03:45 0.25 DRILL N 03:45 - 05:45 2.00 DRILL N 05:45 - 07:30 1.75 DRILL N 07:30 - 09:30 2.00 DRILL N 09:30 - 09:40 0.17 DRILL N 09:40 - 09:50 0.17 DRILL N 09:50 - 12:50 3.00 DRILL N 12:50 - 13:25 0.58 DRILL N 13:25 -13:50 0.42 DRILL N 13:50 - 15:45 1.92 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 SFAL PROD1 DPRB PROD1 DPRB PROD1 SFAL PROD1 DPRB PROD1 DPRB PROD1 PROD1 Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/18/2002 3:05:15 PM ) ) Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 ·.··'···.'Q~~e:'· 1;,.:,I,::FtÓ~·i·I*~I.: ·IHÓ~~~\.·..r~~k:.:·.'Cldd~,NP~:.I:::Rt1~~~;,.I'·.',?:.,:i":,·.· ',.1,··.. .' I "., ',':1' .1, : :'1 "I ',. 'I, I I, L ,', ' "" '. ',.I. I ";i', ; I I, 'I; ',I '> I ';)1 I 'I I, "" I" I ,\'1 ~ <' :'1:../':' I "I,' I . ,'" """.':'' [' :I;:!';:-'.', I <':':.;':.~/ ,,\: ,,1',::;)',1 "I I,:::'", ':, \~I: '" <',: 'i: ~':;' ,':":I:i,~,: 1,1,.: :',''-:: ':. I:/~ ~',"'I:::.' PROD1 WOB & 20fph ROP. Hard drilling with occasional wt stacking. Drilling out of shale. Observe +/-8degs azm swings. PROD1 PUH & shoot check shot surveys @ 12482', to 12519' & 12540'. Observe 95.23 degs incl, 48.34degs azm & 46.5degs DLS @ 12547' survey depth. Also pull heavy around hi DLS area. RBIH to btm. PROD1 Drill to 12610' @ 130TF, 1.5/1.5bpm, 3300/3500psi & 6k WOB. Serious wt stacking. Can't get any wt to bit to drill. Work pipe - no progress. Prepare & pump down 30bbls 4.5% lubetex pill. PROD1 Drilling, Pill out of bit. TF = 120R, 1.5 /1.5 bpm, 3360-3800 psi, Circ. second lubetex 30 bbl pill around for better wt transfer while drilling shale. Slow drilling, 20% Pyrite in geo sample at this depth. 3% lubetex in system now. Drilled to 12,626 ft. Drilling, TF = 120R, 1.5/1.5 bpm, 3400 - 3900 psi, Incl = 88 deg. Drilled to 12,713', Wiper trip to window. Hole was clean. Log tie-in with RA tag. Open circ sub and log down. Added 7 ft to CTD. Rig generator #1 motor intake valves failed. Valves stuck and twisted. Pistons damaged. Engine rebuild required. Spare engine/generator in conex at Price pad. Will install spare engine/generator. POH. Expect to be shut down for approx. 12 - 18 hours. POH while waiting on rig generator / engine #1 replacement. Haul spare eng/gen from Price pad to location for swap. LlO MWD BHA. Shut in well at swab valve. SIWHP = 0 psi. BHI on standby at 03:30 hrs. Spare eng / gen on location, Pull gen #1 radiator off and pull eng/gen off rig. Install spare generator & engine onto rig. Rig off downtime. PJSM. Grease tree valves & carried out weekly testing of BOPE to 3500psi as per drilling permit. Witnessing of test waived by State Rep John Crisp. Pffested inner reel valve to 3500psi. Meanwhile continue hooking-up rig gen set accessories. Rig back on downtime. Continue hooking-up rig gen set accessories - cable wiring, etc. Test Gen set #1. OK. Safety meeting. Review procedure and hazards for BHA make-up. M/U Coiltrak BHA #10. 1.5 deg motor and HC 3.0" bi-center bit #7. MlU Coiltrak BHA #10 with 1.50 deg motor and 3.0" HC Bi-center Bit # RIH. Shallow test Coiltrak, OK. RIH to 11500 ft. Wait for BHI surface computer problems. Re-boot computers, unable to display any information to ops cab or geology monitors. Fixed problem. Log Tie-in with RA tag at 11 ,540'. Added 13 ft to CTD. RIH & set down @ 11700' (shale). P/U & fall thru. Set down @ 12562' (shale). Ream thru shale from 12525' @ original TF. Precautionary ream to TD (tagged - 12723') @ 1.5/1.5, 3400psi, 300bbls PVT. 5/29/2002 13:50 - 15:45 1.92 DRILL P 15:45 - 16:40 0.92 DRILL P 16:40 - 18:30 1.83 DRILL P 18:30 - 21 :00 2.50 DRILL P 21 :00 - 22:45 1.75 DRILL P PROD1 22:45 - 23:20 0.58 DRILL P PROD1 23:20 - 23:45 0.42 DRILL P PROD1 23:45 - 00:00 0.25 DRILL N RREP PROD1 5/30/2002 00:00 - 03:00 3.00 DRILL N RREP PROD1 03:00 - 03:30 0.50 DRILL N RREP PROD1 03:30 - 07:30 4.00 DRILL N RREP PROD1 07:30 - 11 :00 3.50 DRILL N RREP PROD1 11 :00 - 17:00 6.00 DRILL P PROD1 17:00 - 23:30 6.50 DRILL N RREP PROD1 23:30 - 23:45 0.25 DRILL N RREP PROD1 23:45 - 00:00 0.25 DRILL N RREP PROD1 5/31/2002 00:00 - 00:15 0.25 DRILL N RREP PROD1 00:15 - 02:15 2.00 DRILL N RREP PROD1 02:15 - 05:45 3.50 DRILL N SFAL PROD1 05:45 - 06:00 0.25 DRILL P PROD1 06:00 - 06:50 0.83 DRILL P PROD1 Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: Spud Date: 5/24/2002 End: 6/6/2002 I I I, : ' " " L ,~ I 1 I ' 'r:' ,,, : ,:,_ :,"":,"',','~.~ :, ",::,,1.':\.", ,'>:,I:',,:~, ':,.'>.', :::":" ':::" ,'::.'" '::'.',' :,;' ":''- .1, ,I ,',,:'::, "', '; ;':',,:, ,:.'..",:",,<, ': ,",' , ,'I'!, :/, ,.,,', ·,.,,:II,,·D~sch~t¡OnQfØÞeratiPq".' . . ',,; : ·t. ",',1", ,:',I\'!:'::!:,:,::,,:,.:\':·,"~':::':: ::""'11 : ':,' ,:,',. ',' ',:.:,:,<' :'::,', "r': ::', :', "; ::,:'"" :':' ,:' :., ,1\: "",.(,,:,:,:.::,1:,: '.' ",",,', ': Printed: 7/1812002 3:05:15 PM } ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . '! .'. '"i ..... ..'. . ....,~ ,.' ..' .::', > "'" " ...... .......... . .. .... I .. .<. ",!. ;I;i~ ·Qatê'~' 1·,..i::~'fP,·...·rnl ~'~p:. Hours.:·.. · Task,., ".:':",":,', ':' ''''', :";,':",,' ";,:',1,'"",·:1,,;,'1' I·:"·" .",:",:,:":,:,,,,:,',1',1":'1":-': 1.,1::: :,..',,:'1,1 '\<':';" I,"'" :',,1.:",:.,:, "': "', ::'"",,' 15-30 15-30A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 5/31/2002 06:50 ~ 07:10 07:10 ~ 07:30 07:30 ~ 07:45 07:45 ~ 09: 15 0.33 DRill 0.33 DRill 0.25 DRill 1.50 DRill 09: 15 - 09:45 0.50 DRill 09:45 - 10:20 0.58 DRill 10:20 - 11 :00 0.67 DRill 11 :00 ~ 12:35 1.58 DRill 12:35 ~ 13:50 1.25 DRill 13:50 ~ 14:30 14:30 ~ 15:45 15:45 ~ 16:40 16:40 - 17:30 17:30 - 17:45 17:45 ~ 18:45 18:45 ~ 22:00 22:00 ~ 00:00 6/1/2002 00:00 - 03:00 03:00 ~ 03:45 03:45 - 04:00 04:00 - 05:00 05:00 - 05:30 0.67 DRIll 1.25 DRill 0.92 DRill 0.83 DRill 0.25 DRill 1.00 DRill 3.25 DRill 2.00 DRill 3.00 DRill 0.75 DRIll 0.25 DRIll 1.00 DRill 0.50 DRIll Spud Date: 5/24/2002 End: 6/6/2002 Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: . I' III I I" . ·~Òde.: ~~T,,· - . Pna~~ I, ·1' I ',". ,....,:...... :·;....·.·:'·.i;.;,t)ij,$criptiþ.n'9t·ØÄ~råtiqn$; , I I 'I I I I ,I',' I 'p I I'" " ":,1.', ' :.' ,>": :i~,;',:':.i::: "1':.:.'':"0,::,; I,I" :,:":' ':","""'.;: I." :':' ;:, ~:, .:" ':'.,,' ,,' ,:', " '.:'" >': II' " I, I'I' :',. P PROD1 Resume drilling from 12723' to 12740' @ 15TF, 1.5/1.5bpm, 3400/3800psi, 2k WOB, 15fph aye ROP & 300bbls PVT. PROD1 Drill to 12759' @ 90TF, 1.5/1.5bpm, 3350/3800psi, 2k WOB, & 100fph aye ROP. P/U & pull heavy. STUC PROD1 Differentially stuck. P/U & SID pumps for 15m ins. Pull free with 56k (30k O/P). P/U & ream drilled section. PROD1 Continue drilling to 12795' @ 110TF, 1.5/1.5bpm, 3450/3950psi, 2k WOB, 25fph aye ROP & 282bbls PVT. Drilled thru shale from 12770' ~ 12793'. PROD1 Drill to 12840' @ 260TF, 1.5/1.5bpm, 3400/3900psi, 2k WOB, & 90fph aye ROP. PROD1 Drill to 12868' @ 300TF, 1.5/1.5bpm, 3400/3900psi, 2k WOB, & 48fph aye ROP. PROD1 Wiper to window. RBIH & set down several times in shale from 11630 to 11700'. Backream thru section & continue RIH to bottom. Meanwhile held fire drill. PROD1 Drill to 12887' @ 260TF, 1.5/1.5bpm, 3500/3800psi, 2k WOB, & 12fph aye ROP. Seeing some pyrite in geo samples. PROD1 Drill to 12925' @ 290TF, 1.5/1.5bpm, 3500/3700psi, 2k WOB, & 30fph aye ROP. Drilled shale from 12875' ~ 12895' - may be drilling thru Zone~1A11 B interface shale. Geo decides to mantain 91 degs incl. PROD1 Drill to 12959' @ 260TF, 1.5/1.5bpm, 3500/4050psi, 2k WOB, & 51fph aye ROP. Wt stacking. PROD1 Short wiper trip to 12500'. RBIH & set down @ 12596'. P/U & RBIH. Still stacking wt. Drill solids in mud up to 0.7%. Prepare & pump down 30bbls 4.5% lubetex pill. PROD1 Pill out of bit. Take off & drill to 12991' @ 260TF, 1.5/1.5bpm, 3500/4050psi, 2k WOB, & 30fph aye ROP. Serious wt stacking. Call for fresh SFFP mud. Work pipe & take off drilling again to 13023'. PROD1 Wiper to window. PROD1 Open EDC. log tie~in with RA tag. Added 13' to CTD. Close EDC. PROD1 RBIH to btm. Clean trip to bottom. PROD1 Drilling, Stacking wt, good wt [+9K] just off bottom, but unable to get enough WOB to drill ahead. max WOB = 700 Ibs. Ream hole while waiting for new FloPro. Drilling with new flopro. TF = 115R, 1.5/ 1.5 bpm, 2700 ~ 3200 psi, Drilled to 13067' PROD1 Drilling, TF = 120R, 1.5/1.5 bpm, 2700 ~ 3300 psi, Drilled to 13081 ft. PROD1 Drilling, TF = 165R, 1.6 / 1.6 bpm, 3000-3400 psi, Slow drilling, chert and pyrite in geo sample from this depth. Drilled to 13083 ft. Unable to drill any further, max wt on bit possible was 1700 Ibs, no ROP with this WOB. PROD1 Wiper trip to window. Hole clean. PROD1 logged tie~in with RA marker. Added 2 ft to CTD. PROD1 RIH to TD. Sat down at 12700, 12818 ft. RIH clean to TD of 13,083 ft. PROD1 Drilling, zero ROP with 1400# WOB. Unable to drill any further. Call TD at 13,083 ft. P N P P P P P P P P P P P P P P P P P P P Printed: 7/1812002 3:05:15 PM ,) ') 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: ;i,~:'I:, ,'" ;II,:~'~", '-:\'';,'1.':,:> ,I,:· / :,:,'1 ,'I'., "':':," (,I'I':':~'" :', '1....:1 ',I..' , :,;'}~I'." ';,,'\" ;,1,.: \¡.!:' !,,':' " ':';':-~:: 1:':<.':1,' "i',',·· "':\:, ',: ",.\"," ,.!:' .::,',:: ..,. ," ': .:"''::'.'':;. '\:':'.'::.':,,:""1':\:'11, ,',~ ,1'1.,.·,. ,,' I I I:; , ", ~.': 'I,":" I,. ,., ".1 ", "',' I" ",,'" I, ., 'I' ~'I:i/ /";,,:',1,'.. I '\~.:,:.,;'. ,',I POOH. Clean hole up to window. Open EDC & POOH to 500'. Close EDC, POOH & Tag up @ surface. Inspect bit - OK. UD driling BHA# 10. PJSM for BID CT with N2. Displace CT to water. PT N2 unit to 3500 psi - OK. BID CT with N2 & bleed off. PJSM for securing CT prior to reel removal. Clamp CT end. Spool CT across pipe shed roof onto reel. Clamp CT tip with u-bolts & chain in place. PJSM with all personnel for simops on RIH liner assy & swapping reel. Reviewed HAlHM for planned activities & contingencies for well control without CT reel. Stress good communication & need to STOP any unsafe activities during simops. R/U, M/U & RIH 63 jts of 2-3/8" 4.7# L-80 STL with Pljt float equipment & turbos. M/U Baker Deployment Sleeve & CTLRT. Meanwhile swap out e-line reel to conventional 2" coil. Prep to stab CT into injector. Pull CT with tugger & place into counter. Secure CT with spooler clamp. Pull CT into rig floor. Prep CT tip for stabbing. Stab CT into injector. Prep & install weld-on eTC. Meanwhile hook-up hard line connections to reel. Pump 2 CT volumes thru coil to clean out any scale. Pump 2.75 bpm at 3000 psi. Pull test CTC. OK. Drift CTC with 1.0" drift. SAFETY MEETING. Review M/U of Baker CTLRT to eTC. Discuss hazards and mitgations. M/U Baker CTLRT for 2 3/8" liner. Liner and running tools = 2030.65 ft. RIH with 2-3/8" liner on CT. circ. 0.2 bpm, 870 psi. Up Wt = 28.5K at 11450 ft. Dwn Wt = 12.8K. DS computer went down twice while RIH. Correct to depth off of mechanical indicator. No flag on CT to correct to due to new coil. COMP Ran thru window with no wt loss. RIH at 60 fpm, 0.4 bpm, 1430 psi, Sat down at 12,260, 12430, 12486, 12521, 12588, 12620, 12680, 12745, 12767, 12803'. Sat down at 12,803 ft, ten times. Pull 200 ft while circ. RIH sat down at 12795', 3 times. COMP Work liner down to 12,910 ft. Work down to 12,960 ft. Circ. at 1 bpm, RIH at 130 fpm with 0.1 bpm, Work liner down to 13,070 ft at 0000 hrs. DS computer shut down again. UPS cannot always keep up with rig dirty power supply. Need generator #3, which is still in Anchorage getting rebuilt. COMP Working liner to TD. Changes in load on CT hyd. powerpack causing UPS to computers to die. DS computer died 3 times in 30 min. Got clean power to DS computer by running extension cord from BHI clean power supply in their trailer. Work liner down to TD of 13,078 ft CTD, 13,083 ft corrected. Sat down 6 times at same depth. Liner landed on bottom. COMP Insert 5/8" steel ball and circ. at 1.7 bpm, 3700 psi. Ball on seat at 32 bbls, sheared at 3100 psi, Pull up and free from Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 6/1/2002 05:30 - 08:00 2.50 DRILL P PROD1 08:00 - 08:45 0.75 DRILL P PROD1 08:45 - 09:00 0.25 DRILL P PROD1 09:00 - 10:45 1.75 DRILL P PROD1 10:45 - 11 :00 0.25 CASE P COMP 11 :00 - 12:00 1.00 CASE P COMP 12:00 - 12:20 0.33 CASE P COMP 12:20 - 16:00 3.67 CASE P COMP 16:00 - 17:45 1.75 CASE P COMP 17:45 - 19:15 1.50 CASE P COMP 19:15 - 20:00 0.75 CASE P COMP 20:00 - 20:15 0.25 CASE P COMP 20: 15 - 20:30 0.25 CASE P COMP 20:30 - 22:30 2.00 CASE P COMP 22:30 - 23:45 1.25 CASE P 23:45 - 00:00 0.25 CASE P 61212002 00:00 - 01 :00 1.00 CASE P 01 :00 - 01 :45 0.75 CASE P Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:15 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 15-30A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: Spud Date: 5/24/2002 End: 6/6/2002 6/2/2002 01 :00 - 01 :45 0.75 CASE P COMP liner. RIH to same depth. 01 :45 - 03:00 1.25 CEMT P COMP Circ. well to 2% KCL water. Recover FloPro and haul to MI plant for next well. circ at 1.7 bpm, 3700 psi. 03:00 - 03:45 0.75 CEMT P COMP Circ. 2% KCL water at 1 bpm [0.9 bpm returns], while rigging up DS cement equipment. Cement slurry at 15.8 ppg wt. at 03:40 hrs. 03:45 - 04:00 0.25 CEMT P COMP SAFETY MEETING. Review cement job procedure and hazard mitigation. 04:00 - 04:45 0.75 CEMT P COMP Press test cementing line. Stage 8.0 bbls, 15.8 ppg. G cement slurry. Stop pump. purge cement lines, vac cement from behind dart. 04:45 - 05:45 1.00 CEMT P COMP Displace cement with Biozan water. pump 1 bbl. confirm dart was gone. Displace at 1.7 bpm, 3400 psi, 1.5 bpm returns. Dart on liner wiper plug at 40.6 bbl. Liner wiper plug sheared at 3000 psi, pumped 1.4 bbls and packed off completely. Holding static pump pressure of 4000 psi, bleed off CT press thru choke, pump up to 4200 psi, press fell back to 2000 psi, pump up to 4300 psi, holding static. 0 bpm, 4300 psi. 2 bbls cement out float shoe. Bleed off CT press and pump back up to 4500 psi, Holding 4500# jug tight. 05:45 - 06:30 0.75 CEMT P COMP Cycle press, up to 4500#, to zero and back up to 4500 psi, Float shoe or float cllr seem to be plugged. Bled CT to zero and pumped 500 psi down backside of CT. WHP held steady at 400 psi, [CT press at 30 psi, float valves holding press.] bleed off WHP and pump down CT to 4500 psi. 06:30 - 07:15 0.75 CEMT P COMP Bleed CT press to 1500 psi. Sting out of liner deployment sleeve. Saw CT press drop to 0 psi. Sting back in, sat down wt at same depth. Pump 0.3 bpm away at 4450 psi. Most likely pumping by seals, but pump away 8 bbls just in case. 07:15 - 07:30 0.25 CEMT P COMP Sting out of deployment sleeve & circ on TOL. 07:30 - 09:00 1.50 CEMT P COMP POOH CTLRT circ @ 2.6bpm, 2750psi 09:00 - 09:15 0.25 CEMT P COMP OOH. UD CTLRT. Observe no seals on CTLRT. 09: 15 - 09:30 0.25 CLEAN N CEMT COMP PJSM on P/U & RIH BHA & workstring for liner cleanout run. 09:30 - 11 :45 2.25 CLEAN N CEMT COMP P/U & RIH 1.90" D331 DSM, 1-11/16" motor & MHA. M/U 68 1" CSH singles 11 :45 - 14:00 2.25 CLEAN N CEMT COMP MlU injector & RIH with cleanout BHA#12 & tag TOL @ 11038'. Wt check = 24.5k up. 14:00 - 14:30 0.50 CLEAN N CEMT COMP Wash down clean with KCL water from 11038' to 11450' @ 0.9bpm, 2370/2400psi, & 28fpm. UCA compressive strength of cement @ 14:00 - 1072psi. Tag LWP @ 11450' i.e. estimated cement behind casing - 1.6bbls, 490' with TOe @ 12590'. 14:30 -16:10 1.67 CLEAN N CEMT COMP Mill LWP (11450') @ 1.1 bpm, 2600psi. Fell thru & wash down to 11460'. 16:10 - 21 :00 4.83 CLEAN N CEMT COMP Mill down with 1 ppb biozan-KCL water from 11460' 1.1 bpm, 2100psi. Various motor stalls @ 11469'. Milling junk from liner wiper plug 1 dart, getting stalls and some overpull. Pump 10 bbl high vis sweep. Mill junk. Pump 15 bbl high vis pill. Mill thru junk. Drill cement to 11500'. Ave ROP = 30 FPH. 21 :00 - 23:30 2.50 CLEAN N CEMT COMP Milling out cement. 1.1 bpm, 2500 psi, 30 FPH. Still seeing Printed: 7/18/2002 3:05:15 PM ) ) Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Start: 5/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 6/6/2002 Rig Name: NORDIC 1 Rig Number: 1"::\ ·t' 'I I , 'I!:: ' ., ,. ~. ..",¿:.'¡.,.'.',.",.'......."..,.,....' :.,...:'..~.. '.,.....::.,;'.'. ",0.;'·.\,'.:,'.';. '.',':.",'ql:":.:"" '.,'.·.:..,::.M,'. :,.~..'"...~,'."'.';'.:.,'..;.,',;..~, ',.....~".'.,.;;, :.:,'.:.,..'.., ,:.,""':..',..;...'.;,,','.:,, '..,".':','...".',.!,..\.',':.:..1:.,·,",,'...,',,··..:,'..'...'.,;...':), " ..,.'.: ... " , I ~,. .,~.,,$,.,"',,·,..r ··n,'~, "on",',Qlf, 1"'\1' ,p' e' rall·:'¡';n, '.c:; , , '..,:.......'.'....:,.'.:,.',::,.,.,J,....~,'".,', .,':,',..~,..',.".'.,.,'...',:.,..e..'..','.'.':,.:.,':.,',:.....,.,.,..,','..,'....',,:.'..,'.'..,:':',', ,..,:.':'..:,..1"'""....'.,..,.,:,:.ro.',·.,,:,',:::'....·',m,' ..,.,'........,.,'.:",.-."...,'.·...,i.'," ":,.'.'..,,...º,.,', '.·:,·.:,'.:,.".:..,'po~rs '1'~SI\., ,~ø e, I ,,,11'::" r:; "I,'stS~ 'I ", I;J' "'~, ~!~ ~ I U,..,. :' i/, .,.. ,.".., ,',.'.:' .'. ...,"",."" ...; .',';T:,' i. ...:.<,':. '.1·;.::' ::'{::.:'\'I :,:::" . 2.50 CLEAN N CEMT COMP 6/2/2002 21 :00 - 23:30 23:30 - 00:00 0.50 CLEAN N CEMT COMP 6/3/2002 00:00 - 02:00 2.00 CLEAN N 02:00 - 04:00 2.00 CLEAN N 04:00 - 05:00 1.00 CLEAN N CEMT COMP CEMT COMP CEMT COMP 05:00 - 06:00 1.00 CLEAN N CEMT COMP 06:00 - 07:45 1.75 CLEAN N CEMT COMP 07:45 - 08:50 1.08 CLEAN N CEMT COMP 08:50 - 14:00 5.17 CLEAN N CEMT COMP 14:00 - 14:45 0.75 CLEAN N CEMT COMP 14:45 -18:30 3.75 CLEAN N CEMT COMP 18:30 - 20:30 2.00 CLEAN N CEMT COMP 20:30 - 22:45 2.25 CLEAN N CEMT COMP 22:45 - 23:30 0.75 CLEAN N CEMT COMP 23:30 - 00:00 0.50 CLEAN N STUC COMP 6/4/2002 00:00 - 00:30 0.50 CLEAN N STUC COMP 00:30 - 02:00 1.50 CLEAN N CEMT COMP 02:00 - 02:15 0.25 CLEAN N CEMT COMP 02:15 - 03:30 1.25 CLEAN N CEMT COMP Spud Date: 5/24/2002 End: 6/6/2002 I",,', '1.:",:,,1 ,"'11 torque/overpulls from rubber or metal on bottom. Drilled to 11530 ft. Milling cement, 1.1 bpm, 2550 psi, 35 FPH. Milled to 11,550 ft. Pumped 15 bbl high vis sweep. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 50 fph. Milled to 11 ,650 ft. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 40 fph. Milled to 11,730 ft. Pumped 10 bbl high vis sweep. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 40 fph. Milled to 11,755 ft. Stall with overpull, pulled to top of liner clean, RIH to bottom clean. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 40 fph. Milled to 11,790 ft. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 50 fph. Milled to 11,855 ft. Wiper trip to TOL. Motor stall & hung-up @ 11035'. Pull free with 10k overpull. Backreamed 2x to TOL. RBIH clean to btm. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 35fph. Milled to 12003 ft. Pumping 5bbls regular bio-sweeps per 50ft. Wiper trip clean to TOL. RBIH clean to btm. Milling cement, 1.1 bpm, 2700-3000 psi, 1500# WOB, 30fph. Milled to 12064ft. Pumping 5bbls regular bio-sweeps per 50ft. Wt stacking & pulling heavy. Can't get enough WOB. Mix-up & pump 5 bbls of hi-vis 3% lubetex pill. Milling cement, still stacking wt. Pump 10 bbls high vis pill with 3% lubtex. Up wt = 29K, Dwn Wt = 9K, 3K more drag in last 12 hrs of drilling. Drilled to 12,080'. Milling cement, added 1 % Lubetex to system to reduce drag [3 drums]. Circ. slicker fluid around while milling cement. Milled to 12,100 ft. Lubetex reduced drag by 1500#, but ROP only 10-20 FPH. POOH. 1.1 bpm, 2800 psi, 28K up wt. Pulled into something at 11420 ft. [very close to where we started milling on LWP [11,450']]. Bit stuck. pulled 8K over. Worked pipe from 30k - [-81<], ten times. Worked pipe. Bit stuck, full returns, pump 1.0 bpm at 3600 psi. Surged well with 1000 psi while working CT from 30K to -8K. Pulled up to 40K, and 45K. Pulled 45K and opened Baker choke and pulled free at 00:30 hrs. POOH. Bit Stuck at 11,420 ft. Work free at 45K up wt and opening Baker choke drop CT press. Pull up clean with 28K. above stuck point. POOH. pump 1.0 bpm, 2800 psi. SAFETY MEETING. Review standing back 1" CSH workstring procedure and hazards. Stand back 34 stds of 1" CSH. UO mill, motor and MHA. MIU new 1.875" HC D331 mill, new Printed: 7/1812002 3:05:15 PM ) ) 15-30 15-30A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ."i#···;:,~,i~:1:.··:::,' ·::f.ib~~;·,.',:¡:~ã~k.,'.::':,c,~åJ:·,:.~~t" .;."",~~I'r I"~ h,:~, :..",~,I',::",'. :,':V> , .::,.";::1,': .',:!i:' "::,: i','; '.'/::::,:...' 02: 15 - 03:30 1.25 CLEAN N CEMT Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ··...:.::):::...;::."R~t~':·::':,,:',' 6/4/2002 Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: Spud Date: 5/24/2002 End: 6/6/2002 :,:"I:I4',·'il ."',. ~:',:'::, :\1).·;;,>;'.'· ','. ::':.'':.,:: "',... ::., , 1.',",1,;.:".:,',.,.,":,":.:.:,.,,':::.1:' .j, ',.'I:,':" :':, ",.:;.;:'.' i~l: ::'~I:::'>.·.;<.:.,.'I '.:: I':'f: ,I· ",:'.''' ",.,:." .. :" ~ ': 'I: i"/: "::<, i "~: ·:'0:'".'" :'::'/' ::.:, '.'.' ,:. ,', Nha§e .,..,. ,',1,' .",,,.;.. ..',.... " "',," .'" ""',' .t \:.'::.'':'.:.:.,',''.'.'.' :,:.:."'.":::;,\".:,,:,,,,:..:..:, :,.:·::,:',~'~.~~n~~I~.~:, Q:I;~,~~r~:'I~ ,.~,':,,'.::: COMP 03:30 - 05:00 1.50 CLEAN N CEMT COMP 05:00 - 07:30 2.50 CLEAN N CEMT COMP 07:30 - 09:15 1.75 CLEAN N CEMT COMP 09: 15 - 09:45 0.50 CLEAN N CEMT COMP 09:45 - 10:00 0.25 CLEAN N RREP COMP 10:00 - 13:00 3.00 CLEAN N CEMT COMP 13:00 - 13:30 13:30 - 13:45 0.50 CLEAN N 0.25 CLEAN N CEMT COMP CEMT COMP 13:45 - 16:15 2.50 CLEAN N CEMT COMP 16:15 - 18:30 2.25 CLEAN N CEMT COMP 18:30 - 19:30 1.00 CLEAN N CEMT COMP 19:30 - 21 :30 2.00 CLEAN N CEMT COMP 21 :30 - 23:30 CEMT COMP 2.00 CLEAN N ,,.:..,'; ',. "; ., I· :,:',: motor and MHA. Mill was 50% cored, the center diamonds had worn and some were missing. Mill still in gauge. RIH with 1.875" diamond mill on 1.69" motor, MHA and 34 stds of CSH. M/U Baker hyd disc, checks and lockable swivel. RIH with milling BHA (Total length = 2097 ft) to 11410'. Ream/backream previous stuck section to 11470' & did not see any restriction or motor work. RIH to btm. Milling cement, 1.1 bpm, 3400-3600 psi, 5.5kWOB, & 25fph. Still stacking wt. Up wt = 25k, Dn wt = 10k. Milled to 12135ft. Meanwhile start swapping well to fresh slick 2% KCL. To bring up system to 1 ppb biozan & 1 % lubetex on 2nd circ. Stall & pull heavy . Wiper trip clean to 11500' chasing fresh KCL water up. RBIH clean to btm. New KCL water @ surface. Start adding biozan & lubetex to KCL water. PUH to 11660' to allow newly replaced Nordic gen to cool off. Gen - OK. RBIH & stacked out @ 12100'. Motor stall. P/U & observe pump pressure still climbing. Continue P/U & back down pump. Got stuck with no circulation (packed off). Worked pipe from 40k to -5k - no luck. Pull to 45k & 50k max - no luck. Pressure up to 4600psi - no luck. Surged well with 1000psi WHP & 2000psi CTP. Dumped WHP thru Baker choke - no luck. Continue working pipe from 45k to -8k. Meanwhile call for pump truck to shear burst disc above motor. Pump truck arrive onsite. RIU hard lines. PJSM with all personnel for HP pumping operations. Reviewed HAlHM for planned activities. Stress good communication & need to stay off HP lines. PT cement line. Press up to 5100 psi and broke circulation. Pump 4000 psi at 0.6 bpm. Work pipe with 50K - [-8K]. Swap to rig pump. Pump 3700 psi at 0.6 bpm. Circ. high vis / 3% lubetex pill to bit. Rate increased to 0.8 bpm at 3400 psi. Circ. 0.9 bpm, 3400 psi. Slick high vis pill outside CT. Work CT 55K to -8K, No luck. Pump 20 bbl crude. Drop 0.5" steel ball to open circ sub. Displace with 14 bbl crude and swap to 1.5# biozan water. Circ. 0.9 bpm, 3400 psi. Circ. ball off reel and let fall. Pull60K with 20 bbl crude outside CT. Work CT 60K to -8K. No luck. Press up backside to 1420 psi. Work CT 60K to -8K. No luck. Crude on backside. Circ. Biozan and work CT. Work CT 65K to -8K. Pull65K and open Baker choke 3 times. Work CTwith 65K to -8 K with no pump. MD = 12,074' at 61K. Pull 65K, circ and open Baker choke to dump press. Still stuck. Open circ Baker sub with .5" ball on seat. Circ. 1.0 bpm, at 2000 psi. Circ. 1.7 bpm at 3830 psi. Circ. 1.5 bpm 2900 psi and work pipe 66K to -8K. Hold 60k pull on coil. Call out Nitrogen, plan to displace CT Printed: 7/1812002 3:05:15 PM ') -) 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: :::'.....,'.'.],';..,...,.....',·..··~.,.,..,',:,.:,ro,·.,·,:::,1',···.·,:,,·.,'...m.'..·...'.....:!'....:,::'.,'.:.-.:,.:.'...','.,',.. T...,.....',I·:.:..,:O,.·..·.·.'..:.',..':, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: :·i.,'·:.·,·'··;·':···::':,·: ,...,[)ªte 1;,:,,,':,:1':'1':'11':'.'1'1.'1:'" 6/4/2002 21 :30 - 23:30 2.00 CLEAN N CEMT COMP 23:30 - 23:55 0.42 CLEAN N CEMT COMP 23:55 - 00:00 0.08 CLEAN N CEMT COMP 00:00 - 01 :00 1.00 CLEAN N CEMT COMP 6/5/2002 01 :00 - 02:40 1.67 CLEAN N CEMT COMP 02:40 - 03:00 03:00 - 03:20 03:20 - 04:45 CEMT COMP CEMT COMP CEMT COMP 0.33 CLEAN N 0.33 CLEAN N 1.42 CLEAN N 04:45 - 06:45 2.00 CLEAN N CEMT COMP 06:45 - 09:00 2.25 CLEAN N CEMT COMP 09:00 - 10:00 1.00 CLEAN N CEMT COMP 10:00 - 10:45 0.75 CLEAN N CEMT COMP 10:45 - 13:00 2.25 CLEAN N CEMT COMP 13:00 - 13:15 0.25 CLEAN N CEMT COMP 13:15 - 13:30 0.25 CLEAN N CEMT COMP 13:30 - 15:30 2.00 CLEAN N CEMT COMP 15:30 -17:00 17:00 -17:15 1.50 CLEAN N 0.25 CLEAN N CEMT COMP CEMT COMP Spud Date: 5/24/2002 End: 6/6/2002 . . I '~' ,I ,,:,.' ,,'. I '·',1'1 . with N2. Rig up Dowell nitrogen truck. Pump 30bbl slick pill (1.5ppb bio + 3% Lubetex) ahead of N2. Shut down for PJSM. Pre Job Safety meeting prior to pumping nitrogen down coil. Begin pumping N2 down coil at 1000scf/min. ConLPumping N2 down coil 2600psi @ 1000scf/min Continue pumping N2 to displace coil. 1000scf/min @ 2900psi, still holding 58k up weight on string. 1000scf/min @ 3100psi. 48000scf of N2 away at 3595psi. Shut down N2, pumped a total of 50000scf of N2. 38bbls of returns on the micromotion out meter while pumping N2. Rig down N2 truck. Slowly bleed coil pressure via baker choke to possom belly, trap 500psi on coil. Work pipe, pull up 65k, slack off, pull 65K and hold. Slack off, pull 65K. Pressure up on backside to 1500psi, cycle to 65K several times, slack off to -8K. Pull to 65K a few more times. Nothing. Pull up 65K and dump well head pressure. Nothing still stuck. Bleed down coil. Continue cycling pipe as we bleed down CT. PJSM prior to circulating out N2 to surface. Pump max rate to fill coil and displace N2. At 43bbls away see wellhead pressure response. Hold CTP constant at KRP and circulate out N2. Pump approx 108bbls, observe clean returns, shut well in and monitor. Dead well. Drop & launch 5/8" ball to disconnect from BHA just above eire-sub, motor and mill. 42.5 bbls to ball seat, pump 1.4 bpm, Ball not on seat at 50 bbls, cycle pump. Pump 11 bbl very high vis pill to carry ball on seat. Pump 2 coil volumes, cycle pump. Ball still not on seat. Drop 5/8" Delcron ball, Displace with high vis pill at 1.4 bpm. Pump 60 bbls. Ball not on seat. Check for ball on surface. No ball. Pump 10 bbls high rate. Cycle pump, 2 bpm to 0 bpm. pump 20 bbl at 1.4 bpm. Not free. Drop second Delcron 5/8" ball and displace. Heard ball moving inside CT. Pumped 52 bbls. no indication of ball on seat. Pull 65K. Press up backside to 1400 psi and pull 65K. No pipe movement. Pump 2" X 4 " soft permeable foam pig to chase balls. Circ. Had press spike at 35 bbls. Pump at 2000 psi and foam pig landed at 42.5 bbls (200psi bump in pump pressure, no pressure change when it went through other profile - upper disconnect). Pick up free with 28K up wt - similar to upweight before stuck. POOH. Layout Baker tools. Get ready to stand back CSH workstring. SAFETY MEETING. Review "Getting HSE Right" concepts and present HSE fundamentals with the day crew. Review standing back CSH Stand back 68 joints of 1" CS Hydril in doubles. Recovered all three balls, found six chunks (larger than 5/8", smaller than 3/4") of cement, some foam. (had installed a valve to isolate micro mulsion prior to bursting disk, knocked cement loose) Cut 200' of coil and weld on new CTC. Pull test I Pressure test CTC Printed: 7/1812002 3:05:15 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 'b~t;:' I ; , ': ~ I ': ' ",I 'I I : I i II I I I 6/5/2002 6/6/2002 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: ,,',. "'·~II ~~9~;t,Ttl:, .: !ffl,O~(~·. ,.. ,r~~.~,!..·! :9~~~',:. '··~~t::,·,·~~~~~·,::.:,.·"...i:::'il,':i:·,,:',::·i:'",i,'.:.:::!·i·"I·,',:9~~~fl~Þ~~':ef:9:p,~(~~IC)~~, ' 17: 15 - 21 :50 4.58 BOPSUR N CEMT COMP BOPE Test, witnessed Waived by John Spalding 21 :50 - 23:45 1.92 CLEAN N CEMT COMP Waiting on Schlumberger single shot and chemical cutters. 23:45 - 00:00 0.25 CLEAN N CEMT COMP Pre Job SAFETY MEETING with Bob Staats and rig team. Emphasized safety with strip guns (string shot), similar to running perf guns: keeping people out of cellar while deploying the tool and RIH carefully with the hydril to avoid damaging strip guns. Discussed E-fire process. Make up Schlumberger String shot with e-fire head, 19 joints of 1" CS Hydril and 2.625" NoGo. RIH with string shot assembly at approx. 90fpm Slow RIH speed to 20fpm as we approach liner top. Tag up lightly at 11,038'... believed to be liner top. (liner top expected at 11,056') Set down approx. 20001bs. Work string shot at liner top (2.25" id deployment sleeve inside 3.5" tubing), bottom of the tool has a 3' long 1-1/16" round bullnose (same one we run on perf guns). PU, bring on pumps 0.7bpm @1150psi. Attempt to RIH past liner top, no luck. Repeatedly setting down on liner top every time we try to RIH past 11,038'. PU, Pump down backside, RIH attempt to get past 11,038', unable to proceed. Discuss options...POOH POOH with string shot assembly SAFETY MEETING. Review procedure and hazard mitigation for stand back CSH. Standback 1" CSH workstring. Layout Baker tools and SWS firing head. Found string shot tool parted at top of string shot leaving 10' of steel metal strip in hole and 3' of 1.69" OD guide tube on bottom. Top of fish at 11,043'. Fish setting on top of 2-3/8" liner top at 11,056 ft. RIH with nozzle on CT. Freeze protect 3-1/2" liner with diesel as per program. POOH. Clean rig pits. Supersuck cuttings tank. Nipple down BOPE. RELEASED RIG ON 15-30A AT 15:00 HRS. TOTAL TIME ON WELL WAS 13 DAYS AND 6.5 HOURS. Moved Rig down pad to 15-31 A. 00:00 - 02:05 2.08 CLEAN N CEMT COMP 02:05 - 04:15 04:15 - 05:00 2.17 CLEAN N 0.75 CLEAN N CEMT COMP CEMT COMP 05:00 - 07:00 07:00 - 07: 15 2.00 CLEAN N 0.25 CLEAN N CEMT COMP CEMT COMP 07: 15 - 08:00 08:00 - 09:00 CEMT COMP CEMT COMP 0.75 CLEAN N 1.00 CLEAN N 09:00 - 10:30 10:30 - 11 :30 11 :30 - 13:30 13:30 -15:00 CEMT COMP CEMT COMP CEMT COMP CEMT COMP 1.50 TA 1.00 TA 2.00 TA 1.50 TA N N N N Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:15 PM ') ) Well: Field: API: Permit: 15-30A Prudhoe Bay Unit 50-029-22282-01 202-089, Approval #302-182 & 302-383 Rig Accept: Rig Spud: Rig Release: Drilling Rig: 01/25/03 01/27/03 02/05/03 Nordic #2 NON RIG WORK CONDUCTED BETWEEN SIDETRACK ATTEMPTS 06/08/02 ATTEMPTING TO FISH 13' OF STRING SHOT, RAN WIRE GRAB AND SPECIAL OVER SHOT SET UP. 06/09/02 PULLED 20' PRIMER CORD AND 70" OF STRIP GUN. 06/10/02 PULLED OUT LAST 4' OF STRIP GUN WI BULL NOSE ASSEMBLY 3.21". TAG LINER TOP WI 2.50" LIB, CLEAN PICTURE. LEFT WELL SHUT IN (PRE CTD). NOTIFY DSO OF WELL STATUS. 06/12/02 DRIFTED 2 318" LINER WI 1.85" SWAGE TO 11,220' WLM, ALL CLEAR. NOTIFIED PAD OP. OF WELL STATUS. 06/30/02 RIH WI 1.8" JS NOZZLE TO 11705'. JET LINER WI SLICK WATER. JET LINER WITH 10 BBLS OF 7.5% HCL. CIRCULATE ACID OUT OF HOLE. CHAIN INSPECTION. REPLACE BEARING. PU 1-11/16" MHA & SWS MEMORY GR/CCL. LOG GR FROM 11700' TO 11000'. FLAG COIL @ 11500'. POH. 07/01/02 POH. MAKE FLAG CORRECTION. MU CHEMICAL CUTTER AND E-FIRE HEAD. RIH. TIE-IN TO COIL FLAG. POSITION CHEMICAL CUTTER AT 11610'. PERFORM PRESSURE SEQUENCE TO ACTIVATE FIRING HEAD. GOOD INDICATION OF FIRING. POH. GOOD INDICATION FI CHEMICAL CUTTER DETONATION. BOW SPRINGS SEVERELY DAMAGED. CUT PIPE. PU GS SPEAR, JARS & BHA. OAL=12.0'. RIH. LATCH LINER @ 11060'. PULL 8K# OVER, JAR LINER FREE. PU 130'. RIH, SLIGHT WEIGHT SET @ 10955'. PUMP OFF LINER @ 10960'. POOH. FP BACKSIDE WI METH/WTR. RDMO. JOB COMPLETE. 10/16/02 MITOA TO 2000 PSI (PASSED) - PRE RIG. TOOK 5.5 BBLS OF DIESEL BLED OA DOWN TO 0 PSI. 10/18/02 T/l/0=250/250/150. (POST MITOA). 12/25/02 VALVE CREW TESTED THE MV, WV, AND SV TO 3500 PSI FOR 15 MIN. OK. 12/30/02 T/l/0=320/340/150 (FOR CTD) IA FL @ 1116'. 01/03/03 LOAD & TEST IA TO 3000 PSI, PASSED, STARTING PRESSURES 350/3000/575. 30 MIN PRESSURES 350/2880/545. BLEED IA TO 800 PSI. 01/06/03 TIIIO = 240/400170 BLEED TIO (CTD PREP) TBG FL @ 1690'. BLED TBG FROM 240 PSI TO 10 PSI IN 30 MINS. IA FL @ 100'. BLED IA FROM 400 PSI TO 80 PSI IN 1.5 HRS. FINAL WHP'S = 10/80/60 ) 15-30A, Coil Tubing Drilling Sideuack Page 2 ) 01/07/03 TIIIO = 10/90/70 MONITOR WHP'S (POST TIO BLEED, CTD PREP) IA AND OA PRESSURE INCREASED 10 PSI SINCE BLED YESTERDAY. POSSIBLE DIFFERENCE IN GAUGES USED. 01/09/03 TIO= 0/100/70 PREP FOR MITIA. IA FL @ 225' (14 BBLS). ) ) EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 15-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 Daté From - To Hours Task Code NPT Phase Description of Opérations 2/6/1 901 00:00 - 0.00 RIGD N WAIT POST Wait on weather phase 2. 24 MPH winds -8 degrees -54 CF. Extensive drifting due to recent snow fall. 1/23/2003 12:59 - 13:00 0.02 P PROD1 Building Cum Phase Breakdown Table 13:00 - 20:00 7.00 MOB P PRE Move over MWD & Mud shacks. Back-off K317B well. Mobilize crane to assist with overhead doors for laying over derrick. Scope down derrick. 20:00 - 00:00 4.00 MOB N WAIT PRE Wind velocities (+30 MPH gusts) have exceeded contract maximum for lowering derrick. WOW. Rig on paid standby. 1/24/2003 00:00 - 04:30 4.50 MOB N WAIT PRE Continue waiting for winds to subside for crane operation. (Need crane to assist lifting overhead pipe shed door to allow for lowering derrick.) 04:30 - 08:00 3.50 MOB P PRE Winds down 10-15 mph. Lift overhead door and lower derrick. 08:00 - 08:30 0.50 MOB P PRE Safety meeting with security and tool services. 08:30 - 00:00 15.50 MOB P PRE Move rig from K-Pad to DS-15. Making repairs to crown sheaves while moving. On location at 23:50 hrs. 1/25/2003 00:00 - 09:00 9.00 MOB N RREP PRE Rig on location, not spotted over well. Continue making repairs to crown sheave, One sheave bearings bad (either didn't get packed or high temp grease). Replace. Inspect others. 09:00 - 14:00 5.00 MOB P PRE Derrick up ops using crane for pipe shed roof. Level rig and survey. 14:00 - 14:30 0.50 MOB P PRE Safety meeting -- stabbing pipe. 14:30 - 15:00 0.50 MOB P PRE PU injector. 15:00 - 15:30 0.50 MOB P PRE Rig injector and winch lines for stabbing pipe. 15:30 - 16:00 0.50 MOB P PRE Stab pipe using internal grapple system. 16:00 -17:00 1.00 MOB N RREP PRE Finish leveling rig and surveying it for level. Lower blocks and take measurements from CL of table -- blocks hanging 6-1/2" off center towards ops cab. This exercise was to get measurements for evaluating shimming requirements to get blocks centered over well. 17:00 - 18:00 1.00 MOB P PRE Position rig over well. Rig accepted at 1800 hrs 1-25-03 18:00 - 18:30 0.50 BOPSUR P PRE Tech Limit meeting and crew change. Review LL on NU procedures and plan forward. 18:30 - 20:30 2.00 BOPSUR P DECaMP Nipple up BOPE. 20:30 - 20:45 0.25 BOPSUR P DECaMP PJSM on testing BOP's. 20:45 - 00:00 3,25 BOPSUR P DECaMP Pressure test BOPE 350 psi low/5min 3500 psi/5min. (AOGCC rep John Spaulding waived witnessing test) 1/2612003 00:00 - 04:00 4.00 BOPSUR P DECaMP Continue testing BOPE. Same test replace packing on injector and prep eline for slack management. Blinds failed. Blind rams not testing. 04:00 - 04:30 0.50 BOPSURN DECaMP Redress blind ram seals. 04:30 - 05:30 1.00 BOPSUR P DECaMP Finish testing BOPE. 05:30 - 06:30 1.00 PULL P DECaMP Clear floor from testing. P/U injector for e-line slack management. Stab on well, 06:30 - 06:45 0,25 PULL P DECaMP Crew C/O 06:45 - 07:30 0.75 PULL N SFAL DECaMP Start reversing thru kill line. Air hose still attached to manifold, and not isolated -- hose ruptured. Clean floor (no spill to ground outside). LCIR 2003-IR-421246. 07:30 - 08:45 1.25 PULL P DECaMP Reverse circulate to pump E-line back into coil. As before, did not hear rattle until rate hit 2.2 BPM (Note: using KCL water here vs Flo-Pro mud last time), then the rattle was short lived (also, as before). Continue reversing for about 15 minutes at 2.5 BPM. Blow back coil with air for cutting ops. 08:45 - 09:30 0,75 PULL N MISC DECaMP Unstab inj. About 12' of E-line sticking out end -- it went the Printed 2/10/2003 11 .17: 1 0 AM ) ) BP EXPLORATION Qpe.rations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 5-30 15-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 Date Frorn ~ To . Hours Task Code NPT Phase Description of Operation~ 1/26/2003 08:45 - 09:30 0.75 PULL N MISC DECOMP wrong direction! Cut E-line, shrink wrap, and try procedure again (this time, install connector to make sure end of cable is up inside coil). Pump cable back. Unstab. 09:30 - 10:15 0.75 PULL P DECOMP Cut 28' coil to end of E-line. 10:15 - 12:15 2.00 PULL P DECOMP Rehead CTC. Pull test to 30k. Blow back air through coil again. MU E-line MHA while checking well pressure -- 80 psi. Bleed well thru buster. 12:15-15:00 2.75 PULL P DECOMP Try circulating. As feared, coil has frozen because of time it took to rehead. MU hyd.spear and jars. 13:00 - 15:00 2.00 PULL P DECOMP RIH, taking methanol returns to cuttings tank, Ice plug melted at about 8000'. Weight check at 10990' - 33k up. 15:00 - 16:00 1.00 PULL P DECOMP Returns still kinda gassy. Circulate until we get good clean KCL back. 1.9 BPM; 3050 psi CTP. lAP = 120 psi; OAP = 240 psi. 16:00 - 16:45 0.75 PULL P DECOMP RIH and latch FN at 11058'. Pull to 56k, looks like we were dragging it for about 5', then broke back to 33k. Keep pump off. Repeat tags. No more overpulls. Tag depths at 11054' (after stretch). 16:45 - 18:15 1.50 PULL P DECOMP POOH filling down backside. Fish-on 18:15 - 18:30 0,25 PULL P DECOMP Setback injector. 18:30 - 18:45 0.25 PULL P DECOMP Crew change and PJSM for I/d fishing tools and 2 3/8" liner. 18:45 - 19:30 0.75 PULL P DECOMP LID 17 jts 2 3/8" STL liner 19:30 - 20:15 0.75 CLEAN P DECOMP P/U BHA #2 (49.71 ') stab-on injector. Surface test BHI tools -okay. 20:15 - 22:25 2.17 CLEAN P DECOMP RIH to 11537'. (gr 23' from bit) Briefly circulated some gas to surface. 22:25 - 22:40 0.25 CLEAN P DECOMP Orient TF to 180. Tie-in f/ 11514' to 11573'. found RA at 11545'. -5' correction. 22:40 - 22:45 0,08 CLEAN P DECOMP RIH at min/rate tagged at 11615'. 22:45 - 00:00 1.25 CLEAN P DECOMP TOH flag EOP at 11400' Continue TOH 1/27/2003 00:00 - 00:40 0.67 CLEAN P DECOMP Finish TOH. 00:40 - 01 :55 1.25 STWHIP P WEXIT Stab off well. PT BHI coil connector to 3500 psi-ok. LID BHI motor. P/U Weatherford 2.5" OH Whipstock with BHA #3 (52.09') Stab-on well. Open EDC 01 :55 - 04:20 2.42 STWHIP P WEXIT RIH w/o pump. Stop at flag and correct -8' to 11452'. RIH to 11570'. Check weights 17k down 33k up. 04:20 - 05:25 1.08 STWHIP P WEXIT Log up for RA tag. (gr 24' up from bottom of WS) Log RA tag at 11540' and stop, slack-off 1'. Close EDC pressure up 4100 psi and set whipstock. Set dwn and confirm set. WS set with top at 11552'. 05:25 - 06:30 1.08 STWHIP P WEXIT POH to 11530', Open EDC and swap hole to Flo-Pro mud. 06:30 - 08: 15 1.75 STWHIP P WEXIT POOH. Flag pipe at 11400' EOP. 08:15 - 08:30 0.25 STWHIP P WEXIT LD BHA -- everything OK on setting tool and rod. 08:30 - 09: 15 0.75 DRILL P PROD1 MU drilling BHA with 3.0 deg motor and 2.75" M-09 bit. 09:15 -11 :30 2.25 DRILL P PROD1 RIH. Correct depth at flag (-7'). RIH with LS tool face clean through window. Tag aluminum billet at 11,554'. 11 :30 - 12:00 0.50 DRILL P PROD1 Work TF on 3.0 deg motor from 140L to 60R. 2.4 amps to get there (typically takes about 0.8 amps), 12:00 - 13:30 1.50 DRILL P PROD1 FS 1.6/3200. Couple of stalls getting started, Time drill off billet for first 1', then ease into it w/ controlled drilling at 10 - 15 FPH. Drill to 11573'. Saw RA. 13:30 - 14:00 0.50 DRILL P PROD1 PUH and get correct tie-in into Halliburton GR/CCL (11/1/92) to get a corrected RA depth. Correction only +1'. Corrected RA Printed: 2/10/2003 1117:10 AM ) " ) BP Page 3 of 8 Operations Summary Report Legal Well Name: 15-30 Common Well Name: 15-30 Spud Date: 5/24/2002 Event Name: REENTER+COMPLETE Start: 1/23/2003 End: 2/5/2003 Contractor Name: NORDIC CALISTA Rig Release: 2/5/2003 Rig Name: NORDIC 2 Rig Number: N2 Date From- To Hours Task Code NPT Phase Description of Operations 1/27/2003 13:30 - 14:00 0.50 DRILL P PROD1 at 11540'. So, the BHllog of 6/1/2002 is 16' off depth to PDC in one spot, but on depth with PDC at RA over a continuous displayed log strip covering 100' (splicing issue??). 14:00 - 15:30 1.50 DRILL P PROD1 Drill to 11620'. 15:30-17:30 2.00 DRILL P PROD1 TOH f/ laterial BHA 17:30 - 18:00 0.50 DRILL P PROD1 LID 3 deg motor. P/U 1.1 deg motor. 18:00 - 22:45 4.75 DRILL N PROD1 BHI orienter not surface testing. Change out to #2 orienter notice it's not made-up correctly from shop. P/U #3 orienter. This does not test great either. Try different combo's of tools with equally questionable results. Finally trace problem to surface test cable and test cap rather than individual tools. 22:45 - 23:00 0.25 DRILL P PROD1 P/U BHA #5 (54,11 ') 23:00 - 00:00 1.00 DRILL P PROD1 RIH 1/28/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Continue RIH to 11550'. 01 :00 - 01 :15 0.25 DRILL P PROD1 Log tie-in from RA tag at 11540', + 1 correction. 01 :15 - 03:10 1.92 DRILL P PROD1 Directionally drill ahead f/ 11620' to 11754' 1,5 / 1.5 ECD 10.8 ppg 3425 psi on btm 3170 psi free-spin 4.5k WOB 100'/hr. Up wt 26k, dwn wt 11.6k Landed out at 11649'md 8723.6'tvd Start stacking weight. 03:10 - 03:25 0.25 DRILL P PROD1 Wiper trip to window. 03:25 - 04:00 0.58 DRILL P PROD1 Directionally drill f/ 11754' to 11770'. Differentialy stuck. 04:00 - 04:20 0.33 DRILL N PROD1 Find neutral point. Shutdown pump. Wait 15 min. Pull 52k came free. 04:20 - 04:55 0.58 DRILL N PROD1 Make another short wiper trip to 11580'.. ream last 15' to bottom. 04:55 - 07:45 2.83 DRILL P PROD1 Drilling ahead f/ 11770' to 11950' @ 0600 hrs but very ratty and stalling/sticking early on. 15-20k overpulls. 3160 FS 3440 on btm 3-4k WOB 1.6 / 1.6 07:45 - 08:25 0.67 DRILL P PROD1 Wiper trip to window. 08:25 - 10:30 2.08 DRILL P PROD1 Drilling ahead f/ 11950' to 112151'. 3-4k WOB 1,6/1.6 10:30-11:00 0.50 DRILL P PROD1 Wiper trip to window. 11 :00 - 12:40 1.67 DRILL P PROD1 Drilling ahead f/ 12151' to 12223'. 3110 FS 3380 on btm 3-4k WOB 1.6 / 1.6 slow drilling and stacking out. 12:40 - 13:50 1.17 DRILL P PROD1 Wiper trip to window. 13:50 - 19:50 6.00 DRILL P PROD1 Drilling ahead f/ 12223 to 12257' 3300 FS 3800 on btm 2-4k WOB 1.65 / 1.65 stacking out. Appears to be hard drilling similar to Nordic 1 drilling. Town crew wants to continue grinding on it. 19:50 - 20:00 0.17 DRILL P PROD1 250' wiper trip. 20:00 - 20:15 0.25 DRILL P PROD1 Unable to drill ahead. Fair to good wt transfer and WOB. 200-400 psi motor work but NO drill off. May be mud. 20:15 - 22:10 1.92 DRILL N DPRB PROD1 TOH to check BHA. 22: 10 - 23:00 0.83 DRILL N DPRB PROD1 Set back injector. Check torque on connections. Minor wear on bi-center bit gauge. Motor looks okay no bearing wear - turn bit to drain. Change bits. PT CTC to 3500 psi - ok. Stab on injector. RIH 40'. 23:00 - 23:50 0.83 DRILL N DPRB PROD1 Checking out off drillers side drive plate companion flange bolts and tighen. 23:50 - 00:00 0.17 DRILL N DPRB PROD1 RIH w/ BHA#6 (54.12') 1/29/2003 00:00 - 01 :45 1.75 DRILL N DPRB PROD1 Continue RIH to 11545'. 01:45 - 02:00 0.25 DRILL N DPRB PROD1 Log tie-in. -8' correction. 02:00 - 02:30 0.50 DRILL N DPRB PROD1 Continue RIH. Start mud swap to new (55% new & 45% used mud mixed) Flo-Pro ( 8ppb Kla-Gard, 3% LubeTex) Tag-up at Printed: 2/10/2003 111710 AM ) ) BP EXPLORATION O.perations Summary Report Page 4 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 1 5-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 Date From -To Höurs' Task Code NPT Phase DescriptiqnofOþeratiQns 1/29/2003 02:00 - 02:30 0.50 DRILL N DPRB PROD1 12262' (corrected), 02:30 - 03:50 1.33 DRILL N DPRB PROD1 Directionally drill f/ 12262' to 12270'.. up wt 26.7k dwn wt 11 k 1,50 / 1,50 3200 FS 3520 on btm (still old FP in hole) 3.1 WOB drilling off 10-12fph to 12265'. Stacking wt again. Back off pump to 1.3 bpm 2900 FS 3290 on btm . Increase to 1.4 bpm and on btm pressure> to 3670 psi. Flat line P-rate Do a rate vs psi while off and on bottom. Motor appears weak and can stall it with <500psi differential pressure. 03:50 - 06: 15 2.42 DRILL N DFAL PROD1 TOH 06:15 - 08:00 1.75 DRILL N DFAL PROD1 LD Baker extreme motor. Send off to shop for inspection. MU replacement motor (1.1 degree with Hycalog bicenter bit) 08:00 - 09:30 1.50 DRILL N DFAL PROD1 RIH with lateral drilling assembly. 09:30 - 09:45 0.25 DRILL N DFAL PROD1 Log gr tie in from 11540' (bit depth) Subtract 6' correction, 09:45 - 12:30 2.75 DRILL P PROD1 RIH to TD. Hole smooth. Drill ahead. Still seem to be in hard spot. Getting strong motor stalls. Drilling ahead very slow from 12270'. 3200 psi fs @ 1.6 bpm. 12:30 - 17:00 4.50 DRILL P PROD1 Drilling ahead. 3200 psi fs@1.6 bpm. 400 dpsi. Full rtns, ROP:30-40 fph.WOB:2000#. Drill to 12387'. Stacking weight when WOB exceeds 2000#. 17:00 - 18:00 1.00 DRILL P PROD1 Drill to 12426'. 18:00 - 19:20 1.33 DRILL P PROD1 Wiper trip to window 19:20 - 00:00 4.67 DRILL P PROD1 Drilling ahead. 40-60 fph, Continues to stack wt after driling several ft. Play with WOB without finding one particular wt that is better 1.6 bpm in/out motor work 300-700 psi over free-spin, Frequent small 200' wiper trips helping more than anything. Drilled to 12564'. Actual on-bottom time for bit 11.45 hrs. Total time on this motor 13.75 hrs. 1/30/2003 00:00 - 01 :05 1.08 DRILL P PROD1 Wiper trip to 10580'. 01 :05 - 04:50 3.75 DRILL P PROD1 Directionally drill f/ 12564' to 12700'. 1.6bpm in/out 3450 free-spin, 3600-3850 on bottom 2-4k wob. Short 100' wiper trips. 3.5 hrs on bottom drilling 04:50 - 06:00 1.17 DRILL P PROD1 Wiper trip to 11800' 06:00 - 07:30 1.50 DRILL P PROD1 Drilling ahead. 3250 psi fs at 1.58 bpm. 500 dpsi. Full rtns. WOB:2.5K# - 3.0K#. ROP: +/-40 FPH. 07:30 - 07:45 0.25 DRILL P PROD1 300' wiper trip. Hole smooth. PU clean. 07:45 - 10:30 2.75 DRILL P PROD1 Drilling ahead. ROP:30-40 fph 10:30 - 11 :30 1.00 DRILL P PROD1 Wiper trip to 11560'. Hole smooth. 11 :30 - 13:45 2.25 DRILL P PROD1 Drilling ahead. 3650 psi fs @ 1.73 bpm. 600 dpsi. Full rtns. WOB:3K# ROP: 70-90 FPH. Drilling has really picked up. Not sure why. Holding off on mud change while drilling at high rop. 13:45 - 18:00 4.25 DRILL P PROD1 Drill ahead to 13132' 3800 psi fs @ 1.8 bpm. 350 dpsi. Full rtns. WOB: 1000#. ROP:50-70 fph. Continuing to drill ahead smoothly. Short trip to window every 100'. 18:00 - 19:00 1.00 DRILL P PROD1 Wiper trip to window. Hole smooth. Start swap to new 8.6ppg Flo-Pro Light w/6ppb Klaguard, 2% Lubetex 40k cps. Returned 350 bbls old mud to MI 19:25 - 20:05 0.67 DRILL P PROD1 Drill ahead to 13152' 3710 psi fs @ 1.6 bpm. 350-450 dpsi. Full rtns, WOB: 2-3k. ROP:40-50 fph, Good drilling then stacks out. Either fight it or make a short wiper trip. Wiper has better results and quicker overall. 20:05 - 20: 15 0.17 DRILL P PROD1 Short 100' wiper trip, 20: 15 - 22:20 2.08 DRILL P PROD1 Drill ahead to 13234' 3650 psi fs @ 1.7 bpm, 500 dpsi. Full Printed: 2/10/2003 11: 17: 1 0 AM ) ) Page 5 ofa BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 15-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Gode NPT . Phase 1/30/2003 20:15 - 22:20 2.08 DRILL P 22:20 - 22:40 0.33 DRILL P 22:40 - 23:05 0.42 DRILL P 23:05 - 23:30 0.42 DRILL P 23:30 - 00:00 0.50 DRILL P 1/31/2003 00:00 - 00:40 0.67 DRILL P 00:40 - 01 :30 0.83 DRILL P 01 :30 - 01 :50 0.33 DRILL P 01 :50 - 02:50 1.00 DRILL P 02:50 - 03:30 0.67 DRILL P 03:30 - 05:50 2.33 DRILL P 05:50 - 06:00 0.17 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 09: 15 2.25 CASE P 09:15 - 11 :15 2.00 CASE P 11:15-13:00 1.75 CASE P 13:00 - 14:00 1.00 CASE N 14:00 - 15:30 1.50 CASE P 15:30 - 16:15 0.75 CASE P 16:15 - 16:45 0.50 CASE P 16:45 - 17:15 0.50 CASE P 17:15 -18:00 0.75 CASE P 18:00 - 18:45 0.75 CASE N 18:45 - 19:45 1.00 CASE N 19:45 - 23:00 3.25 CASE N PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP SFAL COMP COMP COMP COMP COMP COMP COMP COMP COMP 23:00 - 00:00 1.00 CASE P COMP 2/1/2003 00:00 - 01 :00 1.00 CASE P COMP 01 :00 - 03:40 2,67 CASE P COMP Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 Descri ption of Operations rtns. WOB: 2.5k. ROP:50-70 fph. Short 300' wiper trip. Drill ahead to 13259' 3650 psi fs @ 1.7 bpm. 500 dpsi. Full rtns. WOB: 2.5k. ROP:50-70 fph. Short wiper 250'. Drill ahead to 13285'. 3780 psi fs @ 1.74 300-400 dpsi Full rtns. Slide time last 24 hrs: 20.33hrs. Motor time total: 37.75 hrs Drill ahead to 13295' 1.74 bpm full returns. 3-4k wob 3780 fs 400 on btm. Stacking out. Wiper trip to 11545'. Log tie-in to RA tag +16' correction. Wiper to bottom. Tag bottom at 13308'. Call this TD Wiper back to window at 25'/min TOH Stab-off injector. Start to LID BHA LD and clean pu Baker & other BHA tools. RU and to displace eline coil to 60/40 meth. RU to unstab coil using winch and cable. Hold PJSM before ops. Spool coil back onto reel. Secure same. Prep to drop reel from reel house. Install slip type plug on e-line reel before removing from reel house. Had problems with slip type connector. Fabricated replacement parts on rig. Drop e-line coil onto flat bed truck, PU and install 2" coil. RU hardline & secure reel. RU and stab coil into injector using hydraulic tugger & slip type connector. (very slick) RU to circulate coil. Circulate 25 bbl methanol into coil. There's an ice plug in the coil. Maintain pressure on coil and allow to thaw in reelhouse. TL and crew change meetings. (Thawing coil). Make-up tools to run and drift 2 3/8" STL liner. (thawing coil holding 4000 psi on coiL). Ice plug gave way. Pump another 17 bbls of water then pressured up. Believe ice plug between reel and injector. Hold PJSM to discuss options. Bleed off pressure. Attempt to RIH open ended but not able to clear BOP stack. R/U to cut coil. R/U hyd coil cutter to injector. Clear floor of personnel and cut 104' of coil. Ice plug was within this length. Position end of coil over sump hole and start circulation. Circulate warm freshwater thru coil and flush methanol to cuttings tank. RID cutter and make hand cut. Load foam "pig" into coil and pump thru. Weld on Baker CTC wi 1.06" ID PT to 3500 psi and pull to 30k. Load and pump 4 fin coil wiper dart @ 1.4 bpm. Hit catcher after pumping 40.6 bbls, But dart failed to pass CTC, Reattach dart catcher, pressure up to 3700 psi before dart went through CTC. Retrieve dart. Suffered substantial damage. Wiper fins completely torn apart, Impact damage to nose was as expected. Discuss problem with BOT. Will pump a different Printed: 2/10/2003 1117: 1 0 AM ') ) Page 6 of 8 BPEXPLORA TION Qperations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 1 5-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From .;.To Hours Task Code NPT Phase 2/1/2003 01 :00 - 03:40 2.67 CASE P CaMP 03:40 - 03:50 0.17 CASE P CaMP 03:50 - 09:30 5.67 CASE P CaMP 09:30 - 10:30 1.00 CASE P CaMP 10:30 - 14:00 3,50 CASE P CaMP 14:00 -15:00 1.00 CASE P CaMP 15:00 - 16:30 1.50 CASE P CaMP 16:30 - 16:45 0.25 CASE P CaMP 16:45 - 17:45 1.00 CASE P CaMP 17:45 - 18:45 1.00 CASE P CaMP 18:45 - 20:00 1.25 CEMT P CaMP 20:00 - 21 :45 1.75 CEMT P CaMP 21 :45 - 22:30 0.75 CEMT P CaMP 22:30 - 23:00 0.50 CLEAN P CaMP 23:00 - 00:00 1.00 CLEAN P CaMP 2/2/2003 00:00 - 01 :30 1.50 CLEAN P CaMP 01 :30 - 03:30 2.00 CLEAN P CaMP 03:30 - 04:00 0,50 CLEAN P CaMP 04:00 - 06:00 2.00 CLEAN P CaMP 06:00 - 06: 15 0.25 CLEAN P CaMP 06:15 - 09:00 2.75 CLEAN P CaMP 09:00 - 11 :15 2.25 CLEAN P CaMP 11:15 -13:30 2.25 CLEAN P CaMP 13:30 - 16:00 2,50 CLEAN P CaMP 16:00 - 17:30 1.50 CLEAN P CaMP 17:30 - 18:00 0.50 BOPSUR P CaMP 18:00 - 18:20 0.33 BOPSUR P CaMP Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 DesctiþtionofOpèratiòns design dart with only 2 wiper fins. Load and pump 2nd dart @ 1.4 bpm. (same time prep to run liner) Dart hit at 41.0 bbls PJSM discuss liner running procedures and drifting of connections. P/U 71 jts of 2.375" 4.43# L-80 STL liner. Drift each connection with 1.875" rabbit. (review safety procedures handling drift pipe) MU liner running tool. Stab on well. RIH with liner. Up wt at 11500': 29.5K#. Continue in hole. Had to work to btm from 12650' on down. Circ at min rate to clean up hole. Finally worked to btm. Add 5' corr. TO at 13308' . Drop 5/8" aluminum ball. Cir to LBRT tool. Ball on seat at 35 bbls (coil volume 41 bbls). Pressure and shear tool at 3850 psi. PU. Liner free, up weight 26K#. Begin displacement to 2% KCL water. Full rtns. Begin to RU cementers, Hold tool box safety mtg to discuss cement job. Water all the way around. 1.0 bpm @ 1070 psi. Mix cement in batch mixer. Mix 2# bio in pits. Recover 300 bbls mud from well & pits. Wait on crew change before pumping cement. Hold second PJSM to discuss job with night crew. PT lines to 4k. Pump 9.5 bbls 15.8# LARC cement. Load and launch CTWD. Displ wi 40.6 bbls 2# bio-water. Dart hit LWD on schedule and released with 3800 psi. Follow with additional 8.5 bbls displ and LWD hit on schedule with 50.7 bbl total displacement. Displ pressure 2380 at start finishing with 4400 psi. CIP @ 1950 hrs. Stab out of liner and lay in #2 bio-water 1:1 from top of liner to surface LID Baker CTLRT. P/U 2.125" motor for 3.5" tbg cleanout run. Replace pawl in levelwind. P/U injector RIH Continue to RIH. Bring pump on line at 1.25 bpm at 10800', Never seen any weight or motor work. Tagged top of liner (twice) at 11063' coil depth. (At 0100 hrs Dowell called to report cement at 600 psi compressive strength and climbing rapidly). Trace amount of cement of micro motion out density. TOH (PJSM plu 1" hydril) Setback injector LID BHA #8. Rig up and run BHA #9 Hold PJSMrrech limits with day crew. Continue to PU 1" CSH & liner clean out assembly. RIH. Clean out 2-3/8" liner. Tag soft cement at 13200'. Clean out to 13270 PBTD. 9K# down, 29.6K# up wt. 1800psi fs @ .93 bpm. POOH with motor & mill. At surface. Drop ball to open circ sub. Stand back CSH. MU swizzle nozzle. Get on well and jet out BOPs. Get off well. RU grease crew, Prep for BOP test. Crew change. And PJSM with oncoming crews on testing Printed: 2/10/2003 11: 17: 1 0 AM ') ') BP,'EXPLORATION OpørationsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 15-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 From ""To· Hours Task Code NPT· Phase Description of Qperations 2/2/2003 18:00 - 18:20 0.33 BOPSURP COMP BOPE. Grease crew doing all tree/manifold valves. 18:20 - 22:30 4.17 BOPSURP COMP Test BOPE 350 psi low, 3500 psi high. Check pre-charge on bottles and perform accumulator drawdown test. 22:30 - 23:20 0.83 CASE P COMP Cap off lubricator at floor level. Open swab/master valve. Well had 50 psi on it, bleed off. Fill stack with charge pump. With rig pump run up pressure on casing to 2050 psi. Double block all valves. Charted pressure after 30 min 1970 psi. PJSM while testing discussing BHA #10 and 1" pipe handling procedures 23:20 - 00:00 0.67 EVAL P COMP P/U CCLlgr and BHA #10 2/3/2003 00:00 - 02:00 2.00 EVAL P COMP Finish picking up BHA #10, Stab injector 02:00 - 03:35 1.58 EVAL P COMP RIH to 10750'. 03:35 - 05:00 1.42 EVAL P COMP Start logging CCL/gr tagged at 13271' coil depth. Start logging up 50'/min and laying in new Flo-Pro perf pill 05:00 - 06:45 1.75 EVAL P COMP POOH with logging tools. 06:45 - 09:00 2.25 EVAL P COMP At surface, PJSM in ops cab. Get off well. Stand back 1" CSH. 09:00 - 09:30 0.50 BOPSURP COMP Test inner reel valve. OK. 09:30 - 09:45 0.25 PERF P COMP Hold PJSM before PU perf guns. 09:45 - 12:00 2.25 PERF P COMP Load pipe shed with 1-11/16" perf guns. RU to run guns. 12:00 - 14:30 2.50 PERF P COMP MU 63 guns. (1.56" HSD PJ 1606,4 SPF) 14:30 - 18:00 3.50 PERF P COMP RIH with perf assembly to 13270' PBTD pick up 18' off bottom. 18:00 - 19:00 1.00 PERF P COMP Drop and pump .500" ball, Ball on seat after rocking several times. Guns appeared to have fired at 2900 psi. 19:00 - 22:20 3.33 PERF P COMP TOH to 1" hydril. Set back injector. 22:20 - 22:30 0.17 PERF P COMP PJSM review handling 1" hydril. 22:30 - 23:00 0.50 PERF P COMP Stand back 14 stds 1" hydril 23:00 - 00:00 1.00 PERF N DFAL COMP Perf guns did NOT fire. Firinghead was triggered as expected but failed to fire due to being wet. Break off 1 st gun and confirm that guns are flooded. O-ring seals on 10th gun out failed. Alert town engineer, plan forward is to wait for replacement guns to be loaded. Approximate wait time is 24 hrs. LID unfired perf guns. 2/4/2003 00:00 - 02:20 2.33 PERF N DFAL COMP Continue I/d perf guns and load out of pipe shed. 02:20 - 00:00 21.67 PERF N DFAL COMP Wait on perf guns. Inspect and grease injector head and chain. Clean rig. Load out equipment for rig move. 2/5/2003 00:00 - 00:30 0.50 PERF N DFAL COMP Wait on perforating guns, 00:30 - 00:45 0.25 PERF N DFAL COMP Pre Job safety PU perforating guns. 00:45 - 01 :00 0.25 PERF N DFAL COMP Load pipe shed. 01 :00 - 03:30 2,50 PERF N DFAL COMP PU guns 03:30 - 04:00 0.50 PERF N DFAL COMP PU 1" Hydril. 04:00 - 04:30 0.50 PERF N DFAL COMP Stab injector. 04:30 - 06:30 2.00 PERF N DFAL COMP RIH with perforating assembly. Slow down to 50fpm in the liner. Tag TD, PU to neutral at 13270.9 Same depth as last time. IA=111 psi, OA=48psi PHASE 1 Weather, blowing snow, 06:30 - 07:30 1.00 PERF N DFAL COMP PU, postition reel to launch 1/2" steel ball, confirm launch. Pump ball down at 1.4bpm. CT Vol=40.6 Hydril vol=1 bbl. Slow down to .75bpm, 800psi in CT at 30bbls, Circ press increase to 950psi in 1" Hydri slow displacement to .66bpm. Pump 42.2 bbls, no ball. Try to rock ball onto seat, bring rate to zero, quickly bring rate back up. Ball on seat. Slowly start Printed: 2/10/2003 11: 171 0 AM ) ') Page8of8 o perélti ons Summary RèpO rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 15-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/23/2003 Rig Release: 2/5/2003 Rig Number: N2 Spud Date: 5/24/2002 End: 2/5/2003 Date From - To Hours· Task· Code NPT Phase· Description of Operations 2/5/2003 06:30 - 07:30 1.00 PERF N DFAL COMP creeping OOH. Pressure up to 2800psi, guns fired. Bottom shot at 13250'. May have lost 2bbl of fluid. Looks like losses are healing. PVT= 125bbls. 07:30 - 09:45 2.25 PERF N DFAL COMP POH with perf guns at 50fpm. Perforated: 11870-12200' (330' interval), 12310-12520' (210' interval), 12670-12250' (580' interval). 1120' Total perforations (1.56" HSD PJ 1606, 4spf). 09:45 - 10:20 0.58 PERF N DFAL COMP PU injector, Unstab MHA, stand back injector. Hole is full. Circulate CT, circulate across the top. PU elevators, LD MHA. 10:20 - 10:30 0.17 PERF N DFAL COMP PJSM. Discuss standing back CS Hydril. Be aware of man in derrick, fall protection. Be aware of pinch points while breaking out CS Hydril with crummies. Leave one jt and stop job prior to getting spent guns to surface. 10:30 - 11 :00 0.50 PERF N DFAL COMP Stand back 13 Stands of 1" CS Hydril, LD one jt on pipe rack. Leave guns below floor on last jt. 11 :00 - 11: 1 0 0.17 PERF N DFAL COMP PJSM prior to pulling spent guns with Schlumberger perf specialits and rig team. Discuss trapped pressure, PPE, well control preparedness, cellar off limits, signs in cellar, minimize # people on rig floor, keep hole full, rolling spent guns on pipe rack to allow for drainage. 36.2hrs NPT due to flooded perf guns. 11:10-13:45 2.58 PERF P COMP LD spent perf guns. All guns fired. 13:45 -14:30 0.75 RIGD P COMP PU nozzle for freeze protect, postion injector. 14:30 - 15:30 1.00 RIGD N WAIT COMP Wait on loader to position methanol trailer, Nordic 2 loader broken down, 15:30-17:00 1.50 RIGD P COMP Freeze protect to 2200' with Methonal. IA=111 psi, OA=46psi. 17:00 - 20:30 3.50 RIGD P POST ND, install tree cap, secure BOPE inside cellar, clean pits. RELEASE RIG @ 20:30 Printed: 2/10/2003 111710 AM ) ) II.. B H IS [N'[EQ BP Baker Hughes INTEQ Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PBDS15 Well: 15..30 Wellpath: 15':30A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 3/12/2003 Time: 15:05: 17 Page: Co-ordinate(NE) Reference: Well: 15-30, True North Vertjcal (TVD) Reference: 44 : 30 8/4/1992 00:00 64~0 Section (VS) Rderence: Well (0.OON¡O.00E,47.00Azi) Survey Calcuhttion Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.236 N 148 34 21.213W True 1.34 deg Well: 15-30 Slot Name: 30 15-30 W ell Position : +N/-S 949.09 ft Northing: 5959811.01 ft Latitude: 70 17 44.570 N +E/-W 1060.96 ft Easting : 677335.32 ft Longitude: 148 33 50.290 W Position Uncertainty: 0.00 ft Well path: 15-30A 500292228201 Current Datum: 44: 308/4/199200:00 Magnetic Data: 1/20/2003 Field Strength: 57545 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 15-30APB 1 11556.00 ft Mean Sea Level 26.03 deg 80.83 deg Direction deg 47.00 Height 64.00 ft Survey Program for Definitive Well path Date: 3/12/2003 Validated: Yes Actual From To Survey ft ft 439.00 11556.00 1 : MWD - Standard (0) 11556.00 13308.00 MWD Version: 2 Toolcode Tool Name MWD MWD MWD - Standard MWD - Standard Annotation 11556.00 8771.29 KOP 13308.00 8775.13 TD Survey: MWD Start Date: 1/31/2003 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11556.00 67.85 32.09 8771.29 8707.29 5521.19 3915.75 5965422.69 681119.46 6629.24 0.00 11587.27 75.73 26,08 8781.07 8717.07 5547.13 3930.14 5965448.96 681133.24 6657.45 31.12 11616.98 85.73 20.78 8785.85 8721.85 5574.00 3941.76 5965476.10 681144.22 6684.28 37.97 11649.34 90.06 27.33 8787.04 8723.04 5603.50 3954,94 5965505.90 681156.69 6714.04 24.25 11679.27 92.82 34.95 8786.29 8722.29 5629.09 3970.39 5965531.85 681171.54 6742.79 27.07 11712.92 91.93 42.35 8784.89 8720.89 5655.33 3991.38 5965558.57 681191.90 6776.03 22.13 11740.95 90.71 46.35 8784.24 8720.24 5675.36 4010.96 5965579.06 681211.01 6804.02 14.92 11772.12 91,38 53.87 8783.67 8719.67 5695.33 4034.86 5965599.59 681234.42 6835.12 24.22 11815.38 89.63 56.29 8783.29 8719.29 5720.09 4070.32 5965625.18 681269.29 6877.94 6.90 11849.74 91.26 61.22 8783.03 8719.03 5737.91 4099.69 5965643,68 681298.23 6911.57 15.11 11890.13 93.56 65.38 8781.33 8717.33 5756.04 4135.73 5965662.65 681333.83 6950.29 11.76 11920.80 91.23 61.42 8780.05 8716.05 5769.76 4163.12 5965677.01 681360.89 6979.68 14.97 ) ) BP Baker Hughes INTEQ Survey Report ¡,NTliQ Company: BP Amoco Date: 3/12/2003 Time: 15:05: 17 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) .Reference: Well: 15-30, True North Site: PB DS15 Vertical (TVD) Reference: 44:308/4/1992 00:00 64~0 Well: 15-30 Section (VS) Reference: Well (0.00N,O.00E,47.00Azi) Wellpath: 15-30A Survey Calculation Method: 'Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11950.99 89.60 59.16 8779.83 8715.83 5784.72 4189.34 5965692.59 681386.74 7009.06 9.23 11983.15 89.05 51.74 8780.21 8716.21 5802.94 4215.81 5965711.43 681412.77 7040.84 23.13 12014.74 89.63 50.70 8780.57 8716.57 5822.72 4240.43 5965731.79 681436.92 7072.34 3.77 12047.70 90.00 46.54 8780.68 8716.68 5844.51 4265.16 5965754.15 681461 .12 7105.28 12.67 12077.94 89.54 45.06 8780.80 8716.80 5865,59 4286.84 5965775.73 681482.30 7135.52 5.13 12110.27 89.26 41.69 8781.14 8717.14 5889.08 4309.03 5965799.74 681503.93 7167.77 10.46 12146.89 90.00 37.28 8781.37 8717.37 5917.34 4332.31 5965828.54 681526.54 7204.07 12.21 12177.46 91.04 34.60 8781,10 8717.10 5942.09 4350.25 5965853.70 681543.89 7234.07 9.40 12205.81 91.38 31.14 8780.50 8716.50 5965.89 4365.63 5965877.86 681558.70 . 7261.55 12.26 12236.26 90.31 36.25 8780.05 8716.05 5991.21 4382.52 5965903.57 681574.98 7291.17 17.14 12277.94 92.24 41.97 8779.12 8715.12 6023.53 4408.79 5965936.50 681600.49 7332.42 14.48 12309.14 93.22 44.71 8777.63 8713.63 6046.19 4430.18 5965959.66 681621.33 7363.52 9.32 12347.41 93.25 54.78 8775.47 8711.47 6070,85 4459.30 5965984.99 681649.86 7401.64 26.27 12373.32 91.41 55.70 8774.41 8710.41 6085.61 4480.57 5966000.25 681670.77 7427.26 7.94 12405.33 90.89 62.48 8773.77 8709.77 6102.04 4508.01 5966017.32 681697.82 7458.53 21.24 12440.96 90.46 67.35 8773.35 8709.35 6117.14 4540.27 5966033.18 681729.71 7492.42 13.72 12470.29 91.17 69.47 8772.93 8708.93 6127.93 4567.54 5966044.61 681756.71 7519.72 7.62 12500.20 90.55 65.67 8772.48 8708.48 6139.34 4595.18 5966056.66 681784.07 7547.72 12.87 12532.56 91.90 63.93 8771.79 8707.79 6153.12 4624.45 5966071.12 681813.01 7578.52 6.80 12561.36 87.85 61.65 8771.86 8707.86 6166.28 4650.05 5966084.89 681838.30 7606.23 16.14 12595.32 88.50 60.73 8772.94 8708.94 6182.64 4679.79 5966101.94 681867.64 7639.13 3.32 12629.92 88.10 53.38 8773.97 8709.97 6201.43 4708.80 5966121.42 681896.19 7673.16 21.26 12661.76 90.03 48.10 8774.49 8710.49 6221.57 4733.44 5966142.13 681920.35 7704.92 17.65 12694.80 93.65 41.21 8773.42 8709.42 6245.04 4756.63 5966166.14 681942.98 7737.89 23.54 12724.21 91.75 37.31 8772.04 8708.04 6267,78 4775.22 5966189.31 681961.02 7766.99 14.74 12772.90 89.45 27.85 8771.53 8707.53 6308.76 4801.40 5966230.89 681986.23 7814.09 19.99 12806.90 90.37 20.24 8771,58 8707.58 6339.79 4815.24 5966262.24 681999.34 7845.37 22.55 12839.68 92.61 26.01 8770.73 8706.73 6369.91 4828.11 5966292.65 682011.48 7875.32 18.88 12871.79 93.62 28,16 8768.98 8704.98 6398.45 4842.70 5966321.53 682025.40 7905.46 7.39 12908.44 91.35 28.76 8767.39 8703.39 6430.64 4860.15 5966354.12 682042.08 7940.18 6.41 12942.40 89.88 30.51 8767.03 8703.03 6460.16 4876.94 5966384.02 682058.17 7972.59 6.73 12975.03 89.75 36.26 8767.13 8703.13 6487.39 4894.89 5966411.67 682075.4 7 8004.29 17.63 13033.37 89.05 55.70 8767.75 8703.75 6527.74 4936.64 5966452.98 682116.25 8062.33 33.34 13066.99 90.21 57.72 8767.97 8703.97 6546.19 4964.74 5966472.09 682143.91 8095.47 6.93 13097.39 90.12 60.56 8767.88 8703.88 6561.78 4990.83 5966488.29 682169.63 8125.19 9.35 13130.36 89.14 69.83 8768.09 8704.09 6575.60 5020.73 5966502.81 682199.18 8156.47 28.27 13160.25 87.48 75.96 8768.98 8704.98 6584.38 5049.27 5966512.26 682227.51 8183.34 21.24 13190.58 88.10 80.73 8770.15 8706.15 6590.50 5078.94 5966519.08 682257.03 8209.21 15.85 13220.16 86.99 85.77 8771.41 8707.41 6593.97 5108.28 5966523.25 682286.27 8233.04 17.43 13250.64 87.70 81.66 8772.83 8708.83 6597,31 5138.54 5966527.29 682316.44 8257.44 13.67 13308.00 87.70 81.66 8775.13 8711.13 6605.62 5195.24 5966536.94 682372.93 8304.58 0.00 BP Amoco F&.. ~~~~~~: {~~r~~jr~~]~Teq.c~m 831<9:f Hughes ¡NTEQ~ {f:J07Ì 257-E-i..:;'Üf} LEGEND T 1~'lfs:3~~,Plan/;102 ^ M 15-30 (15-30APB1) A 15-30A ' é Wellpath: (15-30/15-30A) Azimuths to True North Magnetic North: 26.03· Magnetic Field Strength: 57545nT Dip Angle: 80.83· Date: 1/20/2003 Model: BGGM2002 Created By: Blij Potnis Date: 3/12/2003 Contact nf0rrn3li(jn~ Parent Wellpath: Tie on MD: WELLPATH DETAILS 15-3OA 500292228201 15-30AP B 1 11556.00 lNTEQ Rig: Ref. Datum: Nordic 2 44 : 30 8/411992 00:00 64.0ot! V,Sectlon Origin Origin Angle +N/-S +E/-W 47.00' 0.00 0.00 Starting From TVD 0.00 REFERENCE INFORMATION ANNOTATIONS TVD MD Annolalion 8707.29 11556.00 KOP 8711.13 13308.00 TO 6700-~: : . / · .... .. ..... ... ..... I .. ... ......~.. ........ ......... ..... 660¡r: : · . 1 '~~~'~ïmu'II_~ ¿--- .... . · ~500-: · I ./// /Î / .LIQJ . - · ~a · : · · . : . · i~, /·/"'7 II · . 4~ · ........... '. :. · · ... ....... ... m... ... .. .m.. .... m. . .....m. ... ...... .. · : . / /. , 1/ .' ~6300--= , · : . ......... .. i . · . ~200-~ · · /1 Y' · . · .---: ' - ~:i .' . ... ....... ...//> I~/ .... ..... ... . :6100~ , .. .. m, .... ......... .. ,. .... .m. ; · . .. ~6000= .. .... .. · ... ./ .......... .... .... ~ · / / j! ~ .5900= ... ...... .... ............ ....... ... .. · · ...... ..... . , I . : : : ......m C 5800= ........ ...... .. m .... /4 ï' .'. ..' m ....... . ... ... . .. ...... .. .. .,. .. .. .. .... ....... .... .... ... : ...................... ..... ..........., ..:. m '.. '.' . ...... .... .... .. ~~^^ V'vv . · lV // · . . · : · .... · , : ..:. .. . · ~^^^ .. .... ... .. vvvv · Þ · . · · 5500 · .... ...: ...... ... · .. : . · · · . '" , ..>">vv , 'j - I : , · , : . : · ,,"vv , . / .. . · : .: : · . . , , JO ;1'~O 3~ )0 '3'3'00 34 . ". . . . JO . ¡ " .' ···~:o~·· '~'60'~" ~~'~o' ~'9 : JO .. ! 30 0035 00 3600 38 4000 4100 4200 4300 JO 50 5~ )0 5~ )0 54 )() 5E )0 5f 00 -~ Co-ordinate (N/E¡ Reference: Well Centre: 15-30. True North Vertical (ND Reference: System: Mean Sea Level Section (VS Reference: Slot - 30 (O.OON.O.OOE) Measured Depth Reference: 44: 30 8/4/1992 00:00 64.00 Calculation Method: Minimum Curvature 000 5.e191$ .t231 U Pd',.gon 000 6')1132 "27039 PdJ'P1 :;~ª rnÍli ill!!! ~ j[mlmr~ 1 8150 8200 8250 ~300 æ8350 o ~400 .c 'S,a450 CÞ Q 8500 1i .!:! 8550 1:: ~ 8600 28650 ... 8700 West( -)/East( +) [100ft/in] c~ 8800 .~.~ j ~~~ 8750 8850 Vertical Section at 47.00° [50ft/in] 3/12/2003 3:03 PM ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 15-30APBl Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary ¿}Od-O 'öj 115ft '&1. lL..~:u~'::;::--~J: BAKER :_~ ...'~'''~;. ., ..., HUGHES :" "'''''' .... i~' :~: "'..,,~:. i~-;~"""" ';7;'"'' "~'-" ~~,., ~~ Anchorage GEOScience Center ) ::::: ~i..?' r -. ~.~ ¡. §§=S; , """"I: a¡¡..,:' \1r1\lt' r'=~~ . - '::,:("~~,::,~~:' ~~.". ,,~~ t=~:·"· ·"ffi~:···-·~·· .~~., -r~~ ~~~·T--:::::'-~ --_...,,"'~....._..~ 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 LAC Job#: 280415 Sent By: Glen Borel ReceivedB~ 4- ~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 1'...'......."-.,.:..... Date: Mar 3, 2003 Date: t~'\~:3';7 ; - ~.,,~- RECEIVED ~~ __ø__~·_·· MAR 04 2003 AlaeIœ œ & Gas Cons. Commiaeion Anchorage .-- ) ) Distribution Letter r&.. BAKER HUGHES INTEQ Anchorage GEOScience Center Reference: Re-distribution of 15-30APB 1 logs & data. This wellbore reached TD (Total Depth) on 01-Jun-02. At that . time, the wellbore was identified as 15-30A with API number 500292228201. I The data for this wellbore is being redistributed at this time. The data presented here is final and has been corrected per instructions from BP , Exploration (Doug Stoner). An error was made during acquisition I regarding a depth tie-in between two bit runs. This resulted in an 18' interval being logged and displayed twice. Gamma Ray data from 11492 - 11510' MD was removed with data below 11510' MD being shifted up 18' . Subsequent to the original completion and distribution of logs on this wellbore (June-02), this hole section was plugged back and a new wellbore was drilled. Standard Alaska naming conventions dictate that the original 15-30A wellbore be renamed to 15-30APB 1 with a corresponding API number of 500292228270. Since data from this well was being redistributed for a depth correction, the well name and API number were corrected as well to reflect this wellbore's current plug back status. Logs and LDWG CDs included here are identified as 15-30APB 1 and are depth corrected replacements for original logs and data distributed as 15-30A. Glen Horel LWD Data Analysis Manager Baker Hughes Inteq c5l{)d-O~C¡ II 57? l-I._.--~~:~:~;~:~=~--_.-- I ~':1'(",:¡, :[~~r~¡" q""~ :0'~'" ''''.,~' """''''';~'''-''::~'-'''''7'"~ -... i· i ~fj§ i~--P~'L:~,:,rr(a(l.:I. ¡,:u,,!~~.,.. .,.=,~;,. '. ..~.... ,,~:~ ,,-,.:,~~ !::i;",,, m~~·~ "·~;dU~~' .:~~ ~~:~ i .-.".,.. ~ lli;·¡': .~~,I,.~~~~../: ._.___..,_..n,__'_' i' . ~ -' ,r,+~', ",-", :",,. _.~,. ,.,-~-,------,. -'--~--~- :"'.~ :ffi¡::L:.,¡¡:': : - ...-- RECEIVEã~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 MAR 0 4 2003 AJaaka Oil & Gas Cons. ComrniMion Anchorage ·'r. I.^-i 6 A- 12-/ Z 3!6J·7.-- ,M,~ I )...ll"J/D~ ) Z / 2 1- ÞZ3' ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: D Abandon D Suspend D Plugging D Time Extension D Perforate D Alter Casing D Repair Well D Pull Tubing D Variance aa Other / D Change Approved Program D Operation Shutdown D Re-Enter Suspended Well D Stimulate Re-Enter Ops Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: II Development D Exploratory D Stratigraphic D Service 6. Datum Elevation (DF or KB) RKB = 64' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1702' SNL, 1390' EWL, SEC. 22, T11N, R14E, UM At top of productive interval NIA At effective depth 4334' NSL, 221' EWL, SEC. 14, T11N, R1i4E, UM At total depth 4899' NSL, 925' EWL, SEC. 14, T11N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 8. Well Number /' 15-30A 9. ,Permit Number '/ 202-089 I 302-182 10. API Number 50- 029-22282-01 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool measured true vertical 13083 feet 8768 feet 12135 feet 8780 feet Plugs (measured) 2-3/8" Liner full of cement, cleaned out to about 12135', where the first BHA became stuck. Effective depth: Junk (measured) Liner Cut at 11610'; Top of Liner Fish jarred to about 10960, Bottom at about 11514' Casing Structural Conductor Surface Intermediate Production Liner Liner Length Size Cemented MD TVD 80' 20" 3801' 13-3/8" 10535' 9-5/8" 1271' 7" 2027' 2-3/8" 2880 cu ft CS III, 1326 cu ft 'G' 110' 3838' 110' 3522' 2543 cu ft Class 'G' 10568' 487 cu ft Class 'G1 10263' - 11534' 10 cu ft Class 'G' 11610' - 13083' (Estimate roc in annulus 1. re E I V E D 8299' 8119' - 8764' 8790' - 8704' Perforation depth: measured None Tubing (size, grade, and measured depth) ~ g 0 M S B F l DEG 3 I M::tska Oil & Gas Cons. Commtssto.n 4-1/2", 12.6#, L-80 to 34'; 3-1/2", g.'31r, 13Cr80AROl1tm{ge 4-1/2", 12.6#, L-80 to 11043'; 3-1/2",9.3#, 13Cr80 to 11534' Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker 'SABL' packer at 11036'; 3-1/2" Cameo 'TRDP-4A-SC' SSSV Nipple at 2111' true vertical None DEC 12 2002 13. Attachments II Description Summary of Proposal D Detailed Operations Program 15. Status of well classifications as: II Oil D Gas D Suspended D BOP Sketch 14. Estimated date for commencing oper~ion January 1, 2~9Z? 16. If proposal was verbally approved Service Name of approver Date Approved Contact Engineer NameINumber: Alistair Sherwood, 564-4378 17. I ~erebY certify that the f, or~?. Oim"g, ~1rue,an, d. C,o, rrect t,o" ,t~.e b" 'est. '0. f ~y,.., k. n,o., W."I~, d" ge" Signed Alistair Sherwood IV', ye Ji..::I::PJ _ Title CT Dnlhng Engineer -i\'\,r",.,..·'". ",. ......." \:::",,¿~\,.·,~;!:~q~~;:~':·~Mlj,",.y~~;:;! .':.. ··I,{i::<:.')\·~ ',':: ::C·· Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test L Location clearance _ Me.chaf.1icallnte~rity Test _ ~ Subsequen.t form r~q~íred 1[0-. ':(07 1\ J l Pi D 2~' 'Z- - D ~ C( [')i r'- K-l..-l t- S't'l f (.,( C-l. l¡,c.. ~ Approved by order of the Commission ORIGINA ~1~NF=n RY Form 10-403 Rev. 06/15/88 M t. ~n~; . Prepared By NameINumber: Terrie Hubble, 564-4628 Date io/r¿~2- . ;" , ~ ,:','\ ",': , : ,.:1. ~:' I. ~ Approval N0,<-3 c?;2 -- .3 ð: 3 T~:-{¡ j$cJ PE b "5SM f i { . ~Pfl(.,¡. /~!~I /1 'Î Commissioner Date /t>*1.-?! Y/{),-~ Submit In Triplicate 1\, ) ) bp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Alistair Sherwood CTD Engineer Date: December 11 th, 2002 Re: CTD Sidetrack of well 15-30 j" In May 02, 15-30a w~ drilled as a 3" OH sidetrack by Nordic 1. At TD on the 1st June, 2%" liner was run to bottom with ease. Difficulties commenced during the 8bblliner cement job. With just 1 Y2bbls out of the shoe, circulation packed off and was never regained. The subsequent clean-out BHA, found the liner wiper plug 85' above the window. This was milled out, as was the underlying cement to 565' below the/ window. At this point the milling BHA became stuck, and was disconnected from the coil and left in hole. /" Since the shutdown of operations on the 6th June, the 2%" liner has been cut at 11,610', (75' below the window) and lifted 130'. With a swap from 33A" to 3" OH operations by Nordic 2 at the Year End, Nordic 2 will return to 15-30. Before drilling operations commence, Nordic 2 will undertake the following prep work. 1. Recover -570' of 2%" , from the cut point at 11,610' . / .,/' 2. Lay cement in 3", 75', OH, washing bas,~"Gtc)wnt9 the dual 3Y2 x 7"window. 3. Kick off from cement plug, drill f0L:~ Nordic 2 will likely arrive on D815 on the 1 st / 2nd week in Jan 03. Note: The new directional plan is to the original reservoir target and as such does nord~viate from the ~,. original plan by more than 500ft. The existing Permit to Drill, (10-401) Numb~'ó2~~9, approved 5/2/02 therefore remains valid. Y"" /í//<,<l . / ¡~kloL. ftt(i~{J{~r:!\ Alistair Sherwood CTD Drilling Engineer CC: Well File Terrie Hubble · TREE~~ FMC WB.LHEAO = McEVOY Aè1ÜA TOFf;'OTiS 70 UI-f2202 KïI-liË\r;;-....······~..··,·..··_..··..···,·'''_····'-·-6¡ï BF. REV = _..........."..',...'...~..,......."._..,......._.,....,'.~'. KOP = 1286' "Max 'Anglè ~.. ,. ~~~~,~~~~ '5ãiûm"MO ~...."... 12116' Dätuñiwo;;-'''''''''''''''''''''''''''''SSÕÕ;'SS' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 34' c.,\.l_~n+ 15-30A 13-3/8" CSG, 68#, L-80, 10= 12.415" 1-1 3838' ~ I TOP OF 7" LNR 1-1 10263' 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 10568' Minimum ID = 13-1/2" TBG, 9.3#, 13-CR-80, FOX, 0.0087 bpf, 10 = 2.99" 110'-1" strip charge, 3'-1 11/16" bar wI guide shoe I Top of 2 318" Liner I Punch Tubing 11 11032' 11043' 11056' 1-1 11100' I Low side 2 string window from W/S 1-1 11534' I 3-1/2" TBG, 9.3#, 13-CR-80, FOX, 0.0087 bpf, 10 = 2.99" 11632' I ÆRFORA TION SUMMt\RY REF LOG: GRJPDC 11/01/92 ANGLE AT TOP PERF: 59 @ 11002' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE ..1 !4 C ,,,- í ') r)n2· '1 1 OOC; S '1 O/¿ij¡q¡ 2..1/2" f:~ Î ! ...1. }'O~ 1 1 ::,;;;(:; ,,) ! 1 (:H~~) . , 2· 1 !2~1 l) '! . SBO.. 1 '. 60C (¡ 1 'I 0>99 , . . 2- ii/..· 1 '1 :)96·· 1 î bSb (0' O~ì:U'1 /~)9 "J 2- <"! :.'~ ,. ,~ /36· 1 ¡ //G () O~)!(':5/H3 i ; ~.. /', '1/2': ~) Î ?:> /b· ! LA:)': 0 ()~~!O¡:~!93 ::;L 'j ?t);:;t.~.. 12::i/ ;- () 09!C4·'9:? SL , .~ 2\~7(j.. . 2~17() 0 O~)iC·1 /8~~ ~ I ifD""I".:,:,:, :,:,\,'., i: t---..4 ,¡ I I~,.'.<~,~, ; :~ .. / \) 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, D = 3.958" 1-1 13000' -AI ~ DATE REV BY COMMENTS DATE REV BY COMMeoITS 09/06192 ORIGNAL COMPLETION 05/17/02 MSE PROPOSED SDETRAO< 09/05193 LAST WORKOVER 06/06/02 MSE FISH 12/18/00 SIS-IsI CONVERTED TO CANVAS 02/14101 SIS-MD FNAL 01/09/02 RWTP CORRECTIONS f ) 'ØTES: LDL INDICATES 7" LNR LAP LEAK @ 1 \. .' ' '. '- ,;.IIENTED 4/3/98. CMT COLLAR 2.76" ID FROM 9600' TO 11032' REMOVED WHEN (8/99) RlH, MILL SWNTO 2.81". 34' 1-1 4-1/2" X 3-1/2" XO 1 2111' 1- 3-1/2"CAMCOTRDP-4A-SC SSSV NIP, 10 = 2.812" GAS LIFT Mt\NORB.S ST MO ìVO OEV lYPE VLV LATCH PORT OA TE 1 3405 3195 39 MMG RK 2 6544 5479 44 MMG RK 3 8615 6997 44 MMG RK 4* 10023 7971 44 MMG RK 5* 10147 8049 52 MMG RK * B8-IINO CMT SHEA TIi 11014' 1-1 3-1/2" OTIS XN NIP, 10 = 2.813" I 11036' H 7" X 4-1/2" BAKERSABL-3 PKR, 10 = 3.930" 11070' 1-1 3-1/2" PARKER SWS NIP, 10 = 2.813" 11100' 1-1 Top of Cement 31/2" x 7" I 2-3/8" 4.7# ST-L Cemented & Perf'ed liner -1 13300' " ~""1 \ 7,·'1'·".',~, /' .... '111'. '! f ' 12600' 1-1 Top of Cement (calc) I " "- 12100' 1-1 ~/16" motor and 1.875" 0331 mill I 12653' 1 7" LNR, 26#, NTSOS, NSCC, .0383 bpf, 10 = 6.276" PRUDHOE BAY UNIT WB.L: 15-30A PERMIT No: 202-089 API No: 50-029-22282-01 SEC 22 T11N R14E, 4264.77 FB. 20.07 FNL BP exploration (Alaska) ¿ TREE !::: FMC WaLHEAD = McEVOY Äê"ruÃTOFf;"õfìS'7ÓTjH"'2'2Õ2 KïfEl'B/;;;; .... ........ ... ....... . ..... "'64; SF. B..EV = ...'''''.........."........'''·,''__.,......,,.....,·,·,·...........·,w'''''·....._................,., í(õp';;"'"'''' 1286' .. ~ -. - -. .. - - ~~!'..~.gl~..~ ' ~~.~ 1~~~6' Datum MD = 12116' .......',.........."....... . "......,....................... Datum TVD = 8800' 55 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 34' ) 15-30A Proposed CrD Sidetrack J - 13-3/8" CSG, 68#, L-80, 10 = 12.415" 1-1 3838' ~ 1 TOP OF 7" LNR 1-1 10263' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10568' ~ Minimum ID = 3-1/2" TBG, 9.3#, 13-CR-80, FOX, 0.0087 bpf, 10 = 2.99" 1- 11032' Tubing Punch Top of 2 3/8" Liner 1-1 11056' 1-1 11100' 1 Low side 2 string window from W/S 1-1 11534' 1 13-1/2" TBG, 9.3#, 13-CR-80, FOX, 0.0087 bpf, 10 = 2.99" 11 11632' I PERFORATION SUMMARY REF LOG: GRlPDC 11/01/92 ANGLEATTOPPERF: 59 @ 11002' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 'I 1002 11 í)Oh .., " ~::. ,. "" ~ :·>h!£;.. j >~)f'~,_~ 11036' 1-1 7" X 4-1/2" BAKER SABL-3 A<R, 10 = 3.930" 11070' 1-1 3-1/2" PARKER SWS NIP, 10 = 2.813" .. 11100' 1-1 Top of Cerrent 31/2" x 7" 1 ~: '- : I 11534' H Openhole sldetraekoff em! 1i ~' 1 2-3/8" 4.7# ST-L Cerrented liner 1-1 13083' I ¡ _:.. i I _ ~_1~21~O' ~~~::~~:T::~:.~::~~a: ::" :::..:''J.'{;:;~~.:;:~:\:.;(..., ·.)~í~~~J:i~4~,O· ill {·,)iV:iŒ;:~:~~:~. .: . . ,", " '. . . .. - ",' ',' " . . . - ~., ,~ "'. ,;- .: ... l' .. ; ,:' ::-:);¡'/,~~~':·s : ~.:...~ ~- Al.ooooo·~ . I I I I I I I 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 13000' I--AI .. ") .OTES: LDL INDICATES 7" LNR LAP LEAK @ 1"...03. ....:MENTED4/3/98. CMT COLLAR 2.76" ID FROM 9600' TO 11032' REMOVED WHEN (8/99) RlH, MILL SWN TO 2.81". ~ 34' 1-1 4-1/2" X 3-1/2" XO I 2111' 1- 3-1/2" CAMCO TRDP-4A-SC SSSV NIP, 10 = 2.812" GAS LIFT MANDRELS ST MO TVD DEV TYPE VLV LATCH PORT DATE 1 3405 3195 39 MMG RK 2 6544 5479 44 MMG RK 3 8615 6997 44 MMG RK 4* 10023 7971 44 MMG RK 5* 10147 8049 52 MMG RK * BB-iIND GMT SHEATH ~ 11014' 1-1 3-1/2" OTIS XN NIP, 10 = 2.813" 1 2-3/8" 4.7# ST-L Cerrented liner H 13300' 1 /" 12653' 11 7" LNR, 26#. NT80S, NSCC, .0383 bpf, 10 = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/06/92 ORIGINAL COMPlETION 05/17/02 MSE PROPOSED SÐETRACK 09/05/93 LAST WORKOVER 06/06/02 MSE FISH 12/18/00 SIS-IsI CONVERTED TO CANVAS 02/14/01 SIS-MD FINAL 01/09102 RNITP CORRECTIONS PRUDHOE BAY UNIT WaL: 15-30A PERMIT No: 202-089 API No: 50-029-22282-01 SEC 22 T11N R14E, 4264.77 Fa. 20.01 FNL BP exploration (Alaska) ) ao~-or¿ 9 I J d3ð Transmittal Form - ..... "._._____._~~_._~.._____. n_,___ '&1. BAKER HUGHES I ì--~;!~;-:-:;:;;;-;;~-;;;;;-l .'.'.... .......'.'. ,'~;"'~';':;';::1Ï;';:¡';';¡; ~~; ...'.. ..'.'.. ;,IIdIIIIi:'" OOIiIIR",·"" 110,1\ N'l..:. ,."" ... ., ... INTEQ Anchorage GEOScience Center :~~-----s-;;,-;,·-~~--~·'---~~ .,..........,.., "'''......,..... To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Wee pie Reference: 15-30A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary !------.,-----~~I~...;~~-.,. --..----. ..--. c~~·----§:--;õ,;~:~,,-~::· --~:~:~ ........·I~·..' _""." . . ....,," '"" [,::~ii~--ii¡~~~:j;- I 1 blueline - GRlDirectional Measured Depth Log 1 blueline - GRlDirectional TVD Log Date: LAC Job#: 280415 ~'~'_"n___~_"""~,_...____,__,_ "_.~_'..___,.___.____,,__..~........._______.,,_. -_.~~----"~._.._--_."._---~...- Sent By: Glen Borel ReceivedalJ-OOo_~~ ./ Date: Oct 23, 2002 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING . ~ OR FAXING YOUR COpy ECE\\. 'ED" FAX: (907) 267-6623 R IV :>; 'IIIII:~:W Baker Hughes INTEQ OC-r 2. 4 l.002 7260 Homer Drive , Ancho~~~~, gAlaSka ,aJ_a Of\ &. Gas ConS. eomm\leiOn Direct: (907) 267-6612 ~ FAX: (907) 267-6623 ." ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: II Operation Shutdown [J Stimulate [J Pull Tubing [J Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1702' SNL, 1390' EWL, SEC. 22, T11N, R14E, UM At top of productive interval NIA At effective depth 4334' NSL, 221' EWL, SEC. 14, T11N, R14E, UM At total depth 4899' NSL, 925' EWL, SEC. 14, T11N, R14E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 13083 feet 8768 feet 12135 feet 8780 feet measured true vertical Casi ng Structural Conductor Surface Intermediate Production Liner Liner Length 80· 3801' 20" 13-3/8" 10535' 1271' 2027' 9-5/8" 711 2-3/8" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Size [J Plugging [J Perforate [J Repair Well [J Other 5. Type of well: ØI Development [:J Exploratory [:J Stratigraphic [:J Service 6. Datum Elevation (DF or KB) RKB = 64' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 15·30A 9. Permit Number I Approval No. 202-089 302-182 10. API Number 50- 029-22282-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) 2-3/8" Liner full of cement, cleaned out to about 12135', where the first BHA became stuck. Junk (measured) Liner Cut at 11610'; Jarred Up to top about 10960, Bottom at about 11514' Cemented MD TVD 2880 cu ft CS III, 1326 cu ft 'G' 110' 3838' 110' 3522' 2543 cu ft Class 'G' 487 cu ft Class 'G' 10 cu ft Class 'G' (Estimate TOC in annulus at 12600') 10568' 10263' - 11534' 11610' - 13083' 8299' 8119' - 8764' 8790' - 8704' 4-1/2", 12.6#, L-80 to 34'; 3-1/2",9.3#, 13Cr80 to 11032', 4-1/2",12.6#, L-80 to 11043'; 3-1/2", 9.3#, 13Cr80 to 11534' ~~ ~ t 112' Baker 'SABL' packer at 11036'; 3-112" Ra~l' 'T~I'rtD SSSV Nipple at Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) JUL 2 4 2002 Alaska Oil & Gas Gons. CommissiQn Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments [:J Copies of Logs and Surveys run ØI Daily Report of Well Operations 17. I hereby certify that the for,oin~ is true and correct to the best of my ~nOWle~ge Signed Terrie Hubble -1'0 ~ ~ Title Technical Assistant Casing Pressure 16. Status of well classifications as: ØI Oil [:J Gas [:J Suspended Form 10-404 Rev. 06/15/88 Service Date 07· ;¡.Lf-O a ~ o k IG I N A L Prepared By _unWer. Terrie Hubble, 564-4628 Submit In Duplicate ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ',:1 ': . '.: ' ," : '.,' ,', .: ,":' ~ ¡': " , : ~ I:: I, I " : I ··"·D~t::······ :'.',.::' :·".·:::"·:'I:·P·;~I,., 5/23/2002 5/24/2002 5/25/2002 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: :,::.·W',.d~....··~.···+6:.·':.··RqJr$,;,··.···.··.··.·.T~~H.·,;··.·.··.·,GÞ~~:;:':':,'~~1-,·..·.,,::·,··,þ·~·~~~.'...;::.. .,..,......::...':,:. ..'.'.:.'.:.'..'...'.:'.:...::...,:,..:.,.::.......:.'.:,::\:.:.·.:."..·...:.·.·.:.·.1.:·,I·...:...:'::....':...:.·'.,....,....,.:::,. '::·i:;Q~$Þ~idtiÞO··ofa.~~·~ti~~~" ,'....:., . ",' . I 1,' 'I I ',' ~:: '\::" ".,:,;1 ,:,I,~:,,.' I :': ' :'1::, ~!, :~,:'Ir', ,:' "':, .:" : ,~r,": ":':';::. 1,,1';. "::: .:i; II :1:;:',11 .,:': ~: ',,: ,;,: : 1,1:: :'< !':":; ,:",1 ':/,1:" ,I:' , :,1,'. ::,'":' ':: :1', :;, ':-:':,' ::::', /.,:I,~ .' ',':',::,' P.' ':': :,' ,1"1 'I . ::' ; ;" ;1,',"::':'('1';::' ":'. ,I:":.: I::::;, ¡.', : ;'" I" ,.", ",.'. 'I' .' 1,1 I', ': ", '[', i"'-'::" ~ ;11 :' ".," I I'" '1..1. I': "L, ,. I' 11" I, ':~:' \.', 08:00 -10:45 2.75 MOB P PRE RD on F-04a. Unstab CT. Remove gooseneck. Set injector in pipe bay. Load oout mise loads Move rig off tree and to end of pad. Clean up Location. Lower windwalls. Load CSH out of pipe shed. Prep floor Scope down derrick. Lay down derrick PJSM rig move. Include all parts involved, Leave location. Move to DS 15. Arrived to DS-15.. PJSM: Raise derrick Raise and scope derrick. Secure derrick Raise windwalls and secure. Retract Tilt Rams. RU injector, install gooseneck and stab in coil Safety mtg re: move over well Move rig over tree and set down Accept rig for operations at 0830 hrs 5/24/02 Remove tree cap. NUBOPE Grease crew service leaking wing/swab. FL had previously been depressured to zero, but pressured back up to 400 psi Test BOPE. Witness waived by AOGCC PU injector. Kinked CT at levelwind on move. Cut off 80' of CT. Pump slack back (rev) w/ 56 bbls. Cut off 15' to find cable. Cut 10' of col and cable to find dry cable. PU. Baker tools. MU cement milling BHA RIH/straight motor to drill out approx 100' of cement. Up wt 35K#s. wt dwn 12.5k#s. Free spin 2700 psi. Tag cement stringer @11285'. See some motor work. Clean out cement from 11285'. 400-500 psi motor work. Tag whipstock @11517'. Had good cement returns. POH. EOP @11400'. P/U. BHA #2 for window milling. RIH w/2.5 Weatherford motor. Corr +11' to flag. Work on BHI PC. 36.5k at 11500' RIH w/o pump, tag WS at 11532' CTD PVT 290. PUH 37k, start pump. RIH slow at 1.5/2580 and see motor work at 11530.1'. Corr to 11534' and let it drill off Begin milling by procedure at 11534' 1.5/2160/212 deg 12.5k Flag CT at 11535.5' 1.6/2600/217 10.3k PVT 286. PUH l' and begin time milling by schedule Safety mtg re: emergency resources tied up on C-07 DSM shut down moving flowback tank/hard line for same reason Back at flag 1.6/2630/225 10. 7k PVT 286 DSM resume RU flowback tank hard line 11537.5' 1.6/3000/197 7.5k PVT 282 11538.8' 1.6/3140/200 6.7k PVT 280 11539.21.613144/2156.7k PVT280 11539.71.6/3190/2107.6k PVT 280 11540.1 1.6/3250/220 8.0k PVT 278 11540.2'.1.6/3280/200 8.0k PVT 277. Power source went down. No computers. Got ups back, 11540.3.1.6/3320/205 7.6k PVT 278 11540.71.6/3350/210 7.8k PVT 277 . 10:45 - 11 :30 0.75 MOB P PRE 11 :30 - 15:00 3.50 MOB P PRE 15:00 - 16:30 1.50 MOB P PRE 16:30 - 16:45 0.25 MOB P PRE 16:45 - 23:30 6.75 MOB P PRE 23:30 - 00:00 0.50 MOB P PRE 00:00 - 01 :00 1.00 RIGU P PRE 01 :00 - 02:00 1.00 RIGU P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 07:45 4.75 RIGU P PRE 07:45 - 08:00 0.25 RIGU P PRE 08:00 - 08:30 0.50 RIGU P PRE 08:30 - 09:30 1.00 BOPSUR P DECOMP 09:30 - 10:30 1.00 BOPSUR P DECOMP 10:30 - 16:40 6.17 BOPSUR P DECOMP 16:40 - 17:40 1.00 BOPSURP DECaMP 17:40 - 19:00 1.33 BOPSUR P DECOMP 19:00 - 22:00 3.00 STWHIP P WEXIT 22:00 - 00:00 2.00 STWHIP P WEXIT 00:00 - 00:15 0.25 CLEAN C WEXIT 00:15 - 03:30 3.25 CLEAN C WEXIT 03:30 - 05:30 2.00 CLEAN C WEXIT 05:30 - 06:00 0.50 STWHIP C WEXIT 06:00 - 07:50 1.83 STWHIP P WEXIT 07:50 - 08:20 0.50 STWHIP N SFAL WEXIT 08:20 - 08:45 0.42 STWHIP P WEXIT 08:45 - 11 : 10 2.42 STWHIP P WEXIT 11:10 -14:10 3.00 STWHIP P WEXIT 14:10 - 16:45 2.58 STWHIP P WEXIT 16:45 - 18:15 1.50 STWHIP P WEXIT 18:15 -18:45 0.50 STWHIP P WEXIT 18:45 -19:15 0.50 STWHIP P WEXIT 19:15 -19:45 0.50 STWHIP P WEXIT 19:45 - 20:15 0.50 STWHIP P WEXIT 20:15 - 21 :00 0.75 STWHIP P WEXIT 21 :00 - 21 :15 0.25 STWHIP P WEXIT 21 :15 - 21 :45 0.50 STWHIP P WEXIT Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:58 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L , . ,'::' I I:' I :1" , . I ': ~/:' ',',: '.', I:: ':':. ·p~'~:.I.·:, ~::' " ; , I ,I :. ,', .' II ' " '"," I' I 5/25/2002 5/26/2002 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: .... ..;' :.:'..' ,..:.. i:, .... ....'.,. .".:..',:, .' · :.:. . i.' :.:'.. ,':;: i' '.. ;:;1 ..,...... . : "'. .. '. . .... ...... ,'.;' 'i:'.::.:::/i..:\...~:··'::;t·~·:, '.'~::. ::..'.':.; ': \.. '. ,'., . ", '. .:: .; .. , '. ·:.Frotn.~::iTo:IHoursi·:ma$k·,' "Cóäe·..·NP,:r :.·.;·.·..:..·.iP.·..;.,.,.·.h.......·....,.....·s.·.....·....e.'..·..·...':..··...1·'·;..; ...·..'..'1,,:"'··1' ".1 .......' ,.~e$crlptiQoof Gpetatløt:¡.s ,,' ;1 ",,' ,{. "¡"','.:" :, ":','I,>~, '" I :I'/:',i " I,;, "":" ,';:" ','" "', : ,'", ' .i:' .';' , II'" ","", ::', I ',: ':1/:,:):.:" ",", ,,; ", . '. ',::}":: ,," ""/.'; >:'1' ,1-" I _.',1 ,\:.< ,'.,' .I:II.;,I,,,,'~ ,:,I,:'J:':.:;':"~I;' ":.:, " ::,:,,):}I: ,:, .j,,;, ,,',"" .:': I,';" :::. i,"I',.:" :'," i, .I,~II.: ,.' ,","-: 1':'\," " ,:..:i", ,::1" \:i,. ;1,,: ' , :,:,:1", : I ;: ,'II", : I,: : :,,11',' 'I, :::: ' I,'" 'I " ,II : , WEXIT 11541.01.6/3230/2207.0 PVT 277 WEXIT 11542.0 1.6/3240/210 6.9 PVT 277. Increase on ROP and WOB go down. WEXIT Drilling formation. 11542.4 1.6/3248/205 7.6k PVT 275 WEXIT 11545' 1.6/3230/205. 7.5k PVT 274 WEXIT Drill to 11551'. Pump 2# biozan pill. Got sand over the shakers. WEXIT POH to p/u crayola mill. WEXIT P/U dressing BHA WEXIT RIH w/2.79" crayola mill to 11521' CTD. Attempt to ream and BHA pressured up-assume motor. Open EDC, POOH filling thru CT WEXIT POOH to check BHA WEXIT LD BHA. Couldn't turn motor w/ Phil on a '48'. Change out WF motor for BHI. Changeout BHI EDC due to drawing high current. Install backup DS UPS and replumb wiring in ops cab WEXIT RIH w/ BHA #4 WEXIT Tag at 11520' CTD and corr to 11534'. Dress window 1.6/2620/210 deg PVT 270. A few stalls getting started, then relatively clean to 11535.7' WEXIT Mill a burr on 7" at 11535.7' with a bunch of stalls to 11536.0' WEXIT Ease into open hole from 11536' 1.5/2365/225 to another burr at 11541.4'. Clean after that to tagged TD at 11551' Ream window from 170-250 deg in 3 passes, clean. Dry tag POOH for drilling assy OOH. UD milling assy. PJSM on cutting pipe. Cut 100' of coil Re-heading. MU Build assy. RIHw/BHA #5 (2.4 Baker motor and bicenter bit). RIH to 11500'. Tie in. +14' correction. Waiting on mud. Mud on location. Swap well to mud Orient to 210L. Drill ahead. 1.5/3520/10R. Drill to 11600' Drill from 11600-630' 1.5/3440/5L 40-50'/hr Enter the shale above the Kavik at 10630' at 80 deg and penetration slowed to avg 10'/hr. Finish the build at 95 deg at 11670' and begin the left turn PROD1 Stalled at 11700', but then back to more of the same. Drill to 11725' and P rate picked up Wiper to window from 11725'. RIH to TD Slow backream while BHI reboots PC Resume drilling from 11725' 1.5/3460/85L. Drill to 11737' Orient to right side to set up for lateral and drill from 11737' 1.5/3560/85R 5Q-70'/hr in target sand 45 api. Drill to 11770' Wiper to window. Open EDC. POOH for lateral assy OOH. UD build assy. P/U lateral assy. RIH w/1.1 motor. Tie in. Correct +20'. Problems with Baker equipment. Back on bottom drilling. 1.4/3650/150. Drill to 11850'. 21 :45 - 22:00 0.25 STWHIP P 22:00 - 22:30 0.50 STWHIP P 22:30 - 23:00 0.50 STWHIP P 23:00 - 00:00 1.00 STWHIP P 00:00 - 01 :30 1.50 STWHIP P 01 :30 - 03:30 2.00 STWHIP P 03:30 - 04:00 0.50 STWHIP P 04:00 - 06:30 2.50 STWHIP P 06:30 - 08:15 1.75 STWHIP N DFAL 08: 15 - 09:45 1.50 STWHIP N DFAL 09:45 - 12:00 2.25 STWHIP N DFAL 12:00 -13:45 1.75 STWHIP P 13:45 - 16:30 2.75 STWHIP P 16:30 - 17:40 1.17 STWHIP P 17:40 - 18:00 0.33 STWHIP P 18:00 - 20:00 2.00 STWHIP P 20:00 - 20:30 0.50 STWHIP P 20:30 - 20:45 0.25 STWHIP P 20:45-21:15 0.50 STWHIP P 21:15-23:30 2.25 DRILL P 23:30 - 00:00 0.50 DRILL P 5/27/2002 00:00 - 02:00 2.00 DRILL P 02:00 - 02:20 0.33 DRILL P 02:20 - 03:45 1.42 DRILL N 03:45 - 04:00 0.25 DRILL P 04:00 - 06:00 2.00 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 07:30 1.00 DRILL P 07:30 - 12:30 5.00 DRILL P 12:30 - 13:50 1.33 DRILL P 13:50 -14:05 0.25 DRILL P 14:05 - 16:00 1.92 DRILL N 16:00 - 16:20 0.33 DRILL P 16:20 - 16:50 0.50 DRILL P 16:50 - 17:00 0.17 DRILL P 17:00 - 18:45 1.75 DRILL P 18:45 - 19:45 1.00 DRILL P 19:45 - 22:00 2.25 DRILL P 22:00 - 23:00 1.00 DRILL N 23:00 - 00:00 1.00 DRILL P WAIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 SFAL PROD1 PROD1 PROD1 SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:58 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .··..·.··.,;.i:'·[)åt~.:.:,·:""·· :":':',"1<,:,: :,','L,,",:li','I'I,: 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: :#·~6ri;..:Ä'·.Î6·,:,.,:H·ÓG~ã/;··Ir~~~...;,::~øóa~·::·.·,;'~'þ~;,"·;~:hl~~~·):lli\:,II:.' 1,...'··.···'·;··'···,1 ',,' 1.,O~$g~iÄtip, ~" o~ G>R,~r~tiRn~'· ',...1. .".,..... /:1" ",":'\:..:;>:':"I;:~ ':':.:.,.;:::1.:, " ' I"" ' .., 'I' ¡'.,', ,1·,''",,:, I' " " :"J\", 'i, " I ::. , '.1, ",' I '. '" ' I ;"'\I!:'):<I .':'::,:1::':,,;:;1',':,,".1"'<:11,1",::1::: " ::,: ',',,:':\',,::1;1';:",:',:,.';11 !. "",,:, ":1 '~.':',':, ::::,"':"'1:,:::, ''':''1' <,'¡,'[ ;,1"'1,;,:,...111 I"':' , I I "11" , Ii " ",', 'II 'I" I l' : I I'., ,I 11'1 'I,' I I' " ,'.: I Spud Date: 5/24/2002 End: 6/6/2002 5/28/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Drill ahead. 1.6/30001 Drill to 11911'. Motor not giving predicted doglegs. Will deviate from plan if continue with this motor. 01 :00 - 03:00 2.00 DRILL P PROD1 POH to P/U a more agressive motor. 03:00 - 03:35 0.58 DRILL P PROD1 OOH. Change motor bend. 03:35 - 05:30 1.92 DRILL P PROD1 RIH w/2.0 deg motor. 05:30 - 08:00 2.50 DRILL P PROD1 Drill from 11911' 1.6/3700/90-125R. 1:1 returns. 08:00 - 08:15 0.25 DRILL P PROD1 Wiper to window from 12062' 08:15 - 08:20 0.08 DRILL P PROD1 Log tie-in up from 11570', no corr 08:20 - 08:40 0.33 DRILL P PROD1 RIH, begin swap to new mud 08:40 - 11 :20 2.67 DRILL P PROD1 Drill from 12062' in a shale. Get back into 55 api sand at 12115' 1.5/3430/90R. Drill to 12165' 11 :20 - 12:25 1.08 DRILL P PROD1 Orient back to left side and drill 1.5/3400/85-11 OL. Get into 35-45 api sand at 12225'. Drill to 12282' 12:25 - 13:15 0.83 DRILL P PROD1 Wiper to window from 12282' 13:15 -15:05 1.83 DRILL P PROD1 Drill from 12282' 1.5/3400/95L. Took 45 min to get thru a hard spot at 12313' 15:05 - 17:15 2.17 DRILL P PROD1 POOH from 12330' to change motor angle circ thru EDC. 17:15 - 17:45 0.50 DRILL P PROD1 Close EDC & tag up @ surface with BHA #7. Check bit - OK. Reset motor to 1.5 degs bend. 17:45 - 19:45 2.00 DRILL P PROD1 RIH BHA #8 with 1.5 deg motor & same HCC bicenter bit. RIH to 2000'. Open EDC & continue RIH @0.3bpm & 1200psi to 11550'. 19:45 - 20:00 0.25 DRILL P PROD1 Log tie-in with RA marker. Added 18 ft to CTD. Closed circ sub. 20:00 - 20:30 0.50 DRILL P PROD1 RIH to TO. Tagged TO at 12,331 ft. Clean hole to TO. 20:30 - 22:20 1.83 DRILL P PROD1 Drilling, 1.5 /1.5 bpm, 3300-3700 psi, 90 FPH, 2000# WOB, Drilled to 12,500'. 22:20 - 23:15 0.92 DRILL P PROD1 Wiper trip to window. Clean Hole. RIH to TO. 23:15 - 00:00 0.75 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3300-3800 psi, Drilled to 12,520 ft. 5/29/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Drilling, 1.5/1.5 bpm, 3300-3800 psi. Drilled to 12,552 ft. BHA not drilling directionally as it should. Appears to be 60 deg off on tool face. 01 :00 - 03:10 2.17 DRILL N DPRB PROD1 POH to check motor and bit. Clean in open hole. POH. 03: 1 0 - 03:30 0.33 DRILL N DPRB PROD1 Check BHA. Found motor high side to be 56 deg off. 03:30 - 03:45 0.25 DRILL N DPRB PROD1 SAFETY MEETING. Review CT cutting procedure and hazards. 03:45 - 05:45 2.00 DRILL N DPRB PROD1 Cut off 100 ft of CT using hydraulic cutter and hydraulic cable cutter. M/U BHI CTC and pull test. Press test eTC. M/U same BHA with 1.5 deg. motor and Bit #5. 05:45 - 07:30 1.75 DRILL N DPRB PROD1 RIH to 10989' with BHA #9 with 1.5 deg. motor and bi-center Bit #6. 07:30 - 09:30 2.00 DRILL N SFAL PROD1 Stop to reboot BHI surface computers - system not recording to database. 09:30 - 09:40 0.17 DRILL N DPRB PROD1 Continue RIH with BHA #9 to 11550'. 09:40 - 09:50 0.17 DRILL N DPRB PROD1 Log tie-in with RA marker. Added 13.75' to CTD. 09:50 - 12:50 3.00 DRILL N SFAL PROD1 BHI surface computers acting up again - system crash. Re-install software & re-initialize well. Also prepare spare initializing data for quick re-initializations if bug re-occurs. 12:50 -13:25 0.58 DRILL N DPRB PROD1 Continue RIH to 12500'. 13:25 - 13:50 0.42 DRILL N DPRB PROD1 Log down MAD pass from 12500' @ 210 TF & 150fph to validate BHI computer data. 13:50 - 15:45 1.92 DRILL P PROD1 Drill lateral to 12600' @ 140TF, 1.5/1.5bpm, 3300/3550psi, 2k Printed: 7/1812002 3:05:58 PM ) ') Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: ¡'............:...p....I....',.'.'·.11..;.....:8;..·.:.:......s..·,.....··.:.e.·..:.'...¡·,.........,....:....... ';...'........,'..:....'.'....,i...·..:.......:......:.'....:.:.....'...'.':....:.',..........:.......',.,............I..'.·....,......~.,....,'...:;.....,.....1.......... ::J,:'·,;··.>·.·D~$ààÄtib~'·bfldø~rafiòÔsl":·¡ , , '~:I'.'> ,,':', :', ;. ,: :11:'-,' I, 'I :', :','1 '¡':" ':1'::: :~ I {," ','; ~ :\'. 'i' :["\' : ~' ;. ;'" : ' "':':' , , :< :' I ;., ': I ' ;',,:: .>1 ::.''' : ::',: ~ ':.,:¡" ::. 1:,:","..' ",IIi"". ",,:: ,I 'I:: " PROD1 WOB & 20fph ROP. Hard drilling with occasional wt stacking. Drilling out of shale. Observe +/-8degs azm swings. PROD1 PUH & shoot check shot surveys @ 12482', to 12519' & 12540'. Observe 95.23 degs incl, 48.34degs azm & 46.5degs DLS @ 12547' survey depth. Also pull heavy around hi DLS area. RBIH to btm. PROD1 Drill to 12610' @ 130TF, 1.5/1.5bpm, 3300/3500psi & 6k WOB. Serious wt stacking. Can't get any wt to bit to drill. Work pipe ... no progress. Prepare & pump down 30bbls 4.5% lubetex pill. PROD1 Drilling, Pill out of bit. TF = 120R, 1.5 /1.5 bpm, 3360-3800 psi, Circ. second lubetex 30 bbl pill around for better wt transfer while drilling shale. Slow drilling, 20% Pyrite in geo sample at this depth. 3% lubetex in system now. Drilled to 12,626 ft. Drilling, TF = 120R, 1.5/1.5 bpm, 3400 - 3900 psi, Incl = 88 deg. Drilled to 12,713'. Wiper trip to window. Hole was clean. Log tie-in with RA tag. Open circ sub and log down. Added 7 ft to CTD. Rig generator #1 motor intake valves failed. Valves stuck and twisted. Pistons damaged. Engine rebuild required. Spare engine/generator in conex at Price pad. Will install spare engine/generator. POH. Expect to be shut down for approx. 12 - 18 hours. POH while waiting on rig generator / engine #1 replacement. Haul spare eng/gen from Price pad to location for swap. UO MWD BHA. Shut in well at swab valve. SIWHP = 0 psi. BHI on standby at 03:30 hrs. Spare eng / gen on location, Pull gen #1 radiator off and pull eng/gen off rig. Install spare generator & engine onto rig. Rig off downtime. PJSM. Grease tree valves & carried out weekly testing of BOPE to 3500psi as per drilling permit. Witnessing of test waived by State Rep John Crisp. PfTested inner reel valve to 3500psi. Meanwhile continue hooking-up rig gen set accessories. Rig back on downtime. Continue hooking-up rig gen set accessories'" cable wiring, etc. Test Gen set #1. OK. Safety meeting. Review procedure and hazards for BHA make-up. MlU Coiltrak BHA #10. 1.5 deg motor and He 3.0" bi-center bit #7. MlU Coiltrak BHA #10 with 1.50 deg motor and 3.0" He Bi-center Bit # RIH. Shallow test Coiltrak, OK. RIH to 11500 ft. Wait for BHI surface computer problems. Re-boot computers, unable to display any information to ops cab or geology monitors. Fixed problem. Log Tie-in with RA tag at 11,540'. Added 13 ft to CTD. RIH & set down @ 11700' (shale). P/U & fall thru. Set down @ 12562' (shale). Ream thru shale from 12525' @ original TF. Precautionary ream to TD (tagged'" 12723') @ 1.5/1.5, 3400psi, 300bbls PVT. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-30 15-30A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 :,' :.,,:,::1,; <.,' .,;": :;>~'/" ::' ::,.' "'::.:::':::,:' ,",' ,':!:.:; ,: i ,::.':': ': :. ~:';:':'; ,: :::::,' ,I',,; .:,1, ';';';. 'I " ':: '::,:':: .:::: ,. :;;:!> I :.~,~: "', ~ .' Hour¡· ·.,m~$k· ·:Coøe..NP! /'",' ,'I':': " :"','. ' , ,,",>''::,: ,I : ':1:, 'I" ',,~,i"' ":',:,:.,,' '" I,::.'::':: ,'::, ::.'::' ':1':: ,'; "<' ,,: /,'I'! ' ',,::' ,:/', "":.,':1,,,1, ~; 1.92 DRILL P , "" '1'·"1 I' "1'1' ......Q~~..... ..... ,,'~romC'r() I 11"1"" . I " ',"',' I; ,',"," 5/29/2002 13:50 - 15:45 15:45 - 16:40 0.92 DRILL P 16:40 - 18:30 1.83 DRILL P 18:30 - 21:00 2.50 DRILL P 21 :00 - 22:45 1.75 DRILL P PROD1 22:45 - 23:20 0.58 DRILL P PROD1 23:20 - 23:45 0.42 DRILL P PROD1 23:45 - 00:00 0.25 DRILL N RREP PROD1 5/30/2002 00:00 - 03:00 3.00 DRILL N RREP PROD1 03:00 - 03:30 0.50 DRILL N RREP PROD1 03:30 - 07:30 4.00 DRILL N RREP PROD1 07:30 - 11 :00 3.50 DRILL N RREP PROD1 11 :00 -17:00 6.00 DRILL P PROD1 17:00 - 23:30 6.50 DRILL N RREP PROD1 23:30 - 23:45 0.25 DRILL N RREP PROD1 23:45 - 00:00 0.25 DRILL N RREP PROD1 5/31/2002 00:00 - 00:15 0.25 DRILL N RREP PROD1 00:15 - 02:15 2.00 DRILL N RREP PROD1 02: 15 - 05:45 3.50 DRILL N SFAL PROD1 05:45 - 06:00 0.25 DRILL P PROD1 06:00 - 06:50 0.83 DRILL P PROD1 Spud Date: 5/24/2002 End: 6/6/2002 ,"'I', I,"', ,:","',,: ., I :'" Printed: 7/1812002 3:05:58 PM ) ') Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Start: 5/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 6/6/2002 Rig Name: NORDIC 1 Rig Number: .lp~te.:;:,,:;~(9n:rt'lq:,:,;Hp·IJ~;, .'.1;a$k:)Cød~<·,·NFrr;:.:....·Rha$~;, '..,' ..... ,.:..;.:.,....' .'.: :.(¡)e$ÞfiþtiQn,ófØþ~~tio.o~·'.,' I'· ,.I." I· :, ',' , ',' '. ' ' :' i "\' ,',1'1::,:: :' '/1:,::' '\" ::' ';. ", "." ,', I ". I, "I .::: ': :)'1 ~ ,:',1, ':: ¡. ::, :;1'," ,::" I' ,I", ' ' ,~.' :' 'ï' :: ' " , "II:, :-i', I :~:' '" p' I'~, I ",.':. I,,:::: 1,':: ,': ,.-' I." ':', ',.' ':'" , :,,1:,: ,',":'. I, . ',: ' , "I ),) ,':': ",1' : I :' . I I:' '. I, "/;Ir'::' ~ :.;,:,:: I, ',':' . I '!":'" ,:: ",1:.':1: ,J.> ':', ,': ,',:' .:':, } :',":1', I ',.,,~ ;',:' ;,' :': ',": I :,:¡ '" ": ':',: ';.'. ,; I, ':',,';: ,l" ': I ' I,' ) ,I ,:: :~'I ,I.' ", ," Resume drilling from 12723' to 12740' @ 15TF, 1.5/1.5bpm, 3400/3800psi, 2k WOB, 15fph aye ROP & 300bbls PVT. Drill to 12759' @ 90TF, 1.5/1.5bpm, 3350/3800psi, 2k WOB, & 100fph aye ROP. P/U & pull heavy. Differentially stuck. P/U & SID pumps for 15m ins. Pull free with 56k (30k O/P). P/U & ream drilled section. Continue drilling to 12795' @ 11 OTF, 1.5/1.5bpm, 3450/3950psi, 2k WOB, 25fph aye ROP & 282bbls PVT. Drilled thru shale from 12770' -12793'. Drill to 12840' @ 260TF, 1.5/1.5bpm, 3400/3900psi, 2k WOB, & 90fph aye ROP. Drill to 12868' @ 300TF, 1.5/1.5bpm, 3400/3900psi, 2k WOB, & 48fph aye ROP. Wiper to window. RBIH & set down several times in shale from 11630 to 11700'. Backream thru section & continue RIH to bottom. Meanwhile held fire drill. Drill to 12887' @ 260TF, 1.5/1.5bpm, 3500/3800psi, 2k WOB, & 12fph aye ROP. Seeing some pyrite in geo samples. Drill to 12925' @ 290TF, 1.5/1.5bpm, 3500/3700psi, 2k WOB, & 30fph aye ROP. Drilled shale from 12875' - 12895' - may be drilling thru Zone-1A11 B interface shale. Geo decides to mantain 91 degs incl. Drill to 12959' @ 260TF, 1.5/1.5bpm, 3500/4050psi, 2k WOB, & 51fph aye ROP. Wt stacking. Short wiper trip to 12500'. RBIH & set down @ 12596'. P/U & RBIH. Still stacking wt. Drill solids in mud up to 0.7%. Prepare & pump down 30bbls 4.5% lubetex pill. Pill out of bit. Take off & drill to 12991' @ 260TF, 1.5/1.5bpm, 3500/4050psi, 2k WOB, & 30fph aye ROP. Serious wt stacking. Call for fresh SFFP mud. Work pipe & take off drilling again to 13023'. Wiper to window. Open EDC. Log tie-in with RA tag. Added 13' to CTD. Close EDC. RBIH to btm. Clean trip to bottom. Drilling, Stacking wt, good wt [+9K] just off bottom, but unable to get enough WOB to drill ahead. max WOB = 700 Ibs. Ream hole while waiting for new FloPro. Drilling with new flopro. TF = 115R, 1.5/ 1.5 bpm, 2700- 3200 psi, Drilled to 13067' PROD1 Drilling, TF = 120R, 1.5/1.5 bpm, 2700 - 3300 psi, Drilled to 13081 ft. PROD1 Drilling, TF = 165R, 1.6/1.6 bpm, 3000-3400 psi, Slow drilling, chert and pyrite in geo sample from this depth. Drilled to 13083 ft. Unable to drill any further, max wt on bit possible was 1700 Ibs, no ROP with this WOB. Wiper trip to window. Hole clean. Logged tie-in with RA marker. Added 2 ft to CTD. RIH to TD. Sat down at 12700, 12818 ft. RIH clean to TD of 13,083 ft. Drilling, zero ROP with 1400# WOB. Unable to drill any further. Call TD at 13,083 ft. 5/31/2002 06:50 - 07:10 0.33 DRILL P PROD1 07:10 - 07:30 0.33 DRILL P PROD1 07:30 - 07:45 0.25 DRILL N STUC PROD1 07:45 - 09:15 1.50 DRILL P PROD1 09: 15 - 09:45 0.50 DRILL P PROD1 09:45 - 10:20 0.58 DRILL P PROD1 10:20 - 11 :00 0.67 DRILL P PROD1 11 :00 - 12:35 1.58 DRILL P PROD1 12:35 - 13:50 1.25 DRILL P PROD1 13:50 - 14:30 0.67 DRILL P PROD1 14:30 - 15:45 1.25 DRILL P PROD1 15:45 -16:40 0.92 DRILL P PROD1 16:40 -17:30 0.83 DRILL P PROD1 17:30 - 17:45 0.25 DRILL P PROD1 17:45 - 18:45 1.00 DRILL P PROD1 18:45 - 22:00 3.25 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P 6/1/2002 00:00 - 03:00 3.00 DRILL P 03:00 - 03:45 0.75 DRILL P PROD1 03:45 - 04:00 0.25 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:58 PM ) ) Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: ~~~:::i 'i/:~~~i~~;::::} i..fi:".',',·,:. ..,·.·:·.::'::,.·;':':::·':·.··'.·:i'::":~.::,:'¡.,.'. Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 ,..' . 0', f ',. '~' .','. T· ,. ..~",i.···,~·,¡·:,'ri:s':.·,:,···,',.",',:.,'....'.,''T::':.."".,..···a'.·"i':"'s,lk·'.···...·.·...·..',;",.:.:".:.~. ·::.'o':':,'~e;'·:..·,. .,.. ',.'..'...'.':.':.....:,:"',...,.~.~~ ':::?':.....:,:,.,.,i:.·..·,~·~ðm,.'.':"'!:I·'.,.~..:..·,.'.',......·.,..·,·.":',ø.'.,·,.,,,'. 'I Ry,-« :1 ~ ~ I'/'::I"~·':<',.. ':':: .,'"1"',;,'.\', 1'"1,:":; I';''':''·'''':'' 'I, 'I,'" ::""1:';:"." .,', "::-:'.1 :''i.'.'''~;'I"I'':' >'."1.,: \".I'I;':'::::~ ::::;111': 6/1/2002 05:30 - 08:00 2.50 DRILL P PROD1 08:00 - 08:45 0.75 DRILL P PROD1 08:45 - 09:00 0.25 DRILL P PROD1 09:00 - 10:45 1.75 DRILL P PROD1 10:45 - 11 :00 0.25 CASE P COMP 11 :00 - 12:00 1.00 CASE P COMP 12:00 -12:20 0.33 CASE P COMP 12:20 - 16:00 3.67 CASE P COMP 16:00 - 17:45 1.75 CASE P COMP 17:45 -19:15 1.50 CASE P COMP 19:15 - 20:00 0.75 CASE P COMP 20:00 - 20: 15 0.25 CASE P COMP 20:15 - 20:30 0.25 CASE P COMP 20:30 - 22:30 2.00 CASE P COMP 22:30 - 23:45 1.25 CASE P COMP 23:45 - 00:00 0.25 CASE P COMP 6/212002 1.00 CASE P COMP 00:00 - 01 :00 01 :00 - 01 :45 0.75 CASE P COMP Spud Date: 5/24/2002 End: 6/6/2002 ""'00' ',,'.:":-": ,\'1:,:":,:"::';': ',;::i::: "': ':',.',':: :,:':,'\<":'" : ,',: :".',,',:::'.' ',:/11,: 'I' ',1::,;1' ': ", ,"; ,:": :'.'.1 :.' ,:~, :; .. ·i!'·,iÞ·',.' ·~ÞM: "·"tiô:~:Þf,ºp~rªti..,"$..·."'¡: ,i::··.:,;.::~,:,·.R·. ...'"..\,:....:'>. ,..,~."..,'.:. POOH. Clean hole up to window. Open EDC & POOH to 500'. Close EDC, POOH & Tag up @ surface. Inspect bit - OK. UD driling BHA# 10. PJSM for BID CT with N2. Displace CT to water.· PT N2 unit to 3500 psi - OK. BID CT with N2 & bleed off. PJSM for securing CT prior to reel removal. Clamp CT end. Spool CT across pipe shed roof onto reel. Clamp CT tip with u-bolts & chain in place. PJSM with all personnel for simops on RIH liner assy & swapping reel. Reviewed HAlHM for planned activities & contingencies for well control without CT reel. Stress good communication & need to STOP any unsafe activities during simops. RIU, M/U & RIH 63 jts of 2-3/8" 4.7# L-80 STL with P/jt float equipment & turbos. M/U Baker Deployment Sleeve & CTLRT. Meanwhile swap out e-line reel to conventional 2" coil. Prep to stab CT into injector. Pull CT with tugger & place into counter. Secure CT with spooler clamp. Pull CT into rig floor. Prep CT tip for stabbing. Stab CT into injector. Prep & install weld-on CTC. Meanwhile hook-up hardline connections to reel. Pump 2 CT volumes thru coil to clean out any scale. Pump 2.75 bpm at 3000 psi. Pull test CTC. OK. Drift CTC with 1.0" drift. SAFETY MEETING. Review M/U of Baker CTLRT to eTC. Discuss hazards and mitgations. M/U Baker CTLRT for 2 3/8" liner. Liner and running tools = 2030.65 ft. RIH with 2-3/8" liner on CT. circ. 0.2 bpm, 870 psi. Up Wt = 28.5K at 11450 ft. Dwn Wt = 12.8K. DS computer went down twice while RIH. Correct to depth off of mechanical indicator. No flag on CT to correct to due to new coil. Ran thru window with no wt loss. RIH at 60 fpm, 0.4 bpm, 1430 psi, Sat down at 12,260,12430, 12486, 12521, 12588, 12620, 12680, 12745, 12767, 12803'. Sat down at 12,803 ft, ten times. Pull 200 ft while circ. RIH sat down at 12795', 3 times. Work liner down to 12,910 ft. Work down to 12,960 ft. Circ. at 1 bpm, RIH at 130 fpm with 0.1 bpm, Work liner down to 13,070 ft at 0000 hrs. DS computer shut down again. UPS cannot always keep up with rig dirty power supply. Need generator #3, which is still in Anchorage getting rebuilt. Working liner to TD. Changes in load on CT hyd. powerpack causing UPS to computers to die. DS computer died 3 times in 30 min. Got clean power to DS computer by running extension cord from BHI clean power supply in their trailer. Work liner down to TD of 13,078 ft CTD, 13,083 ft corrected. Sat down 6 times at same depth. Liner landed on bottom. Insert 5/8" steel ball and circ. at 1.7 bpm, 3700 psi. Ball on seat at 32 bbls, sheared at 3100 psi, Pull up and free from Printed: 7/1812002 3:05:58 PM ) ) Start: 5/24/2002 Rig Release: 6/6/2002 Rig Number: ",:.1":."'.:::1::,,":"::',,';1;', :::.:',:,:',:':' ':·"·"::.',,:'I:'·::'::'::';!;./:':,· "<>,:,'>,;,:"::[:',:''/.'::,,:'.;.'' :::',':-,:.,,1::, 1,1 I ' 'I ' ' I . I I I '.' 'I' "I 'I ·NR~:, .,...I.IPh:a$~·. ..1,..:1.·.··,'.:.· .;;: 1·"·:"::I;.'I,·D~~¢i"iêtiQ6··df ·6Þèt~tibd$. ':. :::'::,,:.,: ::,:<:" \".: il~IL ,:, : ;', .::::: I :,,'11' : I "'.:' I;';. :',. "'.: .' :':;:. ';, :"'': "", ï:,/,: I, .' Ili::·":.'.'~.':,.':," ':1", ',~::,:: I . ,1."." .....,;..': ,.' ,,',,: '.' /' 1::"", ',:.' '/,,', ,':' ':, II:: . ',': 'I: " " : ':' :,', : :' ':"", ,,',: .: ',I" ,: I ": ' .: :!':,":'I: I "," " :'1, :', ' :':,': ,,',':. \ COMP liner. RIH to same depth. COMP Circ. well to 2% KCL water. Recover FloPro and haul to MI plant for next well. circ at 1.7 bpm, 3700 psi. Circ. 2% KCL water at 1 bpm [0.9 bpm returns], while rigging up DS cement equipment. Cement slurry at 15.8 ppg wt. at 03:40 hrs. SAFETY MEETING. Review cement job procedure and hazard mitigation. Press test cementing line. Stage 8.0 bbls, 15.8 ppg. G cement slurry. Stop pump. purge cement lines, vac cement from behind dart. COMP Displace cement with Biozan water. pump 1 bbl. confirm dart was gone. Displace at 1.7 bpm, 3400 psi, 1.5 bpm returns. Dart on liner wiper plug at 40.6 bbl. Liner wiper plug sheared at 3000 psi, pumped 1.4 bbls and packed off completely. Holding static pump pressure of 4000 psi, bleed off CT press thru choke, pump up to 4200 psi, press fell back to 2000 psi, pump up to 4300 psi, holding static. 0 bpm, 4300 psi. 2 bbls cement out float shoe. Bleed off CT press and pump back up to 4500 psi, Holding 4500# jug tight. COMP Cycle press, up to 4500#, to zero and back up to 4500 psi, Float shoe or float cllr seem to be plugged. Bled CT to zero and pumped 500 psi down backside of CT. WHP held steady at 400 psi, [CT press at 30 psi, float valves holding press.] bleed off WHP and pump down CT to 4500 psi. COMP Bleed CT press to 1500 psi. Sting out of liner deployment sleeve. Saw CT press drop to 0 psi. Sting back in, sat down wt at same depth. Pump 0.3 bpm away at 4450 psi. Most likely pumping by seals, but pump away 8 bbls just in case. Sting out of deployment sleeve & circ on TOL. POOH CTLRT circ @ 2.6bpm, 2750psi OOH. UD CTLRT. Observe no seals on CTLRT. PJSM on P/U & RIH BHA & workstring for liner cleanout run. P/U & RIH 1.90" D331 DSM, 1-11/16" motor & MHA. M/U 68 1" CSH singles MIU injector & RIH with cleanout BHA#12 & tag TOL @ 11038'. Wt check = 24.5k up. Wash down clean with KCL water from 11038' to 11450' @ 0.9bpm, 2370/2400psi, & 28fpm. UCA compressive strength of cement @ 14:00 -1072psi. Tag LWP @ 11450' i.e. estimated cement behind casing - 1.6bbls, 490' with TOC @ 12590'. CEMT COMP Mill LWP (11450') @ 1.1 bpm, 2600psi. Fell thru & wash down to 11460'. CEMT COMP Mill down with 1 ppb biozan-KCL water from 11460' 1.1 bpm, 2100psi. Various motor stalls @ 11469'. Milling junk from liner wiper plug / dart, getting stalls and some overpull. Pump 10 bbl high vis sweep. Mill junk. Pump 15 bbl high vis pill. Mill thru junk. Drill cement to 11500'. Ave ROP = 30 FPH. CEMT COMP Milling out cement. 1.1 bpm, 2500 psi, 30 FPH. Still seeing Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,I I,"" b~t~':·': ,I'l, '1";"1':..·'·,'1' I 15-30 15-30A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 L:' ':::.:': ::,.1. \:':: ,::''''::'''~: 1':, " "::,::",:'¡'I,:'::.' ";".. '::", ': I",:", ,:-" :' :.1 :,',',' :,".: ,I ,~.:·,.'I " ": ::'1' .;, :',:':.:}' "," ':1'" ':' '.:.': I,:. i,:' I.: ': ",' !'::' ·l.From#.TO,1 .iH6Ur$·..·..· ·.'Task·'I.~C.bäEi. : .::", :::,' I,' ~ ::,1, I'.: :,': '. :",,':: "';, ':.' :'::, I '.~: :I:~" ,I ';,,1 'i ':.:; ,'I;~.",:·' ! :,/1:, :":'.'' ';A>: : :,"; ,< .',":;,,: ;". ~:: ::," ,,':,' ,:: ),1 I:. ; ':',','.,.: 1':;,1,1.1, ,"~: '11. ,':: ','.:: 6/2/2002 01 :00 - 01 :45 0.75 CASE P 01 :45 - 03:00 1.25 CEMT P 03:00 - 03:45 0.75 CEMT P 03:45 - 04:00 0.25 CEMT P 04:00 - 04:45 0.75 CEMT P COMP COMP COMP 04:45 - 05:45 1.00 CEMT P 05:45 - 06:30 0.75 CEMT P 06:30 - 07:15 0.75 CEMT P 07:15 - 07:30 0.25 CEMT P COMP 07:30 - 09:00 1.50 CEMT P COMP 09:00 - 09:15 0.25 CEMT P COMP 09:15 - 09:30 0.25 CLEAN N CEMT COMP 09:30 - 11 :45 2.25 CLEAN N CEMT COMP 11 :45 - 14:00 2.25 CLEAN N CEMT COMP 14:00 - 14:30 0.50 CLEAN N CEMT COMP 14:30 - 16:10 1.67 CLEAN N 16:10 - 21:00 4.83 CLEAN N 21 :00 - 23:30 2.50 CLEAN N Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:58 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ",,:', :.: ;>' ,', ,:, .: 1',1': ,:"::' ,1'"1':::' I:, ::' i.:'::'~ " :,....'.....:.,..,:,.:,.~. a'.., ,tCl.·,· ··'.:.·.1.. ""I"",:,I~,",i~L,:1 6/3/2002 00:00 - 02:00 2.00 CLEAN N 02:00 - 04:00 2.00 CLEAN N 04:00 - 05:00 1.00 CLEAN N 6/2/2002 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: .... :::'~'r6:~·i7f'b:'·,·,Hòbr$ ,·:::,·....i~Sk"·:.·..\Cb,d~.,·.:~'~t,'·,,:·,··~h~$~:::,'1.·..:,.';'/:.1,:..,:'",... Ii, .::rl.,:I<:'b:i.$þ¡ "ti6h·~f·'Ó'·eråtr ·.0.5' "I:;.'" . '.:. I:·;.',:."· .,: ,I : .·1 . I..:':.' ...1··:::., :.'·i· ,:'.} .,..,'.'.';. ..'! '.'(.,,1,";1.:',,::'.: ',.':.,1) ·'11 :.1,..:· .'.,. ':' :,'.:. .,/: :.,.' ,..," I, ).' . . . ;'..' :...:,:?:'''.:.I. ,... fH '...:.';,:::,....,., .,,~: ". .' :.,::~ '..1: . . 21 :00 - 23:30 2.50 CLEAN N CEMT COMP torque/overpulls from rubber or metal on bottom. Drilled to 11530 ft. Milling cement, 1.1 bpm, 2550 psi, 35 FPH. Milled to 11,550 ft. Pumped 15 bbl high vis sweep. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 50 fph. Milled to 11,650 ft. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 40 fph. Milled to 11,730 ft. Pumped 10 bbl high vis sweep. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 40 fph. Milled to 11,755 ft. Stall with overpull, pulled to top of liner clean, RIH to bottom clean. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 40 fph. Milled to 11,790 ft. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 50 fph. Milled to 11,855 ft. Wiper trip to TOL. Motor stall & hung-up @ 11035'. Pull free with 10k overpull. Backreamed 2x to TOL. RBIH clean to btm. Milling cement, 1.1 bpm, 2600-2900 psi, 1500# WOB, 35fph. Milled to 12003 ft. Pumping 5bbls regular bio-sweeps per 50ft. Wiper trip clean to TOL. RBIH clean to btm. Milling cement, 1.1 bpm, 2700-3000 psi, 1500# WOB, 30fph. Milled to 12064ft. Pumping 5bbls regular bio-sweeps per 50ft. Wt stacking & pulling heavy. Can't get enough WOB. Mix-up & pump 5 bbls of hi-vis 3% lubetex pill. Milling cement, still stacking wt. Pump 10 bbls high vis pill with 3% lubtex. Up wt ;:: 29K, Own Wt ;:: 9K, 3K more drag in last 12 hrs of drilling. Drilled to 12,080'. Milling cement, added 1 % Lubetex to system to reduce drag [3 drums). Circ. slicker fluid around while milling cement. Milled to 12,100 ft. Lubetex reduced drag by 1500#, but ROP only 10-20 FPH. POOH. 1.1 bpm, 2800 psi, 28K up wt. Pulled into something at 11420 ft. [very close to where we started milling on LWP [11,450']]. Bit stuck. pulled 8K over. Worked pipe from 30k - [-8K], ten times. Worked pipe. Bit stuck, full returns, pump 1.0 bpm at 3600 psi. Surged well with 1000 psi while working CT from 30K to -8K. Pulled up to 40K, and 45K. Pulled 45K and opened Baker choke and pulled free at 00:30 hrs. POOH. Bit Stuck at 11 ,420 ft. Work free at 45K up wt and opening Baker choke drop CT press. Pull up clean with 28K. above stuck point. POOH. pump 1.0 bpm, 2800 psi. SAFETY MEETING. Review standing back 1" CSH workstring procedure and hazards. Stand back 34 stds of 1" CSH. UO mill, motor and MHA. MIU new 1.875" He 0331 mill, new 23:30 - 00:00 0.50 CLEAN N CEMT COMP CEMT COMP CEMT COMP CEMT COMP 05:00 - 06:00 1.00 CLEAN N CEMT COMP 06:00 - 07:45 1.75 CLEAN N CEMT COMP 07:45 - 08:50 1.08 CLEAN N CEMT COMP 08:50 - 14:00 5.17 CLEAN N CEMT COMP 14:00 - 14:45 0.75 CLEAN N CEMT COMP 14:45 - 18:30 3.75 CLEAN N CEMT COMP 18:30 - 20:30 2.00 CLEAN N CEMT COMP 20:30 - 22:45 2.25 CLEAN N CEMT COMP 22:45 - 23:30 0.75 CLEAN N CEMT COMP 23:30 - 00:00 0.50 CLEAN N STUC COMP 6/4/2002 00:00 - 00:30 0.50 CLEAN N STUC COMP 00:30 - 02:00 1.50 CLEAN N CEMT COMP 02:00 - 02:15 0.25 CLEAN N CEMT COMP 02: 15 - 03:30 1.25 CLEAN N CEMT COMP Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:58 PM ) ') 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: I "., ',': >':..:" /" ::" ''';': ;",'I',! \.. '1,\ :': :", :: :::','.<,'1,:\,::: ,::; I ':' :' I .\. :' "î" ,:.'-, :":<"1,:' ~ ",:' ::"''::;:''; I :' .,'" ',.,':: ::":: I ,:-" :..!. I,,' ,: ',' ':", I I ..-:":,'1,'> ',1', : ',',:' :1': " I ,",:, I,:.,,·!,'I: <:':,'":í:~'1 >,':., : ,: ~ '.<! :" \ ¡',·'i. ',~.: ~ ,i: I, . : '/ ',', :.::: :: I j:. ,I' ';' ,': ',': ;'.: ',', ',:'. "-'.' ,',\ ' :" ':',.: ,.,..: II'~ ,':1 , ,':' :' ,':: i, : ' ': ,..::,': ,', I'~ ""~ ":I;,' :;::~':: ", ' .,: ',::" '(I":.,: ",,' . I ! a.:.. , '.' "",···,·"·"·t·"··t,)·,, :Co¡.;¡'"..¡·J;;:.,·I' '''.PiT· ·"'p1.'·'·· .1,:'.' ..,,'.,:."....,.',,.'.,......'. '····1"··'",····,..'··.., '[;)".. ,I.,. ·r"··'" '·f/li'li·,······· ····f,'·'." .,' 1.25 CLEAN N CEMT COMP motor and MHA. Mill was 50% cored, the center diamonds had worn and some were missing. Mill still in gauge. RIH with 1.875" diamond mill on 1.69" motor, MHA and 34 stds of CSH. M/U Baker hyd disc, checks and lockable swivel. RIH with milling BHA (Total length = 2097 ft) to 11410'. Ream/backream previous stuck section to 11470' & did not see any restriction or motor work. RIH to btm. MIlling cement, 1.1 bpm, 3400-3600 psi, 5.5kWOB, & 25fph. Still stacking wt. Up wt = 25k, Dn wt = 10k. Milled to 12135ft. Meanwhile start swapping well to fresh slick 2% KCL. To bring up system to 1 ppb biozan & 1 % lubetex on 2nd circ. Stall & pull heavy . Wiper trip clean to 11500' chasing fresh KCL water up. RBIH clean to btm. New KCL water @ surface. Start adding biozan & lubetex to KCL water. PUH to 11660' to allow newly replaced Nordic gen to cool off. Gen - OK. RBIH & stacked out @ 12100'. Motor stall. P/U & observe pump pressure still climbing. Continue P/U & back down pump. Got stuck with no circulation (packed off). Worked pipe from 40k to -5k - no luck. Pull to 45k & 50k max - no luck. Pressure up to 4600psi - no luck. Surged well with 1000psi WHP & 2000psi CTP. Dumped WHP thru Baker choke - no luck. Continue working pipe from 45k to -8k. Meanwhile call for pump truck to shear burst disc above motor. Pump truck arrive onsite. RIU hard lines. PJSM with all personnel for HP pumping operations. Reviewed HAlHM for planned activities. Stress good communication & need to stay off HP lines. PT cement line. Press up to 5100 psi and broke circulation. Pump 4000 psi at 0.6 bpm. Work pipe with 50K - [-8K). Swap to rig pump. Pump 3700 psi at 0.6 bpm. Circ. high vis / 3% lubetex pill to bit. Rate increased to 0.8 bpm at 3400 psi. Circ. 0.9 bpm, 3400 psi. Slick high vis pill outside CT. Work CT 55K to -8K, No luck. Pump 20 bbl crude. Drop 0.5" steel ball to open circ sub. Displace with 14 bbl crude and swap to 1.5# biozan water. Circ. 0.9 bpm, 3400 psi. Circ. ball off reel and let fall. Pull60K with 20 bbl crude outside CT. Work CT 60K to -8K. No luck. Press up backside to 1420 psi. Work CT 60K to -8K. No luck. Crude on backside. Circ. Biozan and work CT. Work CT 65K to -8K. Pull65K and open Baker choke 3 times. Work CTwith 65K to -8 K with no pump. MD = 12,074' at 61K. Pull 65K, circ and open Baker choke to dump press. Still stuck. Open circ Baker sub with .5" ball on seat. Circ. 1.0 bpm, at 2000 psi. Circ. 1.7 bpm at 3830 psi. Circ. 1.5 bpm 2900 psi and work pipe 66K to -8K. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I ,'I'~::. ,,:.·,,~I;;:'!, ,;',.:'1,1', :,. :. "::",':','1:'1:,::,.::, I,: :::::', :,:':,:.:'I,:;'''~.':';.:''." .:~'~,": ,;.,:'·Jp~!~,:,i..·I'ift~'~;f·~~': 6/4/2002 02:15 - 03:30 03:30 - 05:00 1.50 CLEAN N CEMT COMP 05:00 - 07:30 2.50 CLEAN N CEMT COMP 07:30 - 09:15 1.75 CLEAN N CEMT COMP 09: 15 - 09:45 0.50 CLEAN N CEMT COMP 09:45 - 10:00 0.25 CLEAN N RREP COMP 10:00 - 13:00 3.00 CLEAN N CEMT COMP 13:00 - 13:30 13:30 - 13:45 0.50 CLEAN N 0.25 CLEAN N CEMT COMP CEMT COMP 13:45 - 16:15 2.50 CLEAN N CEMT COMP 16:15 - 18:30 2.25 CLEAN N CEMT COMP 18:30 - 19:30 1.00 CLEAN N CEMT COMP 19:30 - 21 :30 2.00 CLEAN N CEMT COMP 21 :30 - 23:30 2.00 CLEAN N CEMT COMP Spud Date: 5/24/2002 End: 6/6/2002 I.': Hold 60k pull on coil. Call out Nitrogen, plan to displace CT Printed: 7/1812002 3:05:58 PM ) ) Legal Well Name: 15-30 Common Well Name: 15-30A Event Name: REENTER+COMPLETE Start: 5/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 6/6/2002 Rig Name: NORDIC 1 Rig Number: 6/4/2002 21 :30 - 23:30 2.00 CLEAN N CEMT COMP with N2. Rig up Dowell nitrogen truck. Pump 30bbl slick pill (1.5ppb bio + 3% Lubetex) ahead of N2. Shut down for PJSM. Pre Job Safety meeting prior to pumping nitrogen down coil. Begin pumping N2 down coil at 1000scf/min. ConLPumping N2 down coil 2600psi @ 1000scf/min Continue pumping N2 to displace coil. 1000scf/min @ 2900psi, still holding 58k up weight on string. 1000scf/min @ 3100psi. 48000scf of N2 away at 3595psi. Shut down N2, pumped a total of 50000scf of N2. 38bbls of returns on the micromotion out meter while pumping N2. Rig down N2 truck. Slowly bleed coil pressure via baker choke to possom belly, trap 500psi on coil. Work pipe, pull up 65k, slack off, pull 65K and hold. Slack off, pull 65K. Pressure up on backside to 1500psi, cycle to 65K several times, slack off to -8K. Pull to 65K a few more times. Nothing. Pull up 65K and dump well head pressure. Nothing still stuck. Bleed down coil. Continue cycling pipe as we bleed down CT. PJSM prior to circulating out N2 to surface. Pump max rate to fill coil and displace N2. At 43bbls away see wellhead pressure response. Hold CTP constant at KRP and circulate out N2. Pump approx 108bbls, observe clean returns, shut well in and monitor. Dead well. Drop & launch 5/8" ball to disconnect from BHA just above cire-sub, motor and mill. 42.5 bbls to ball seat, pump 1.4 bpm, Ball not on seat at 50 bbls, cycle pump. Pump 11 bbl very high vis pill to carry ball on seat. Pump 2 coil volumes, cycle pump. Ball still not on seat. Drop 5/8" Delcron ball, Displace with high vis pill at 1.4 bpm. Pump 60 bbls. Ball not on seat. Check for ball on surface. No ball. Pump 10 bbls high rate. Cycle pump, 2 bpm to 0 bpm. pump 20 bbl at 1.4 bpm. Not free. Drop second Delcron 5/8" ball and displace. Heard ball moving inside CT. Pumped 52 bbls. no indication of ball on seat. Pull 65K. Press up backside to 1400 psi and pull 65K. No pipe movement. Pump 2" X 4 " soft permeable foam pig to chase balls. Circ. Had press spike at 35 bbls. Pump at 2000 psi and foam pig landed at 42.5 bbls (200psi bump in pump pressure, no pressure change when it went through other profile - upper disconnect). Pick up free with 28K up wt - similar to upweight before stuck. POOH. Layout Baker tools. Get ready to stand back CSH workstring. SAFETY MEETING. Review "Getting HSE Right" concepts and present HSE fundamentals with the day crew. Review standing back CSH Stand back 68 joints of 1" CS Hydril in doubles. Recovered all three balls, found six chunks (larger than 5/8", smaller than 3/4") of cement, some foam. (had installed a valve to isolate micro mulsion prior to bursting disk, knocked cement loose) Cut 200' of coil and weld on new eTC. Pull test I Pressure test CTC 23:30 - 23:55 0.42 CLEAN N CEMT COMP 6/5/2002 23:55 - 00:00 00:00 - 01 :00 0.08 CLEAN N 1.00 CLEAN N CEMT COMP CEMT COMP 01 :00 - 02:40 1.67 CLEAN N CEMT COMP 02:40 - 03:00 03:00 - 03:20 03:20 - 04:45 0.33 CLEAN N 0.33 CLEAN N 1.42 CLEAN N CEMT COMP CEMT COMP CEMT COMP 04:45 - 06:45 2.00 CLEAN N CEMT COMP 06:45 - 09:00 2.25 CLEAN N CEMT COMP 09:00 - 10:00 1.00 CLEAN N CEMT COMP 10:00 - 10:45 CEMT COMP 0.75 CLEAN N 10:45 - 13:00 2.25 CLEAN N CEMT COMP 13:00 - 13:15 0.25 CLEAN N CEMT COMP 13:15 - 13:30 0.25 CLEAN N CEMT COMP 13:30 - 15:30 2.00 CLEAN N CEMT COMP 15:30 -17:00 17:00 - 17:15 CEMT COMP CEMT COMP 1.50 CLEAN N 0.25 CLEAN N Spud Date: 5/24/2002 End: 6/6/2002 Printed: 7/1812002 3:05:58 PM ) ) 15-30 15-30A REENTER+COMPLETE Start: 5/24/2002 NORDIC CALISTA Rig Release: 6/6/2002 NORDIC 1 Rig Number: ··\;Ff6~'·:~'id::·:·:~'bili~~::J:·:··l~~·k',è6d~"N~Î"'::···~~:ä~~: ,I :\:.';:: ,.:'..',. I, .' I " . Deseri~tio~' of 'a'p' e~~ions '.. ..... .:...¡.,;,'..·,..;.¡i..,..·'....,..:.....·I..,...i.,........,.:,'.',:..,..> ;:....... ",':.....>,,'.::.'..,.,;'.. ..... .:.: ,'" ',....' I " \1 , ~. ,. ,'~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 6/5/2002 17:15-21:50 21 :50 - 23:45 23:45 - 00:00 4.58 BOPSUR. N 1.92 CLEAN N 0.25 CLEAN N CEMT COMP CEMT COMP CEMT COMP 6/6/2002 2.08 CLEAN N CEMT COMP 00:00 - 02:05 02:05 - 04: 15 04:15 - 05:00 2.17 CLEAN N 0.75 CLEAN N CEMT COMP CEMT COMP 05:00 - 07:00 2.00 CLEAN N CEMT COMP 07:00 - 07:15 0.25 CLEAN N CEMT COMP 07:15 - 08:00 0.75 CLEAN N CEMT COMP 08:00 - 09:00 1.00 CLEAN N CEMT COMP 09:00 - 10:30 10:30 - 11 :30 11 :30 - 13:30 13:30 - 15:00 CEMT COMP CEMT COMP CEMT COMP CEMT COMP 1.50 TA N 1.00 TA N 2.00 TA N 1.50 TA N Spud Date: 5/24/2002 End: 6/6/2002 BOPE Test, witnessed Waived by John Spalding Waiting on Schlumberger single shot and chemical cutters. Pre Job SAFETY MEETING with Bob Staats and rig team. Emphasized safety with strip guns (string shot), similar to running perf guns: keeping people out of cellar while deploying the tool and RIH carefully with the hydril to avoid damaging strip guns. Discussed E-fire process. Make up Schlumberger String shot with e-fire head, 19 joints of 1" CS Hydril and 2.625" NoGo. RIH with string shot assembly at approx. 90fpm Slow RIH speed to 20fpm as we approach liner top. Tag up lightly at 11,038'... believed to be liner top. (liner top expected at 11,056') Set down approx. 20001bs. Work string shot at liner top (2.25" id deployment sleeve inside 3.5" tubing), bottom of the tool has a 3' long 1-1/16" round bullnose (same one we run on perf guns). PU, bring on pumps 0.7bpm @1150psi. Attempt to RIH past liner top, no luck. Repeatedly setting down on liner top every time we try to RIH past 11,038'. PU, Pump down backside, RIH attempt to get past 11,038', unable to proceed. Discuss options...POOH POOH with string shot assembly SAFETY MEETING. Review procedure and hazard mitigation for standback CSH. Stand back 1" CSH workstring. Layout Baker tools and SWS firing head. Found string shot tool parted at top of string shot leaving 10' of steel metal strip in hole and 3' of 1.69" OD guide tube on bottom. Top of fish at 11,043'. Fish setting on top of 2-3/8" liner top at 11,056 ft. RIH with nozzle on CT. Freeze protect 3-1/2" liner with diesel as per program. POOH. Clean rig pits. Supersuck cuttings tank. Nipple down BOPE. RELEASED RIG ON 15-30AAT 15:00 HRS. TOTAL TIME ON WELL WAS 13 DAYS AND 6.5 HOURS. Moved Rig down pad to 15-31 A. Printed: 7/18/2002 3:05:58 PM ) ) ) Well: Field: API: Permit: 15-30A, Operations Shutdown Prudhoe Bay Unit 50-029-22282-01 202-089, Approval #302-182 Rig Accept: Rig Spud: Rig Release: Drilling Rig: OS/24/02 OS/26/02 06/06/02 Nordic #1 POST RIG WORK 06/08/02 ATTEMPTING TO FISH 13' OF STRING SHOT, RAN WIRE GRAB AND SPECIAL OVER SHOT SET UP. 06/09/02 PULLED 20' PRIMER CORD AND 70" OF STRIP GUN. 06/10/02 PULLED OUT LAST 4' OF STRIP GUN WI BULL NOSE ASSEMBLY 3.21". TAG LINER TOP WI 2.50" LIB, CLEAN PICTURE. LEFT WELL SHUT IN (PRE CTD). NOTIFY DSO OF WELL STATUS. 06/12/02 DRIFTED 2 318" LINER WI 1.85" SWAGE TO 11,220' WLM, ALL CLEAR. NOTIFIED PAD OP. OF WELL STATUS. 06/30/02 RIH WI 1.8" JS NOZZLE TO 11705'. JET LINER WI SLICK WATER. JET LINER WITH 10 BBLS OF 7.5% HCL. CIRCULATE ACID OUT OF HOLE. CHAIN INSPECTION. REPLACE BEARING. PU 1-11/16" MHA & SWS MEMORY GR/CCL. LOG GR FROM 11700' TO 11000'. FLAG COIL @ 11500'. POH. 07/01/02 POH. MAKE FLAG CORRECTION. MU CHEMICAL CUTTER AND E-FIRE HEAD. RIH. TIE-IN TO COIL FLAG. POSITION CHEMICAL CUTTER AT 11610'. PERFORM PRESSURE SEQUENCE TO ACTIVATE FIRING HEAD. GOOD INDICATION OF FIRING. POH. GOOD INDICATION FI CHEMICAL CUTTER DETONATION. BOW SPRINGS SEVERELY DAMAGED. CUT PIPE. PU GS SPEAR, JARS & BHA. OAL=12.0'. RIH. LATCH LINER @ 11060'. PULL 8K# OVER, JAR LINER FREE. PU 130'. RIH, SLIGHT WEIGHT SET @ 10955'. PUMP OFF LINER @ 10960'. POOH. FP BACKSIDE WI METH/WTR.RDMO. JOB COMPLETE. ) ) .... BAKER IlUGHlS INTEQ ObP BP Baker Hughes INTEQ Survey Report Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 15 15-30 15-30' '6\ Date: 7/18/2002 Time: 14:09:12 Page: Co-ordinate(NE) Reference: Well: 15-30, True North Vertical (TVD) Reference: 44 : 30 8/4/1992 00:00 64.0 Section (VS) Reference: Well (0.00N,0.00E,47.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.236 N 148 34 21.213W True 1.34 deg Well: 15-30 Slot Name: 30 15-30 Well Position: +N/-S 949.09 ft Northing: 5959811.01 ft Latitude: 70 17 44.570 N +E/-W 1060.96 ft Easting : 677335.32 ft Longitude: 148 33 50.290 W Position Uncertainty: 0.00 ft Well path: 15-30A 500292228201 Current Datum: 44 : 308/4/199200:00 Magnetic Data: 6/5/2002 Field Strength: 57535 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 15-30APB 1 11534.19 ft Mean Sea Level 26.27 deg 80.82 deg Direction deg 47.00 Height 64.00 ft Survey Program for Definitive Well path Date: 7/18/2002 Validated: Yes Actual From To Survey ft ft 439.00 11440.92 11450.00 11534.19 11564,24 13083.00 Version: 7 Toolcode Tool Name 1 : MWD - Standard (0) 15-30APB1 (1) MWD MWD MWD MWD MWD - Standard MWD - Standard MWD - Standard Annotation MD TVD ft ft 11534.19 8764.83 KOP 13083.00 8768.13 TD Survey: MWD Start Date: 6/1/2002 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10OO 11534.19 73.73 32.91 8764.83 8700.83 5503.66 3904.56 5965404.91 681108.69 6609.10 0.00 11564.24 65.24 31.79 8775.35 8711.35 5527.41 3919.62 5965429.00 681123.18 6636.31 28.47 11594.03 72.19 27.15 8786.17 8722.17 5551.56 3933.23 5965453.47 681136.23 6662.74 27.47 11624.61 79.42 27.01 8793.66 8729.66 5577.94 3946.72 5965480.16 681149.09 6690.60 23.65 11654.36 89.45 22.66 8796.54 8732.54 5604,78 3959.13 5965507.28 681160.86 6717.97 36.71 11685.04 94.06 12.04 8795.60 8731,60 5634.00 3968.26 5965536.70 681169.30 6744.58 37.71 11728.76 95.10 355.48 8792.09 8728.09 5677.33 3971.11 5965580.09 681171.13 6776.22 37.83 11751.32 97.70 355.31 8789.57 8725.57 5699.68 3969.32 5965602.38 681168.80 6790.14 11.55 11781.81 96.83 1.98 8785.71 8721.71 5729.89 3968.60 5965632.57 681167.37 6810.23 21.89 11811.23 93.63 4.08 8783.03 8719.03 5759.14 3970.15 5965661.85 681168.23 6831.31 12.99 11840.94 92.18 2.34 8781.52 8717.52 5788.77 3971.81 5965691.50 681169.19 6852.73 7.62 ) BP ) II¡¡. ObP BAICD. HUGIIIS Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 7/18/2002 Time: 14:09:12 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-30, True North Site: PB OS 15 Vertical (TVD) Reference: 44 : 30 8/4/1992 00:00 64.0 Well: 15-30 Section (VS) Reference: Well (0.00N,0.00E,47.00Azi) Wellpath: 15-308 '8 \ Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11871.01 90.03 2.53 8780.94 8716.94 5818.80 3973.09 5965721.56 681169.76 6874.15 7.18 11904.36 91.17 13.52 8780.59 8716.59 5851.77 3977.74 5965754.63 681173.63 6900.03 33.13 11935.66 90.25 16.03 8780.21 8716.21 5882.03 3985.72 5965785.07 681180.90 6926.51 8.54 11965.49 91.14 20.29 8779.84 8715.84 5910.37 3995.01 5965813.61 681189.52 6952,63 14.59 11997.54 89.69 26.76 8779.61 8715.61 5939.74 4007.80 5965843.27 681201.61 6982.01 20.69 12027.53 90.68 34.02 8779.51 8715.51 5965.59 4022.96 5965869.47 681216.15 7010.73 24.43 12056.89 90.89 42.49 8779.11 8715.11 5988.62 4041 . 12 5965892.93 681233.76 7039.72 28.85 12087.50 88.90 48.75 8779.17 8715,17 6010.02 4062.99 5965914.83 681255.12 7070.30 21.46 12117.55 88.83 57.44 8779.76 8715.76 6028.04 4086.99 5965933.42 681278.68 7100.15 28.91 12147.38 87.73 65.64 8780.66 8716.66 6042.24 4113.18 5965948.23 681304.53 7128.99 27.72 12177.26 90.09 66.43 8781.23 8717.23 6054.37 4140.47 5965961.00 681331.53 7157.22 8.33 12206.99 88.50 58.08 8781.60 8717.60 6068.20 4166.76 5965975.44 681357.48 7185.88 28.59 12237.14 87.85 48.21 8782.56 8718.56 6086.25 4190.84 5965994.05 681381 . 13 7215.80 32.79 12267.95 87.70 43.03 8783.75 8719.75 6107.78 4212.84 5966016.09 681402.61 7246.57 16.81 12302.76 87.79 39.97 8785.12 8721.12 6133.83 4235.88 5966042.67 681425.03 7281.19 8.79 12336.42 88.44 32.29 8786.23 8722.23 6160.98 4255.70 5966070.28 681444.21 7314.20 22.89 12368.73 85.43 25.22 8787.96 8723.96 6189.24 4271.22 5966098.90 681459.05 7344.82 23.75 12398,80 90.71 21.89 8788.98 8724.98 6216.78 4283.22 5966126.71 681470.40 7372.38 20.75 12427.56 96.30 22.18 8787.22 8723.22 6243.37 4293.98 5966153.56 681480.53 7398.39 19.46 12458,99 97.72 26.51 8783.38 8719.38 6271.79 4306.84 5966182.26 681492.71 7427.17 14.40 12487.13 96.64 30.52 8779.86 8715.86 6296.31 4320.17 5966207.10 681505.45 7453.65 14.65 12517.77 99.22 35.23 8775.63 8711.63 6321.79 4336.63 5966232.96 681521.31 7483.06 17.40 12547.03 95.23 48.34 8771.94 8707.94 6343.38 4355.93 5966254.99 681540.10 7511.90 46.48 12577 .49 90.83 52.86 8770.33 8706.33 6362.67 4379.43 5966274.83 681563.13 7542.24 20.69 12607.12 88.50 58.06 8770.50 8706.50 6379.46 4403.83 5966292.19 681587.12 7571.54 19.23 12637.94 88.56 62.73 8771.29 8707.29 6394.68 4430.61 5966308.03 681613.53 7601.50 15.15 12667.64 87.33 67.34 8772.36 8708.36 6407.20 4457.51 5966321.19 681640.13 7629.72 16.05 12699.97 87.45 71.80 8773.83 8709.83 6418.47 4487.76 5966333.17 681670.11 7659.53 13.79 12739,73 91.67 76.76 8774.14 8710.14 6429.24 4526.01 5966344.83 681708.09 7694.85 16.38 12771.59 90,97 80.69 8773.40 8709.40 6435.47 4557.24 5966351 .79 681739.17 7721.94 12.53 12803.38 89.17 79.87 8773.36 8709.36 6440.83 4588.58 5966357.90 681770.36 7748.51 6.22 12833.40 88.40 74.29 8774.00 8710.00 6447.54 4617.82 5966365.29 681799.44 7774.47 18.76 12864.04 89.85 69.61 8774.47 8710.47 6457.03 4646.94 5966375.47 681828.32 7802.24 15.99 12897.60 92.03 63.65 8773.92 8709.92 6470.33 4677.72 5966389.49 681858.78 7833.83 18.91 12930.22 90.74 55.66 8773.13 8709.13 6486.80 4705.84 5966406.61 681886.50 7865.62 24.80 12960.24 91.75 48.51 8772.47 8708.47 6505.23 4729.51 5966425.59 681909.72 7895.50 24.05 12990.22 92.42 41.83 8771.38 8707.38 6526.34 4750.74 5966447.20 681930.45 7925.42 22.38 13021.03 91.87 34.61 8770.23 8706.23 6550.51 4769.78 5966471.81 681948.91 7955.83 23.49 13049.02 91.96 36.34 8769.29 8705.29 6573.29 4786.01 5966494.97 681964,60 7983.24 6.19 13083.00 91.96 36.34 8768.13 8704.13 6600.64 4806.14 5966522,79 681984.08 8016.61 0.00 BP Amoco Parent Wellpath: Tie on MD: WELLPATH DETAILS 1S·3CH1 '61 500292228201 15·30APB1 11534.19 Nordic 1 44 : 30 8/41199200:00 54.00lt Rig: Ref. Datum: V.Sectlon Origin Origin Angle +N/-S +E/·W Starting From TVD 47.00· 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E~ Reference: Well Centre: 15-30, True North Vertical (rVD Reference: System: Mean Sea Level Section (VS Reference: Slot - 30 (O.OON,O.ooE) Measured Depth Reference: 44: 30 8/4/1992 00:00 64.00 Calculation Method: Minimum Curvature ANNOTATIONS lVD MD Annotation T\{) ..-NJ.$ .E1JN sn.ap. :~H~ !~~: 5:~ li~~ ~ ~~H01 !rn~ æl-U hi~ ~ 8700.83 11534.19 KOP 8704.13 13083.00 TO 8200 8250 8300 8350 - C æ8400 o 11)8450 - =8500 a. & 8550 ~ 8600 ~ 8650 > œ8700 ~8750 ~ 8800 8850 8900 8950 ObP 7100-:::--- 7000-= . 6900--=' - 6800 6700--= - 5800-: . 5700--= --- 5600--=--- 5500-= ,---- 5400-.:.; ~--- m... BIlL. INTEQ LEGEND T 1~~n~~~·Plan'102 ^ M 15_30 (15_30APBI) ! ,~ e- Azimuths to True North Magnetic North: 26.27" Stre~~~~;~~;~~~ Dip Angle: 80.82· Date: 6/5/2002 Model: BGGM2002 Created By: Bnj Potnis Contact Informatiow Direct (907ì 26n;-613 E·mail brij,potnis@inteq.com Baker Hughes INTEO: (907) 267 -6600 - ------~--. -- --- --- --. -- - - -~--- ---- -- ----- --------------~-- ------~-_._-- - ------~--- - --~------.--~--- - -------- -~_.-- ~--~ ---.------ --- -- Wellpath: (15-30/15-30A) Dale: 7/18/2002 -------- --- 15_30.15_30A,PI~n #1021 ~- 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 West(-)/East(+) [100ft/in] ':'6600"'::: - .5 = 56500 ~. __ _~~~n_~___ __~~~__-=-__________. o _ 'I"" 6400- - -- - + 6300-= - - :c = 1:: 6200--= · o - Z = :;:::;..6100-::-- I -- :C60OO"'::: · ., ~ ::::I = o ~ en 5900 -=-- ._-------~ ._-----~ . -- ----~_. - ~-- ---~- "---. ----, - -------- --~-----~----- ----- ~._~--- ---~--_. - ----- ---- - ------- . ---------- -- -- --------"- ------"---- ------ -- --- --------- .,-/ .- )~I:5-3:0.:0A,~a:n#:1021 - -- ~ \ 15_;0(15_30)1- ._--_..~.-~--_._- 6550 6600 6650 6700 6750 6800 6850 6900 6950 7000 7050 7100 7150 7200 7250 7300 7350 7400 7450 7500 7550 7600 7650 7700 7750 7800 7850 7900 7950 8000 8050 8100 8150 8200 8250 8300 8350 8400 8450 Vertical Section at 47.000 [50ft/in] 7/18/2002 2:11 PM 15_30 (15_30APB1)t . , - _n____C_ - - ----- ------- ---------_._~ -------------- - -- ---------------- - ~------- - ----- -- ------ -- -~~---- --------~ - - - -------------------- . - ---------- ___ __~_______~_ _____ _______ -______0____" _____ --------- - -"-- - ----- - ----- - --- ---- -~._--------_.- ---------- - - .------------ -_______.-------O---____------.---,-~_~ __~____~_T___·___·_______ ',\ ) ) Dp To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: June 6,2002 Re: CTD Sidetrack of well 15-30 Drlg Permit No. 202-089 Nordic 1 coil drilling rig has experienced problems during the completion of 15-30a. During cementing, the wiper plug stopped early and we were unable to circulate the cement out of the liner. During milling of the cement inside the 2 3/8" liner we became stuck with motor and mill, the coil was disconnected and recovered, leaving the motor and mill at -12,1 OOft with about 900ft of cement left to mill out. ",/ We've decided not to pursue fishing the motor and mill but to cut and pull the 2 3/8" liner and do an open hole sidetrack for the same target. As we commenced to cut and pull, we proceeded to leave another fish in the hole on top of the 2 3/8" liner. The rig will move off, allow slickline to complete the fishing job and the plan is to move Nordic back from 15-31 to 15-30. ./ The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the present and proposed sidetrack is attached for reference. 1. Move Nordic off 2. Fish strip charge from liner top with slick line 3. Move Nordic back on. 4. Run chemical cutter on coil tubing, cut 2 3/8" liner at 11,610' 5. Pull 2 3/8" liner 6. Spot cement in 3" open hole from top of liner to window, WOC. 7. Kick off from cement plug, drill for same target. / Nordic is moving today, fishing will commence as soon as possible. fr!. j ~MJiaar;f/ M.S. Endacott CTD Drilling Engineer CC: Well File Terrie Hubble ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL o Suspend 0 Plugging 0 Time Extension 0 Perforate o Repair Well../ 0 Pull Tubing 0 Variance 0 Other 181 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate \ '"t,,, 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program 2. Nàme of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1702' SNL, 1390' EWL, SEC. 22, T11 N, R14E, UM At top of productive interval 3182' NSL, 4847' EWL, SEC. 15, T11N, R14E, UM At effective depth At total depth 4894' NSL, 1219' EWL, SEC. 15, T11N, R14E, UM 12. Present well condition summary Total depth: measured \}J6Æ- ~/7/oL .6(7 6//; ~H- OP-S' 5. Type of well: 181 Development o Exploratory o Stratigraphic o Service 6. Datum Elevation (OF or KB) RKB = 64' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number v' 15·30A 9. Permit Number 202-089 10. API Number 50- 029-22282-01 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool (As Planned) true vertical Effective depth: measured true vertical 13083 feet 8704 feet feet feet Casing Structural Conductor Surface Intermediate Production Liner Liner Length Size 80' 20" 3801' 13-3/8" 10535' 9-5/8" 2390' 7" 2027' 2-3/8" Perforation depth: measured None true vertical None Plugs (measured) 2-3/8" Liner full of cement, cleaned out to about 12100', where the first BHA became stuck. Junk (measured) First BHA stuck in hole at about 12100', second BHA stuck in hole at about 11056' Cemented MD TVD 2880 cu ft CS III, 1326 cu ft 'G' 110' 3838' 110' 3522' 2543 cu ft Class 'G1 10568' 8299' 487 cu ft Class 'G' 10263' - 11534' 8119' - 8764' 10 cu ft Class 'G' 11056' - 13083' 8569' - 8704' (Estimate TOC in annulus at 12600k E eEl V E D JUN 0 6 2002 A.laska Oil & (1('):';': ;r1l'1!'! >,,01\" ,.-:c' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 34'; 3-1/2",9.3#, 13Cr80 to 1103IRti[:~..¡t;Le1~; 12.6#, L-80 to 110431; 3-1/2",9.3#, 13Cr80 to 11534' Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker 'SABL' packer at 11036'; 3-1/2" Camco 'TRDP-4A-SC' SSSV Nipple at 2111' 14. Estimated date for commencing operation June 6, 2002 16. If proposal was verbally approved Tom Maunder 6/6/2002 Name of approver Date Approved Contact Engineer Name/Number: Mary Endacott, 564-4388 17. I ~erebY certify that the foregoing is true and correct t~ best of my knowledge Signed Mary Endacott ffJ..... ~.. ~tflltl'. ,i.tl.e.. .... . C.. T........D.. rill.ing E. n. g'. ,ineer ,'.' ;-. LJ 'CommissiorrUsepnly Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test _ Øn~ Gym required 10- 404 Cammy Oechsli Taylor Approved by order of the Commission Form 10-403 Rev. 06/15/88 13. Attachments 181 Description Summary of Proposal o Detailed Operations Program o BOP Sketch 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 Date ~ /6/() 2 I Approval No·3 Oc.;l- /fj;;L Commissioner Date (¿/¡q~ Submit In knp,i~te f¡ L_ i~EE = ~, i, FMC WELLHEAD = McEVOY ÷CTUÃTÕR';···'õiÎSM7ÕÛH~2"2Õ2' ....w,',.,''''''w..-.'.'.'.·.....',',','".',ñ'.',·....,w.·.','.'.'.'.'.'.'.''''''.....'''.·.'.-.'.·,..·.'..'.'.'.'.,.w.'..'..'.','"','o\'.w,',',',',,,,,.,,,,,',,',',',.',',',',,',', KB. ELEV = 64' BF:~ËV""';,"Wf,','w,"'" ... ··.·w....·.·,'. .'."'..".~,..w..,...................., 'KOP';^"""^""'^""--'''"''"''''''''''''''12ã6;' MaxÃñgTë~;^-'M~W_"-95"@-12356; Datum-M'D ;;MwM_~~""~-"'-'-""12 1"16Î 'õãiüñî·'T\iD';;"·-....·'·..·..··'··'....·äãõQì..SS ') 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 34' 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 3838' ~ I TOP OF 7" LNR 1-1 10263' I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10568' r--4 Minimum ID ~ 13-1/2" TBG, 9.3#, 13-CR-80, FOX, 0.0087 bpf, ID = 2.99" 110'.1" strip charge, 3'·1 11/16" bar w J guide shoe I Top of 2 3/8" Liner I Punch Tubing 11 11032' 11043' 11056' 1-1 11100' I Low side 2 string w índow from W/S 1-1 11534' I 13-1/2" TBG, 9.3#, 13-CR-80, FOX, 0.0087 bpf, ID = 2.99" 11 11632' I PERFORA TION SUMMARY REF LOG: GR/PDC 11/01/92 ANGLEATTOPPERF: 59 @ 11002' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 15-30A Proposed CTD Sidetrack ) - ~ ~ d ~ A·OOOOO~ I I l I I I I I I I I I I 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 13000' I--AIII ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 09/06/92 ORIGINAL COMA...ETION 05/17/02 MSE PROPOSED SIDETRACK 09/05/93 LAST WORKOVER 06/06/02 MSE FISH 12/18/00 SIS-lsl CONVERTED TO CANVAS 02/14/01 SIS-MD FINAL 01/09/02 RNlTP CORRECTIONS SA') NOTES: LDL INDICATES 7" LNR LAP LEAK @ 102,-_ "'CEMENTED 4/3/98. CMT COLLAR 2.76"ID FROM 9600' TO 11032' REMOVED WHEN (8/99) RlH, MILL SWN TO 2.81". 34' 1-1 4-1/2" x 3-1/2" XO I 2111' 1- 3-1/2" CAMCOTRDP-4A-SC SSSV NIP, ID = 2.812" GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 3405 3195 39 MMG RK 2 6544 5479 44 MMG RK 3 8615 6997 44 MMG RK 4* 10023 7971 44 MMG RK 5* 10147 8049 52 MMG RK * BEHIND CMT SHEATH 11014' 1-1 3-1/2" OTIS XN NIP, ID = 2.813" I 11036' 1-1 7" x 4-1/2" BAKER SABL-3 PKR, ID = 3.930" 11070' 1-1 3-1/2" PARKER SWS NIP, ID = 2.813" 11100' 1-1 Top of Cement 3 1/2" x 7" I 2-3/8" 4.'7# ST-L Cemented & Perf'ed liner -I 13300' 1 --~;_.. .. _..._~.J::~--l1 I 12600' 1-1 Top of Cement (calc) I I 12100' 1-1 111/16" rrotor and 1,875" 0331 mill 1 12653' 11 7" LNR, 26#, NT80S, NSCC, .0383 bpf, ID = 6.276" PRUDHOE BAY UNIT W8.L: 15-30A ÆRMIT No: 202-089 API No: 50-029-22282-01 SEC 22 T11N R14E, 4264.77 FEL 20.07 FNL BP Exploration (Alaska) ') ) ~~!Æ~E : f !Æ~!Æ~~~!Æ ALASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 15-30A BP Exploration (Alaska), Inc. Permit No: 202-089 Sur Loc: 1702' SNL, 1390' EWL, Sec. 22, TIIN, RI4E, UM Btmhole Loc. 4894' NSL, 1219' EWL, Sec. 15, TIIN, RI4E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 15-30A. 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, (j~fJuU 1::t/ Cammy otchsli Taylor Chair . BY ORDER OF THE COMMISSION DATED thisÆ day of May, 2002 jj c/Enc1osures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 2-3/4" ) STATE OF ALASKA \ ALASKA ÚIL AND GAS CONSERVATION COMMI~d1oN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 64' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028306 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 15-30A /' 9. Approximate spud date 06/10/02 ./ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13300' M D I 8700' TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 930 Maximum surface 2244 VPSig, At total depth (TVD) 8800' I 3300 psig Setting Depth TQD Botom Length MD TVD MD TVD 1950' 11350' 8638' 13300' 8700' If-tGÆ- 4(ZS/02- J-4/~u 1 a. Type of work 0 Drill 181 Redrill ORe-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 1702' SNL, 1390' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 3182' NSL, 4847' EWL, SEC. 15, T11 N, R14E, UM At total depth 48941 NSL, 1219' EWL, SEC. 15, T11N, R14E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well /i ADL 028303,385' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11550' MD Maximum Hole Angle 18. Casinp Program Specifications $Ize Casing Weight Grade COUDlinÇJ 2-3/8" 4.7# L-80 ST-L Quantitv of Cement (include staae data) 51 cu ft Class 'G' IEGEtven Casing Structural Conductor Surface Intermediate Production Liner Slotted Liner 13300 feet 8777 feet 12975 feet 8790 feet Length Plugs (measured) AM 5 2002 -'ØI&Gllec..Cœ1ftÎl8iOrl Tagged PBTD at 12975' (10/19~ 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 Junk (measured) Size Cemented MD TVD 80' 20" 3801' 13-3/8" 2880 cu ft CS III, 1326 cu ft 'G' 10535' 9-5/8" 2543 cu ft Class 'G' 2390' 7" 487 cu ft Class 'G' 544' 4-1/2" Uncemented Slotted Liner 110' 3838' 1101 3522' 10568' 102631 - 12653' 12456' - 13000' 8299' 8119' - 8799' 8808' - 8790' Perforation depth: measured 11470' -11530', 11580'-11656', 11736' -11776', 12376' -12431', 12670' -12970' Slotted Liner: 12654' - 12976' true vertical 8746' - 8763', 8775' - 8789', 8801' - 8806', 8814' - 8810', 8798' - 8790' Slotted Liner: 8799' - 8790' 181 Filing Fee 0 Property Plat 181 Drilling Fluid Program 0 Time vs Depth Plot 181 BOP Sketch 0 Diverter Sketch 181 Drilling Program o Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 20. Attachments Contact Engineer Name/Number: Mary Endacott, 564-4388 21. I hereby certify that the fO, re~gf "e ,. g. , t~ue ~r;ð,e, ' correct t~ th, e b, e,s, t 0, f, my kn, " ~, "~, 'Ie" d, ge . Signed Mary Endacott if J( ~Cj/1J:?VI.Äj!peA.. .. Title CT Dnlllng Engineer , ,', " Commission Use Only , Date cf ó/ f;)1..., .. Permit Number API Number .20 ¿ - 0 r;(? 50- 029-22282-01 Conditions of Approval: Samples Required 0 Yes I8J No Hydrogen Sulfide Measures .s Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: S ' lJngmal Igned b} Approved By Cammy Oechsli Tá~(T) ~ Form 10-401 Rev. 12-01-85 ëc<,,I I \ -I APProZI Df "Î See cover letter :5 I:;" :7\. for other requirements Mud Log Re uire 0 Yes 129 No Directional Survey Required ŒI Yes 0 No D4K D5K D10K D15K ~KPsiforCTU ¡ \:1 /\ qommissioner J .¡ ',1.:' ""C' \ ;~,.._ by order of the commission Date C-) (-J/ÛJ- SÚb~; 11T~Plicate ') BPX 15-30A Sidetrack ) Summary of Operations: / A CTO sidetrack of production we1l1S-30 will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Screen & Prep Well: Screen - MIT-IA. PPPOT-tbg hanger seals. MIT-OA and pressure test tree valves. · Punch holes, (6' interval) in the 3Y2" tbg tailpipe at 11,100' · Set inflatable bridge plug at 11,900' I · Install a 3Y2" mon09ore whipstock at 11,SSO'md, (8,703' tvd), oriented at 210° tool face. · Oownsqueeze 30bbls cement in open perfs and fill 3%" tbg x 7" liner annulus. Phase 2: Drill and Complete CTD sidetrack 2" coil will be used to drill an -1800 ft, 2%" open hole sidetrack, (as per attache,Sf plan) from a 2 string window cut thru 3% tbg & 7" liner. The sidetrack will be completed with 1 ,9S0 ft of solid, cemented & perforated, 2-3/8" liner. Mud Program: · Phase 1: Seawater / · Phase 2: Seawater and Flo-Pro (8.6ppg) 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, liner will be run from 11,3S0'md (TOl, 8,638/TVOss) to TO at 13,300'md. The completion will be cemented in place with approximately 9 bbls (annular volume +40% excess in OH) of 1S.8 ppg class G cement. A liner top packer may be needed due to small <1 bbl volume lap........ Well Control: · BOP diagram is attached. .-/ · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,SOO psi. · The annular preventer will be tested to 400 psi and 2,200 psi. Directional · See attached directional plan. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logg ing · Real time MWO & Gamma Ray logs will be run while drilling the open hole section. · A memory CNUGR/CCl will be run inside liner prior to perforating. Hazards · H2S is minimal on drill site 1S. Max recorded on the pad was 50ppm on 15-21 a, latest reading on 15-30 /' was 18ppm. · Numerous small faults are expected while drilling, and several close approaches are made. lost circulation may be experienced depending on the size of associated damaged zones. Reservoir Pressure Reservoir pressure is estimated to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,244 psi. / L I TOPOF7" LNR 1-1 10263' I '} I 9-5/8' CSG. 47#, L-80.ID = 8.681" H 1 0568' ~ ~ ~ Minimum 10 = 2.750"@ 11620' ~\: ~ I 3-1/2" PARKER SWN NIPPLE ~ ~ 11032' I ,~ V I ~ 8 V: jD \~ TREE = FMC 'WRLI-EAD = I\I1cEVOY . .."..... ...... .. ,..,.."....".......... . ,ACTUATOR = 01lS 70 u-J 2202 KB. ELEV = 64' 'BF.ELEv .~ KOP= Max Angië = Datum MD = Datum TVD = 1286' 95@ 12356' 1211 6' 8800' 58 14-1/2"TBG, 12.6#, L-80, 0.0152 bpf, D =3.958" 1-1 ITOPOF 3-1/2" TBG I" 13-318" CSG, 68#, L-80, ID = 12.415" 1-1 I 3-1/2" TBG, 9.3#, 13-m-80, 0.0087 bpf, ID = 2.99" 1-1 I TOPOF4-1/2" TBGI., 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID=3.958" 1-1 I TOP OF 3-1/2" TBG I" 3-1/2" TBG, 9.3#, 13-m-80, 0.0087 bpf, ID = 2.99" H I TOPOF 4-1/2" LNR I" 17" LNR, 26#, L-80, 0.0383 bpf, D = 6.276" H 14-1/2"LNR, 12.6#, L-80, 0.0152 bpf, D =3.958" H I TOP OF 4-1/2" LNR- SL TD H ) 34' 34' 3838' 11032' 11043' 11043' 11632' 12456' 12653' 12654' 12654' 15-30 ) tit ) SAFETY NOTES: UI.. INJICATES 7" LNRLAP LEAK @ 10263', C8\/I alTED 413198. CMT COLLAR 2.76" ID FROM 9600' TO 11032'. FCO TO 11126' (DUIII PED SAND). 7f1> @ 11532' AND90o@ 12202' 34' H 4-1/2" X 3-1/2" XO I 2111' I- 3-1/2"CAMOOlR[P-4A-SC SSSV NP, ID = 2.812" ~ GAS LIFT MA NDRELS ST MD lVD DEV TYPE V LV LATCH PORT DATE 1 3405 3195 39 M1\h3 RK 2 6544 5479 44 M1\h3 RK 3 8615 6997 44 M1\h3 RK 4* 10023 7971 44 M1\h3 RK 5* 10147 8049 52 M1\h3 RK * BEHIND aJT m£A TH 9600' H TOP OF CEM8\lTCOLLAR, ID = 2.76" 11014' H 3-1/2" OTIS XN NIP, ID = 2.813" I 11032' H BOTrOM OF CEM8\lT COLLAR 1 11032' H 3-1/2" X 4-1/2" XO I 11036' 7' X4-1/2" BAKERSABL-3 PKR, ID =3.930" 11 043' 4-1/2" X 3-1/2" XO I 11070' H 3-1/2" PARKERSWS NIP, D =2.813" 11620' - 3-1/2" PARKER SWN NIP - MILLED W/2.81"07/29/GG, D =2.81" 11632' H 3-1/2" WLEG I 12437' H 4-1/2" TIW SS HORIZONTAL SOOOPHEAD 124 73' H 4-1/2" TIW OVERSHOT SEAL ASSY I 12486' H 4-1/2" R:>RTEDJOINT (42.28) I \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ 14-1/2"LNR-SLTD,12.6#,L-80,.0152bpf,ID=3.958" H 12976' ~I \ \ I TOP OF 4-1/2" LNR H 12976' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, D = 3.958" H 13000' PffiFORA TION SUMVlARY RB= LOG: GRlPDC 11/01/92 ANGLEATTOPÆRF: 59@ 11002' f\bte: Refer to Production DB for historcal perf data SIZE SFf' NTffiVAL Opn/Sqz DA lE 1-11/16" 4 11002-11005 S 10/28/97 2-1/2" 6 11470-11536 0 11/16199 2-1/2" 6 11580-11600 0 11/16199 2-1/2" 4 11596-11656 0 09/04199 2-1/2" 5 11736-11776 0 09/05193 2-1/2" 5 12376-12431 0 09/05193 SL 4 12654-12977 0 09/04192 SL 4 12670-12970 0 09/04199 DATE 09/06/92 09/05/93 12/18/00 02/14/01 01/09/02 REV BY OOMVI8\lTS ORIGINAL OOIVPLETION LA ST WORKOV ffi OOf\W ffiTBJ TO CA f\W AS RNAL OORRECTIONS SI&lsl SI&MD RN'TP OA.lE RBI BY COMM:NTS FRLOHOE SA Y Ut\IT WRL: 15-30 PERMIT No: 192-0780 API No: 50-029-22282-00 SEC 22 T11N R14E, 4264.77 FEL 20.07 FNL BP Exploration (Alas ka) PRUDHOE BA Y UNIT WELL: 15-30A ÆRMIT No: API No: 50-029-22282-01 SEC 22 T11 N R14E, 4264.77 FEL 20.07 FNL BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 09/06/92 ORIGINAL COMPLETION 04/03/02 MSE PROPOSED SIDETRACK 09/05/93 LAST WORKOVER 12/18/00 SIS-1s1 CONVERTED TO CANVAS 02/14/01 SIS-MD FINAL 01/09/02 RNffP CORRECTIONS 12653' 11 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276"1 11900' l-l 7" Inflatable Bridge Plug 12437' l-l 4-1/2" TIW SS HORIZONTAL SCOOPHEAD 12473' l-l 4-1/2" TIW OVERSHOT SEAL ASSY I -I 11620' 1- 3-1/2" PARKER SWN NIP- MILLED W/2.81" 07/29/99, ID = 2.81" -'-1 ~..1 / 13300' I 2<j/8" 4Jf.f. ST-I... Cernented & Perf'ed liner l-l I 9600' l-l TOP OF CEMENT COLLAR, ID = 2.76" 11014' l-l 3-1/2" OTIS XN NIP, ID = 2.813" I 11032' l-l BOTTOM OF CEMENT COLLAR 1 11036' l-l 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.930" 11070' l-l 3-1/2" PARKER SWS NIP, ID = 2.813" 11100' l-l Top of Cement 3 1/2" x 7" I /' 11350' l-l Top of 2..,3/8" Liner 1./ 34' l-l 4-1/2" X 3-1/2" XO I 2111' 1- 3-1/2" CAMCOTRDP-4A-SC SSSV NIP, ID = 2.812" GAS LIFT MA NDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 3405 3195 39 MMG RK 2 6544 5479 44 MMG RK 3 8615 6997 44 MMG RK 4* 10023 7971 44 MMG RK 5* 10147 8049 52 MMG RK * BEHIND CMT SHEATH SAFF1IOTES: LDL INDICATES 7" LNR LAP LEAK @ 1026~ JEMENTED4/3/98. CMT COLLAR2.76"ID FROM 9600' TO 11032', FCO TO 11126' (DUMPED SAND), 700@ 11532' AND 900@ 12202' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-l 13000' I--AIIIII .... o D fIi,:,','" t,i,i,l :i:i. m¡ :;:~, :;~ ... 1(j"iYÖ"Ó"6 l .. '...........................""'" I I I . I I I ~ /' 11550' 1 L- ~~. \1:'1::::1:11:,,',',"',,"',,',','"""", ""',,,', ", ", "', "",""",""'",,"\ ~¡:I:;¡:¡I¡ ~111!1¡",'"'"i,, ',,',:", "'" ',',':, '" '""'"',"" """ """"',,',,',,',,:,',',',,:, ,"""""""" 1 :> ¡,',",i,i,:",;', ',.'".:"",,',,',,',,',',",',.""'., 1 1 I ~ 8 14-1/2" LNR-SL TO, 12.6#, L-80, .0152 bpf, ID = 3.958" l-l 12976' ÆRFORA TION SUMMARY REF LOG: GRlPDC 11/01/92 ANGLE AT TOP ÆRF: 59 @ 11002' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-11/16" 4 11002-11005 S 10/28/97 2-1/2" 6 11470-11536 0 11/16/99 2-1/2" 6 11580-11600 0 11/16/99 2-1/2" 4 11596-11656 0 09/04/99 2-1/2" 5 11736-11776 0 09/05/93 2-1/2" 5 12376-12431 0 09/05/93 SL 4 12654-12977 0 09/04/92 SL 4 12670-12970 0 09/04/99 13-1/2" TBG, 9.3#, 13-CR-80, 0.0087 bpf, ID = 2.99" l-l 11632' I Low side 2 string w ìndow from W/S l-l l-l 11100' 1 1 Punch Tubing I 3-1/2" TBG, 9.3#, 13-CR-80, 0.0087 bpf, ID = 2.99" l-l 11032' I Minimum ID = I TOP OF 7" LNR l-l 10263' 9-5/8" CSG, 47#, L-80, ID = 8.681" l-l 10568' ~ 13-3/8" CSG, 68#, L-80, ID = 12.415" l-l 3838' ~ (8 ) Proposed CTD Sidetrack 15-30A 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-l 34' ) TREE= ' \ FMC WELLHEAD = McEVOY 'Ä;cf.uÂ'rõFr;;'''õfÎs'¿ô'ÜR''2'2C)'2 .'.,'"','.'.',,',',,,'.·..,'.',.',',w,'....',·.',','....','.'.... ..'.'...,,'.,'.'.....'..'.'" KB. ELEV = 64' BF:"'ECE'7";'M""~''''''~''''''''''~''''''''''''''''''''''.''''''''''''''','M""",,",,,,,, .','.'.',"'..',.,.'",'."'.'.',',"',',',"',.",. ..'."..,.,"..... .','.'.'.,·.··,.'.'.··.'.'.'.·,'.'·,'.'.'.'.'.'.w",'. KOP = 1286' "Max'Ã'ngíe;"'''''''''''''''''''9S'@123'SEF '5ãtumr\~'5',;;;"",,,,,,,,,-,,,,,,,,,,,,,,,,w",,w"""1'2T16; Datum'iVï5;'·'·'''··..àaÓòisS BP Amoco Wl!LLPATH DnAlLS PI.. ,J 15-30A 1002.2221201 ft.,."t W-Upathr 15-30 Tie 011 MDr 11532.03 lUg. Nordic 1 R.... Datunu "I JO 11411"2 00:00 eUOft v.s.::~~ O.':1'~ ~~ ::::-;t,o 47.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 15-30, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot· 30 (O.OON,O.ooE) Measured Depth Reference: 44: 30 8/4/1992 00:00 64.00 Calculation Method: Minimum Curvature aECßON DETAILS he liD Inc Ad TVD +"1-& +EJ.W DLet TFac. YSee Tatge! 'I 11532.03 7&.43 n.82 ...75 5502.02 H01.5J 0.00 0.00 8807.23 2 11550.00 78.14 32..15 '7O.t.1I 55fe.85 31112." .&.52 355.20 Hu.n 3 11551.00 '..18 31.1-0 870&.68 5521.M H1e.oa ..eo.oo 210.00 &828.74 i Hæ~ f!:~ H:: :~~!~ iæ:: FJi:~ 1::: ~= :æ~ 7 11124.32: eo.31 &.80 BUt..3 ð71J.72 4004.08 12..00 271.00 e.ase.o7 !o H=~~ E:: *::i :n~:: =:i! :::ll ~i5 27:i:5 ~::~~ 11 1n18.32 80.11 58.113 8701.H 6540.47 478187 12..00 272.00 7ese.f! 12 13300.00 n..51 M.78 MH.a.. esa.20 sot5.5' 12.00 17.00 8227.30 ANNOTATIONS T~O€TAlLS TVD MD "'''0t.1:I0II Nvr.. TW +Nf-5 "EJ.w Shape .....7.11132.03 TI, :~~I e1~~ ~~ ;.~~ ~ :~::-l: ~~:::::: ~O~ :~g :~~ ~~~ ~~: =: 070..17 111M.00 2 .713.12 11"..00 J .711.03 1117'.31 .. 0721.1J IttH.J2 1 07tt.TI U22..J2 I .711.1. UU..J2 7 0710.1. UI2..U . 1700.11 1207..U I .....11 IUOO.OO TO Plan: Plan #3 (15-30/Plan#3 15-30A) Created By: Brij Potnis Date: 3/26/2002 Contact Information: Direct: (907) 267-6613 E-mail: brij.potnis@inteQ_com Baker Hughes INTEQ: (907) 267-6600 Azimuths to True North Magnetic North: 26.45° Stre~;~~;~~Ò~~~ Dip Angle: 80.81° Date: 3/26/2002 Model: BGGM2oo1 T ^M ¿ LEGEND 15-30 (15-30) PIan#3 15-30A Plan #3 I' .J i ...1:-.... ........... ;t( re.. BAKER~~. - -- IlUCllEI ObP _6500 C æ 6400 o ~ 6300 - ;"6200 - ~ 1: 6100 o ~ 6000 - . :!" 5900 .. ~ o 5800 en 5700 i ¡ 5600 5500 5400 5300 ~ Juti :c~,!ni~: un i , I i - ,-, -- --'--.--r' --' I - I =-=t= _ : ! '_-.---L [, ,'" . ,- - I i ---In- I , ! ! I I I--·-t-~ I I ---'---'-- :- t T·~ f-~-¡f.---:n.m_!.-+---t ~ 8700-.- --' , I ' , . ! I' I ,m_ , '. ! r. _: I L ' . I ··1 f i I r ~"i I ui ::::: l cc~j , .... ¡ ,mLj--il=+- f~~~:±~:"L 8850 _, ' ' ' , , ,- ' I I , , ¡¡~",i~ "!,, ,t, t,~,j,,_T~cr j , tion at 47.00' [50ft/In] 8000 8050 8100 8150 8,00 825~ '8ino 83~~ ~o -. !15.3'=-~::" -:- ;. :- -- '\ -- r _-----1 L~TEQ 7000 6900 6800 6700 6600 -~- ~ 11 : 16 AM 3/26/2002 - .5 8300 ~ ~ 8350 t It) __ - - ~ 8400 - .. - a. _ CÞ 8450- - a = "i 8500 :::. CJ - 1: 8550 ~~ CÞ - > 8600 -~ CÞ - 2 8650 = ... 8100 ) ') . í:Ntlib !þp BP Baker Hughes INTEQ Planning Report ÜnI1P~ny: Field: Site: Well: Well path: Field: BPAmoco .Prudhqe Bé1Y PBPS1? 15~30 . Plan#3 15-30A I)~~~:,i'~{2Ø/20Ó2'i·\ ....... .·..Ti.ne:.· ·.··.11:17:39P~ge:· 1 Co~r4~~~t~(l'lE)'J:{efer·en~lþ~ ·\J\Iéll: ..,·15~ªÖ,.T rlJ~N~rth ..' .........'.. ......... Yert~c.I('I'Y(»l{e~er~~~e~· $y~terh:Meo:ie §e¡a~~vel· ....... Section (VS)R.eference: . Well (O.00N,O.00E,47.00Aii) Survey Calculation Method: Minimum Curvature Db: Oracle Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.236 N 148 34 21.213 W True 1.34 deg Well: 15-30 Slot Name: 30 15-30 Well Position: +N/-S 949.09 ft Northing: 5959811.01 ft Latitude: 70 17 44.570 N +E/-W 1060.96 ft Easting : 677335.32 ft Longitude: 148 33 50.290 W Position Uncertainty: 0.00 ft Wellpath: Plan#3 15-30A 500292228201 Current Datum: 44 : 30 8/4/1992 00:00 Magnetic Data: 3/26/2002 Field Strength: 57509 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description Dip~ Dir. 15-30A Polygon2.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 TVD .ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8700.00 15-30A T2.3 15-30A T2.2 8712.00 15-30A T2.1 8720.00 Annotation MD TVD ft ft 11532.03 8699.75 TIP 11550.00 8704.15 KOP 11556.00 8705.68 1 11566.00 8708.57 2 11586.00 8713.52 3 11676.32 8722.03 4 11826.32 8721.63 5 12226.32 8719.71 6 12426.32 8716.85 7 12826.32 8710.89 8 Height 64.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 15-30 11532.03 ft Mean Sea Level 26.45 deg 80.81 deg Direction deg 47.00 +N/-S ft 0.00 ~~p..,..... . .1'1~p . . "S__;--··Latit~d~,.-.,~>: ~,r-". .Løngitud:~.';'-~~ fE/·W· Northi~g ,'Eastirlg DegMiil Sec. l)egMinSeç ft: ' ft ft 6021.85 4058.78 5965926.56 681250.64 70 18 43.784 N 148 31 51.894 W 6021.85 4058.78 5965926.56 681250.64 70 18 43.784 N 148 31 51.894 W 6374.10 4309.13 5966284.59 681492.59 70 18 47.247 N 148 31 44.585 W 6679.88 4877.39 5966603.67 682053.44 70 18 50.250 N 148 31 28.002 W 6741.93 5174.65 5966672.72 682349.13 70 18 50.859 N 148 31 19.329 W 6536.44 5235.15 5966468.72 682414.46 70 18 48.837 N 148 31 17.569 W 6594.17 4906.09 5966518.67 682084.15 70 18 49.407 N 148 3127.167W 6408.25 4644.24 5966326.64 681826.78 70 18 47.580 N 148 31 34.809 W 6166.77 4277.35 5966076.58 681465.71 70 18 45.208 N 148 31 45.516 W 5996.34 4208.03 5965904.58 681400.44 70 18 43.532 N 148 31 47.541 W 6595.40 5122.04 5966525.00 682300.00 70 18 49.418 N 148 31 20.867 W 6458.41 4568.62 5966375.00 681750.00 70 18 48.074 N 148 31 37.014 W 6092.34 4184.85 5966000.00 681375.00 70 18 44.476 N 148 31 48.215 W ) BP ) .. Ob .,", p Baker Hughes INTEQ Planning Report I _,~_R.'. ,_._.......,..R_.___._.__.. INIRQ I Company: BPAmocö I)ate:3/2ßI2ap2 ··Thne:11: 17:39/ .... . Page: ·'2 Field: Prudhqe B~y Co-ordtnate(NE lQ:eference:. W~II:t5-30, True Nörth Site: PBDS15 Verticàl(TVQ)Reference: $ys~~m: Me~n S~aLevel Well: 15-3.0 Section,·(VS). Refer~..ce: Well (Q"OaN, ø.QaE,47 .aaAzi) WeUpath: Plan#3 15-3aA Survey Cjilculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 12976.32 87.09.56 9 1330.0..0.0 8699.81 TO Plan: Plan #3 Date Composed: 3/26/2.0.02 Identical to Lamar's Plan #3 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +Nl-S +E/-W PLS.. < .~nilØ< ..··..Turn . · tl<~O ft deg deg ft ft ft deg/1 pan deg(10aft;deg/100ft cleg 11532..03 75.43 32.92 8699.75 55.02..02 39.03.53 .0..0.0 .0..0.0 .0..0.0 .0..0.0 1155.0..0.0 76.24 32.85 87.04.15 5516.65 3912.99 4.52 4.51 -.0.39 355.2.0 11556..0.0 74.16 31.6.0 87.05.68 5521.56 3916..08 4.0..0.0 -34.59 -2.0.78 21.0..0.0 11566..0.0 72.2.0 27.97 87.08.57 5529.86 392.0.84 4.0..0.0 -19.69 -36.38 24.0..0.0 11586..0.0 79.16 23.9.0 8713.52 5547.28 3929.3.0 4.0..0.0 34.83 -2.0.31 33.0..0.0 11676.32 9.0..0.0 23.9.0 8722..03 5629.36 3965.67 12..0.0 12..0.0 .0..0.0 .0..0.0 11826.32 9.0.31 5.9.0 8721.63 5773.72 4.0.04..09 12..0.0 .0.21 -12..0.0 271..0.0 12226.32 9.0.21 53.91 8719.71 611.0.4.0 4197.74 12..0.0 -.0..03 12..0.0 9.0..0.0 12426.32 91.41 29.93 8716.85 6258.11 433.0.37 12..0.0 .0.6.0 -11.99 273..0.0 12826.32 9.0.2.0 77.92 871.0.89 6486.76 4644.28 12..0.0 -.0.3.0 12..0.0 91..0.0 12976.32 9.0.81 59.93 87.09.56 654.0.47 4783.67 12..0.0 .0.41 -11.99 272..0.0 1330.0..0.0 92.51 98.76 8699.81 6599.2.0 5.095.56 12..0.0 .0.53 11.99 87..0.0 Survey MD Incl Azim SSTVD N/S E/W MapN MapE VS PLS ,TF9 Tool ft deg deg ft ft ft ft ft' . ft deg/1aOft dag 11532..03 75.43 32.92 8699.75 55.02..02 39.03.53 59654.03.24 6811.07.7.0 66.07.23 .0..0.0 .0..0.0 TIP 11533..03 75.48 32.92 87.0.0..0.0 55.02.83 39.04..06 59654.04..07 6811.08.21 66.08.17 4.52 355.2.0 15-3aA T 1155.0..0.0 76.24 32.85 87.04.15 5516.65 3912.99 5965418..09 681116.81 6624.13 4.52 /·355.2.0 KOP 11556..0.0 74.16 31.6.0 87.05.68 5521.56 3916..08 5965423..07 681119.79 6629.74 4.0..0.0 v' 21.0..0.0 1 11566..0.0 72.2.0 27.97 87.08.57 5529.86 392.0.84 5965431.48 681124.35 6638.88 4.0.00 240.00 2 11575.00 75.32 26.11 8711.09 5537.56 3924.76 5965439.27 681128.09 6647.00 40.00 33.0..0.0 MWD 11578.76 76.63 25.34 8712.00 5540.84 3926.35 5965442.59 681129.59 6650.40 40.00 330.52 15-3aA T 11586.0.0 79.16 23.90 8713.52 5547.28 3929.30 5965449.1.0 681132.39 6656.94 40.0.0 330.70 3 1160.0.0.0 80.84 23.90 8715.95 5559.88 3934.88 5965461.83 681137.68 6669.62 12.00 0.00 MWD 11625.00 83.84 23.90 8719.28 5582.53 3944.92 5965484.71 681147.18 6692.41 12.00 .0..0.0 MWD 1165.0.00 86.84 23.90 8721.31 5605.31 3955.02 5965507.71 681156.73 6715.33 12..00 .0.00 MWD 11675.00 89.84 23.90 8722.03 5628.15 3965.14 5965530.79 681166.31 6738.31 12.00 0.00 MWD 11676.32 90.00 23.90 8722..03 5629.36 3965.67 5965532.00 681166.82 6739.52 12.00 360.00 4 1170.0.00 90.05 21.06 8722.02 5651.24 3974.73 5965554.09 681175.35 6761.07 12..0.0 271..0.0 MWD 11725.00 90.10 18.06 8721.99 5674.79 3983.1.0 5965577.84 681183.16 6783.25 12..0.0 271.0.0 MWD 1175.0.0.0 90.15 15..06 8721.94 5698.75 3990.22 5965601.96 681189.72 68.04.81 12.00 270.99 MWD 11775.00 90.21 12.06 8721.86 5723.05 3996..08 5965626.39 681195.01 6825.67 12.0.0 270.99 MWD 1180.0.0.0 90.26 9.06 8721.76 5747.63 400.0.67 5965651.06 681199.01 6845.78 12..00 27.0.98 MWD 11825.0.0 90.31 6.06 8721.63 5772.41 4.0.03.96 5965675.91 681201.71 6865.08 12.00 270.97 MWD 11826.32 90.31 5.90 8721.63 5773.72 4.0.04.09 5965677.22 681201.82 6866.07 12.00 270.95 5 11850.00 9.0.31 8.75 8721.50 5797.20 4007.11 5965700.77 681204.28 6884.30 12.00 90.0.0 MWD 11875..0.0 9.0.31 11.75 8721.36 5821.80 4011.56 5965725.47 681208.15 69.04.33 12.00 90..02 MWD 119.0.0.00 90.31 14.75 8721.23 5846.13 4017.29 5965749.92 681213.30 6925.11 12.0.0 90.03 MWD 11925.00 90.30 17.75 8721.1.0 5870.13 4024.28 5965774.08 681219.73 6946.59 12..00 9.0..05 MWD 11950.00 9.0.3.0 20.75 8720.97 5893.73 4.032.52 5965797.86 681227.41 6968.72 12.00 90.06 MWD 11975.0.0 90.29 23.75 872.0.84 5916.87 4041.99 5965821.22 681236.32 6991.42 12.00 9.0..08 MWD 12.000.00 90.29 26.75 872.0.71 5939.48 4052.65 5965844.07 681246.45 7014.63 12.0.0 90..09 MWD 12.025.00 90.28 29.75 8720.59 5961.50 4064.48 5965866.36 681257.75 7038.30 12.00 90.11 MWD 12.050.00 9.0.28 32.75 8720.46 5982.87 4077.44 5965888..03 681270.21 7.062.36 12.00 90.12 MWD 12.075.00 90.27 35.75 872.0.35 6003.53 4091.51 5965909.02 681283.78 7086.74 12..00 90.14 MWD ) BP ') .,z~ bp Baker Hughes INTEQ Planning Report .-'--"-- -,--~--_._-_. ---, IN·fRQ Company: BP Amoco D;¡te: ~/26/2q02 ...... ..' ..... .. . ... ..... Time:.. '11:17:39>' ......................... '. .'. ..' '.. , Page: Field: Prµdhoe' BØY Co~r:dinate(NE)Referellce: VV~U:197~O; True North.... Site: PBDS15 Yertical(I'VD) Refere~ce: ·System:Mean.S·~a~f)vet Well: 15-30 S~ti~n(VS)R~f~rence: '. '.' '. WeU{0.00N,Q.qOEA'7.00Azi) WeUpath: Plån#315-30A SurveyCalculati~n Method: Minimum Curv",tµre . Db: Survey MD Incl Adm SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deQ dég ft ft ft ft ft ft (jeg/tOOft deg 12100.00 90.26 38.75 8720.23 6023.43 4106.64 5965929.27 681298.44 7111.38 12.00 90.15 MWD 12125.00 90.25 41.75 8720.12 6042.51 4122.79 5965948.72 681314.13 7136.20 12.00 90.17 MWD 12150.00 90.24 44.75 8720.01 6060.72 4139.92 5965967.33 681330.83 7161.14 12.00 90.18 MWD 12175.00 90.23 47.75 8719.91 6078.00 4157.97 5965985.03 681348.47 7186.14 12.00 90.19 MWD 12200.00 90.22 50.75 8719.81 6094.32 4176.91 5966001.79 681367.01 7211.12 12.00 90.21 MWD 12225.00 90.21 53.75 8719.72 6109.62 4196.67 5966017.56 681386.41 7236.01 12.00 90.22 MWD 12226.32 90.21 53.91 8719.71 6110.40 4197.74 5966018.36 681387.45 7237.31 12.00 90.23 6 12250.00 90.36 51.07 8719.60 6124.82 4216.52 5966033.22 681405.89 7260.89 12.00 273.00 MWD 12275.00 90.51 48.07 8719.41 6141.03 4235.55 5966049.87 681424.53 7285.86 12.00 272.99 MWD 12300.00 90.67 45.07 8719.15 6158.22 4253.70 5966067.48 681442.27 7310.85 12.00 272.96 MWD 12325.00 90.82 42.08 8718.83 6176.32 4270.93 5966085.98 681459.07 7335.80 12.00 272.93 MWD 12350.00 90.97 39.08 8718.44 6195.31 4287.19 5966105.34 681474.87 7360.64 12.00 272.89 MWD 12375.00 91.12 36.08 8717.98 6215.11 4302.43 5966125.50 681489.64 7385.30 12.00 272.85 MWD 12400.00 91.26 33.09 8717.46 6235.69 4316.62 5966146.41 681503.34 7409.70 12.00 272.79 MWD 12425.00 91.40 30.09 8716.88 6256.98 4329.71 5966168.00 681515.92 7433.80 12.00 272.73 MWD 12426.32 91.41 29.93 8716.85 6258.11 4330.37 5966169.15 681516.55 7435.05 12.00 272.66 7 12450.00 91.36 32.77 8716.28 6278.33 4342.69 5966189.65 681528.39 7457.85 12.00 91.00 MWD 12475.00 91.30 35.78 8715.70 6298.98 4356.76 5966210.63 681541.97 7482.23 12.00 91.07 MWD 12500.00 91.24 38.78 8715.15 6318.87 4371.90 5966230.86 681556.63 7506.86 12.00 91.14 MWD 12525.00 91.17 41.78 8714.62 6337.94 4388.05 5966250.31 681572.33 7531.68 12.00 91.20 MWD 12550.00 91.11 44.78 8714.12 6356.13 4405.18 5966268.90 681589.03 7556.62 12.00 91.27 MWD 12575.00 91.03 47.77 8713.66 6373.41 4423.25 5966286.59 681606.68 7581.61 12.00 91.33 MWD 12600.00 90.96 50.77 8713.22 6389.71 4442.19 5966303.34 681625.23 7606.58 12.00 91.38 MWD 12625.00 90.88 53.77 8712.82 6405.01 4461.96 5966319.10 681644.63 7631.47 12.00 91.44 MWD 12650.00 90.81 56.77 8712.45 6419.25 4482.50 5966333.81 681664.83 7656.21 12.00 91.48 MWD 12675.00 90.72 59.77 8712.12 6432.39 4503.76 5966347.46 681685.77 7680.72 12.00 91.53 MWD 12700.00 90.64 62.77 8711.82 6444.40 4525.68 5966359.98 681707.40 7704.94 12.00 91.57 MWD 12725.00 90.56 65.77 8711.56 6455.25 4548.19 5966371.36 681729.65 7728.81 12.00 91.60 MWD 12750.00 90.47 68.77 8711.33 6464.91 4571.25 5966381.56 681752.47 7752.26 12.00 91.64 MWD 12775.00 90.38 71.77 8711.15 6473.35 4594.78 5966390.55 681775.79 7775.22 12.00 91.66 MWD 12800.00 90.29 74.77 8711.00 6480.55 4618.72 5966398.31 681799.55 7797.64 12.00 91.68 MWD 12825.00 90.20 77.77 8710.89 6486.48 4643.00 5966404.82 681823.69 7819.45 12.00 91.70 MWD 12826.32 90.20 77.92 8710.89 6486.76 4644.28 5966405.12 681824.97 7820.57 12.00 91.72 8 12850.00 90.30 75.08 8710.78 6492.29 4667.31 5966411.19 681847.86 7841.19 12.00 272.00 MWD 12875.00 90.40 72.08 8710.63 6499.35 4691.29 5966418.82 681871.66 7863.54 12.00 271.99 MWD 12900.00 90.50 69.09 8710.43 6507.66 4714.86 5966427.68 681895.03 7886.45 12.00 271.97 MWD 12925.00 90.61 66.09 8710.19 6517.19 4737.97 5966437.75 681917.91 7909.85 12.00 271.95 MWD 12950.00 90.71 63.09 8709.90 6527.92 4760.55 5966449.01 681940.22 7933.68 12.00 271.92 MWD 12975.00 90.80 60.09 8709.57 6539.81 4782.53 5966461.42 681961.92 7957.86 12.00 271.88 MWD 12976.32 90.81 59.93 8709.56 6540.47 4783.67 5966462.10 681963.04 7959.15 12.00 271.84 9 13000.00 90.96 62.77 8709.19 6551.82 4804.45 5966473.94 681983.55 7982.09 12.00 87.00 MWD 13025.00 91.11 65.77 8708.74 6562.67 4826.97 5966485.32 682005.80 8005.95 12.00 87.04 MWD 13050.00 91.26 68.76 8708.22 6572.33 4850.02 5966495.52 682028.61 8029.40 12.00 87.10 MWD 13075.00 91.41 71.76 8707.64 6580.77 4873.54 5966504.51 682051.93 8052.36 12.00 87.16 MWD 13100.00 91.55 74.76 8707.00 6587.96 4897.47 5966512.27 682075.68 8074.77 12.00 87.23 MWD 13125.00 91.69 77.76 8706.29 6593.90 4921.74 5966518.77 682099.80 8096.56 12.00 87.31 MWD 13150.00 91.82 80.76 8705.53 6598.56 4946.29 5966524.01 682124.23 8117.69 12.00 87.39 MWD 13175.00 91.95 83.75 8704.70 6601.92 4971.05 5966527.96 682148.90 8138.10 12.00 87.48 MWD 13200.00 92.08 86.75 8703.82 6603.99 4995.94 5966530.61 682173.74 8157.71 12.00 87.58 MWD 13225.00 92.19 89.75 8702.89 6604.75 5020.91 5966531.96 682198.68 8176.49 12.00 87.69 MWD 13250.00 92.31 92.75 8701.91 6604.21 5045.88 5966532.00 682223.66 8194.38 12.00 87.80 MWD 13275.00 92.41 95.75 8700.88 6602.35 5070.79 5966530.74 682248.60 8211.34 12.00 87.92 MWD 13300.00 92.51 98.76 8699.81 6599.20 5095.56 5966528.17 682273.44 8227.30 12.00 88.04 TD All Measurements are from top of Riser top of bag bttm of bag middle of slips middle of pipes ~- middle of flow cross ---- middle of blind/shears middle of pipe/slips ) "- CD en -- a: 1"1 .'-i " I ! Schlum. - 'i - ' ,. I ~ Blind/Shears 2" combi ram/slips Mud Cross 2 3/8" ram 2" combi ram/slips Flow Tee ~rrr·:r ............,.,......... ..................... r- \..-.- ,......,..,............ -.................... ) 4/3/2002 BAG TOTs / Mud Cross TOTs / - ._--~-_._- ...-..- ..."-,-.'~.__._..... wd: Slight change in 15-30 prep J ) Subject: [Fwd: Slight change in 15-30 prep] Date: Tue, 30 Apr 2002 10:30:38 -0800 From: Tom Maunder <tom _ maunder@admin.state.ak.us> To: Winton GAubert <winton_aubert@admin.state.ak.us> Winton, I don't know if you have an unzipper, so I already forwarded the wellbore drawing. Big file. Would you please look at this and compare with what you did for the original sundry approval. I suspect.that what Mary proposes is just another way of doing the same thing. If all looks good, send a note back to her giving approval and place a copy of your message and the new drawing in the well file. Thanks. Tom V. IMV "n-' ~.n Subject: Slight change in 15-30 prep Date: Tue, 30 Apr 2002 12:30:14 -0500 From: "Endacott, Mary S" <EndacoMS@BP.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Tom Since submitting the sundry application, I have put more detailed thought into the prep of 15-30. New plan is to set CIBP or IBP in the top of the 4 1/2" liner (can't ever get those little IBPs to set in 7" reliably). Then lay in 60bbl 15.8ppg cement to the tubing punches (still at 11,100), drill out and set whipstock (with Nordic at 11,550'). See attached schematic. «15-30wbs.ZIP» Mary S. Endacott Coil Tubing Drlg Engr 907-564-4388 737c endacoms@bp.com \.... "..... ..".........,...,"."..... ......·....·b".... ... ..--..............................-..............-.....--.-.............._~.....-..-............_-_.................. .. .......,. ..................."....'..,.,,,..,, .".... .,..".... .. .......,.. ...." ..,,,..... .. ........ ..p... '''''''',,,. ··'Nâine:i5~3Ówbs.Zí'P ." ~ 15-30wbs.ZIP : T~pe: Zip Compressed Data (application/x-zip-compressed) 'Encoding: base64 ~Wlil.~-^~'.~·^..,W..._-.U"ll.1llll..UIIN....:IP',....i \"'I.'.W.II....\"· I.'" ^.'.v.".V,o\~"" ~H\ . "V,\~"'.' ':1''''''\\1_\1_\\11',''',1/,1·'' '.\ I\~\' ~L\II'.II\ itv'··\I·' .WI,W·\I.\\:WN'I/· '11I'11 ~1~/AII'" "'" 'I I'A ·i'I··.lllhl.I\\1l 111:~llW.\. v Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission :.u.:.:.:.:.................... '" ~ ~. '¡'..,. , ' ..... 1 of 1 4/30/2002 10:44 AM TREE = FMC WB-LHEAD = McEVOY ACTUA TOR = OTIS 70 UH 2202 ~~................-~............._.........-....",.............._-_.......,._........----..---.....---- KB. B...EV = 64' BF. ELEV = ...-........-.....................-....----....---.-.......----.....--.....-......-....-..- KOP= 1286' -~~-~..~-~-~.~:._:_._------_...~_?_.~_.~.~-~~_?~. DatumMD= 12116' . Datu m TV D = 8800' SS I 4-1/2" TBG, 12,6#, L- 80, 0,0152 bpf, ID = 3.958" H ) 15-30A 34' Proposed CTO Sidetrack / .J 13-3/8" CSG, 68#, L-80,ID = 12.415" H 3838' ~ ~ ~ ~ ::ri;~ I) :¡.....,................. "t.1 ·~ù~: ! I &---1 I I TOPOF 7" LNR l-i 10263' I -I 9-5/8" CSG, 47#, L- 80, ID = 8.681" l-i 10568' r-----..4I ~ < ,;: < ':, < < :r~ 'il:: ( ij;:~ & Minimum 10 = \3-1/2" TBG, 9.3#, 13-CR-80, FOX, 0,0087 bpf, ID = 2,99" 11 11032' I I Punc~1 Tubing l-i 11100' I I Lovvside2stringwindow fromvVlsl-f 11531' 13-1/2" TBG, 9,3#, 13-CR-80, FOX, 0.0087 bpf, ID = 2,99" 11 11632' ÆRFORATIONSUMMARY RB= LOG: GRlPOC 11/01192 ANGLE AT TOP PERF: 59 @ 11002' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 1-11/16" 4 11002-11005 S 10/28/97 2-1/2" 6 11470-11536 0 11/16/99 2-1/2" 6 11580-11600 0 11/16/99 2-1/2" 4 11596-11656 0 09104/99 2-1/2" 5 11736-11776 0 09105/93 2-1/2" 5 12376-12431 0 09/05/93 SL 4 12654-12977 0 09/04/92 SL 4 12670-12970 0 09104/99 I I I I I ~ 14-1/2" LNR-SLTD, 12.6#, L-80, .0152 bpf, ID= 3.958" H 12976' 14-1/2" LNR. 12.6#, L-80. 0.0152 bpf.ID = 3.958" H 1~OOO' µ .. DATE REV BY COM'v1E3'JTS DATE REV BY COM\1E3'JTS 09/06/92 ORIGINAL COtvA...EfION 04/03102 MSE ffiOPOSED SIŒTRACK 09/05/93 LAST WORKOVER 12/18/00 SlS-lsl CONVERTEOTO CANV AS 02/14/01 SIS- NÐ RNAL 01/09/02 RNlTP CORRECTIONS . ...- -..... .-.......- -.... -.........---...- ....--... .. ..................... . SAFETY h 1s: LDL I to.Dl CA TES 7" LNR LAP LEAK @ 10263'. CSVlENTED4J3I98. CMT COLLAR 2.76" ID FROM 9600' TO 11032'. FCO TO 11126' (DUMPED SAND). 70° @11632' AND 90° @ 12202' 34' 1-1 4-1/2" X 3-1/2" XO I 2111' 1- 3-1/2" CAMeO TRDP-4A-SC SSSV NIP, ID = 2.812" GA S LIFT MANDRB...S ST MD TVD DEV TYFE VLV LATCH PORT pATE 1 3405 3195 39 tvtv1G RK 2 6544 5479 44 tvtv1G RK 3 8615 6997 44 tvtv1G RK 4" 10023 7971 44 tvfv1G RK 5" 10147 8049 52 tvtv1G RK " BEHIND CMT SHEATH 9600' 1-1 TOP OF CBv1ENT COLLAR,ID = 2.76" 11014' 1-1 3-1/2" OTIS XN NIP, ID = 2.813" I 11032' l-i BOlTOM OF C8v1ENT COLLA R I 11036' 1-1 7" X 4-1/2" BAKER SABL-3 PKR. ID = 3,930" 11070' l-i 3-1/2" PARKER SWS I\IP,ID = 2,813" 11100' H Top of Cement 3 1/2" x 7" I 11350' 1-1 Top of 2-3/8" liner I 2-3/8" 4.7# ST-L Cemented & Perf'ed liner -i 13300' I 3-1/2" PARKER SWNNIP- MILLED W/2,81" 07/29/99,ID = 2.81" 12437' 1-1 12448" 12473' 4-1/2" TIW SS HORIZONTAL SCOOA-fEAD 3 1/2" aBP '" I 4-1/2" TIW OVERSHOT SEAL ASSY 1 12653' 11 7" LI\R, 26#, NT80S. NSO:, ,0383 bpf. ID = 6.276" ffiUctiOE BA Y UNIT WB..L: 15-30A PERMT No: AR No: 50-029-22282-01 SEC 22 T11N R14E 4264.77 F8... 20.07 FNL BP exploratIon (Alaska) <.:';'ff!t1,!.! i'!t.~~r...·:..~..- .:_";.-; -.: ::,:. H 206295 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100. 00 031202 CK031202E PYMT COMMENTS: HANDL:NG IN5T: Pernit to Drill ree 5tH - Terrie Hubhle X4628 \5,30A- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100 on BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519·6612 DATE 03li4J02 CHECK NO. 0020629::;· VENDOR DISCOUNT Ai ASKÄnTi A NET 100. 00 RECEIVED APR ~-' ¡-II~) ~œlGas Con:;, Commission Anchoraqe inn 00 No. H 208285 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVElAND, OHIO CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ---¡:j"2 > 00206295 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 03/14/02 To The oRqfR -:Of'- ,"ALASKA OIL AND GAS "ÇPN?¡:RVf;\TIQN<?OMMISSION 333WËSJ1"': 7tfiAVENUE SUITE 100 ANCHORAGE AK 99501 III 20 b 2'ì Sill 1:0 ~ ¡. 20 38 'ì 51: 008 ~ It .. qlll AMOUNT $100_00 NOT VALID AFTER 120 DAYS n...U . .... .....>--'=. i \( ~{!;¡V(l.. 1 . ---".. - ~ no H --" -.-' ) ) TRANSMlT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT REDv EXPLORA TJON INJECTION WELL INJECTION WELL REDRILL WELLNAME~gt¡ /ç..¿ t1Ófi CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) Pll.OT HOLE (PH) ANNUL'» ..4AL , ~~ÑÖu, ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, ,API No. ' Production should continue to be reported as a function of the original API number stated above. ' In accordaDce with 2,0 MC 2S.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (na,me on permit). Annular disposal has ~ot been requested... Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS L-J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and' produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY AI J¿ WELL NAME f78ú I') - ç ('J A FIELD & POOL (;t:¡OJSn INITCLASS /Jbj/ /-0// ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . .. ..... 2. Lease number appropriate. . . . . . . . . . . .. ..... 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in 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. . . . . . . . ~R ~ ,~~ T~ 12. Permit can be issued without administrative approval.. . . . . /J/'¿ f//;/~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T. B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . .. 21. If are-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; test to ~;ç"" 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 wlo hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones . . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . A~R ~~~'7: 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . /f'J't: j'2rðz 34. Contact namelphone for weekly progress reports {exploratory ANNULAR DISPOSAL 35. 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; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERING: UIC/Annular: COM RP& TEM f/f.'J1/f SFD_ WGA \flú/~ APPR DATE Wf:.'¡\- 4l],sI0'z.. /Æ.?tv1. ~ ("$~-~ GEOLOGY APPR #t DATE i#~ PROGRAM: Exp _ Dev:d Redrll ~ Serv _ Wellbore seg _ Ann. disposal para req _ GEOL AREA ~7 n UNIT# // ¡Ç, ( C1 ON/OFF SHORE nAl fY)N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~~ EN/A--- -¥-N- A j @ ~ A'tDe "b lJ ....-fA, -e~Pc..~' . ~N t-TDU ~ N ~ /1111(1 2.. I ~,..J/Æ Æ~ & N }/L<; I) = Z2q.c¡ ft/. ~~ @ N j;£.¿ b..e I () UJ Y N Y N þ,;:J'v N N ( ( MfI . \J-r~~\fc ~ ~ ~ ç N Comments/l nstructions: COT .) DTS C>S 10 è.. 0 "2- JMH G: \geology\templates \checklist. doc ') ,) Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To inlprove the readability of the Well History file and to simplify finding infomlation. 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. ) ') ¿J08 -00;1 . . . **** REEL HEADER **** MWD 03/12/24 BHI 01 #- J~3W(J RECEIVED JAN 0 9 2004 AlIlkaOil&GaI_Commiulon AnMâ8e LIS Customer Format Tape **** TAPE HEADER **** MWD 03/12/24 422493 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: Idwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11508.0000: STOP.FT 13308.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 22 TOWN.N IlN RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 64.0 DMF KB EKB .F 64.0 EDF .F N/A EGL .F 0.0 CASE.F 11556 OSl . DIRECTIONAL OS2 . PRESSTEQ I -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is Realtime data. (4) Well 15-30A was kicked off from wellbore 15-30APBl at 11556' MD (8707' SSTVD) . (5) Baker Hughes Inteq utilized CoilTrak downhole tools and ADVANTAGE surface system. (6) Tools ran in the string included CCL, Electrical Disconnect and 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 15-30A Prudhoe Bay Unit 70 deg 17' 44.570" N 148 deg 33' 50.290" W North Slope Alaska Baker Hughes INTEQ 2.375" CTK 31-Jan-03 500292228201 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Other Services Line 2 ~~,{\'\.~ Circulating sub, )Drilling Performance Sub (inner é. ')outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and an Orienting Sub with a near bit inclination sensor. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on January 31, 2003. (8) The interval from 13280' MD (8710' SSTVD) to 13308' MD (8711' SSTVD) was not logged due to sensor bit offset at TD. MNEMONICS: GRCX -> Gamma Ray MWD-AAPI [MWD] (MWD-AAPI units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth (SSTVD), feet SENSOR OFFSETS: RUN GAMMA 2 23.71 ft. 3 28.11 ft. 4 29.96 ft. 5 45.70 ft. 6 45.70 ft. 7 45.74 ft. CURVE SHIFT DATA OBSERVED, ACTUAL, 11531.6, 11537.6, 11536.8, 11542.8, 11547, 11547.6, 11553, 11552.4, 11562.6, 11562.6, 11578.6, 11577, 11585.8, 11583.7, 11593.3, 11591, 11631.7, 11631.5, 11643.5, 11641, 11651.7, 11652.5, 11674.2, 11670.3, 11688.7, 11691, 11712.6, 11713.8, 11740.4, 11744.1, 11762.8, 11765. 1, 11772, 11775.7, 11785.8, 11787.7, 11796.5, 11800.5, 11812.6, 11816.6, 11850.2, 11853.1, 11856.2, 11858.9, 11870.3, 11872.6, 11902.5, 11906.7, 11928.8, 11929.3, 11964.5, 11963.4, 11973.2, 11972.1, 11997.9, 11995.9, 12009.4, 12008, 12055.9, 12056.5, 12079.5, 12079.1, 12106.7, 12104.4, 12116.4, 12114.1, 12150.4, 12151.7, 12158.6, 12160.4, 12183.9, 12188.9, 12195.5, 12197.2, 12238.2, 12236.8, 12244.6, 12243.3, 12266.9, 12268.4, 12269, 12271.9, 12280, 12281.6, 12293.1, 12297, 12323, 12322.6, 12347.5, 12348.3, 12403.8, 12405.9, 12431, 12437, 12454.4, 12460, 12467.1, 12468.8, 12518.8, 12521.1, 12526.3, 12531.3, 12535.4, 12543.5, 12570.1, 12572.4, 12599.4, 12601.8, DIRECTIONAL 22.63 ft. 27.03 ft. 28.88 ft. 27.03 ft. 27.03 ft. 27.06 ft. DISPLACEMENT 6.02734 6.02637 0.623047 -0.623047 o -1.66309 -2.07812 -2.28613 -0.208008 -2.49316 0.831055 -3.94824 2.28613 1.24707 3.74023 2.28613 3.74023 1.87012 3.94824 3.94824 2.91016 2.70117 2.28613 4.15625 0.416016 -1. 03906 -1.03906 -2.07812 -1.4541 0.624023 -0.415039 -2.28613 -2.28516 1.24707 1.87012 4.98828 1. 66211 -1. 4541 -1.24707 1. 4541 2.90918 1.66309 3.94824 -0.415039 0.832031 2.07812 6.02637 5.61133 1. 66309 2.28516 4.9873 8.10449 2.28613 2.49316 j - ' 12611.3, 126L ..), 1.24707 ') 12633.9, 12636.8, 2.90918 12655.8, 12659.1, 3.3252 12665.6, 12672.2, 6.64941 12674.6, 12679.2, 4.57227 12678.8, 12685, 6.23438 12706.4, 12709.5, 3.11719 12726.3, 12730.3, 3.94824 12732.6, 12735.7, 3.11719 12748.1, 12750.8, 2.70117 12766.8, 12774.3, 7.48145 12784.8, 12791.3, 6.44238 12792.7, 12800.6, 7.89648 12828.6, 12832.1, 3.5332 12837.7, 12842.1, 4.36426 12852.8, 12856.6, 3.74023 . 12867.3, 12870, 2.70215 12888.8, 12895, 6.23438 12898.7, 12901.8, 3.11719 12908.5, 12915.6, 7.06543 12922, 12929, 7.06543 12954.1, 12960.9, ! 6.8584 12979.6, 12985.6, ! 6.02637 12993.9, 12999.3, ! 5.40332 13003.2, 13010.5, ! 7.27344 13014.8, 13023, 8.10547 13019, 13026.5, 7.48145 13034.1, 13042, 7.89746 13048.8, 13056.7, 7.89746 13066.3, 13071.9, 5.61133 13080.4, 13087.7, 7.27344 13096.4, 13108.7, 12.2607 13121.4, 13127.5, 6.02637 13137.2, 13145.1, 7.89648 13161.4, 13173.6, 12.2617 13188.2, 13205, 16.833 13205.4, 13219.3, 13.9238 13213.7, 13227.9, 14.1309 13229.5, 13240.5, 11.0137 13243.2, 13254, 10.8057 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRCX Tape Subfile: 1 167 records. . . Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska) Inc. 15-30A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!. '} Remark File Version 1.000 ) The data presented here is final and has been depth snifted to a PDC (Primary Depth Control) recorded by SWS, 31-Jan-03 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRCX ROPS 0.0 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 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 AAPI 2 ROP MWD 68 1 F/HR Size Length 4 4 4 4 ------- 8 Total Data Records: 43 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11508.000000 13308.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN raw.xtf 150 BP Exploration (Alaska) 15-30A Prudhoe Bay Unit COUN STAT North Slope Alaska ) ) *** LIS COMMENT RECORD *** !! !!!! !! !! !!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRCX ROPS GRCX ROPS GRCX ROPS 0.0 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCX MWD 68 1 AAPI 2 ROPS MWD 68 1 F/HR Size Length 4 4 4 4 ------- 8 Total Data Records: 44 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11501.000000 13308.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 3 53 records... Minimum record length: Maximum record length: 42 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/12/24 422493 01 **** REEL TRAILER **** MWD 03/12/24 BHI 01 ) ) Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 11508.0000 16.5000 -999.2500 11508.5000 22.0000 -999.2500 11550.0000 50.3000 -999.2500 11600.0000 53.7831 30.5854 11650.0000 87.1002 104.8237 11700.0000 61.3236 109.6866 11750.0000 57.1935 111.1345 11800.0000 60.0947 17.0334 11850.0000 65.6793 64.1654 11900.0000 61. 4664 127.0715 11950.0000 44.7558 59.4078 12000.0000 45.4000 136.9709 12050.0000 50.5469 71. 7066 12100.0000 43.6161 119.4173 12150.0000 52.3919 128.5162 12200.0000 64.4017 64.7165 12250.0000 67.6062 59.3688 12300.0000 73.4000 44.2953 12350.0000 46.8077 42.6485 12400.0000 55.9053 46.5359 12450.0000 49.6837 42.6453 12500.0000 49.3000 87.0883 12550.0000 73.7913 65.9205 12600.0000 63.9408 47.3629 12650.0000 82.8131 52.4592 12700.0000 46.9736 50.0849 12750.0000 50.0603 50.4428 12800.0000 44.6749 22.0891 12850.0000 42.1415 76.0820 12900.0000 55.8442 51.1994 12950.0000 41.8705 105.1443 13000.0000 39.6000 92.0052 13050.0000 29.7111 89.4574 13100.0000 67.5135 37.3213 13150.0000 49.4724 53.8304 13200.0000 49.8177 36.4483 13250.0000 48.9762 23.3005 13300.0000 -999.2500 67.9781 13308.0000 -999.2500 -999.2500 Tape File Start Depth 11508.000000 Tape File End Depth 13308.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet Tape Subfile 3 is type: LIS DEPTH GRCX ROPS 11501. 0000 -999.2500 -999.2500 11501. 5000 -999.2500 -999.2500 11550.0000 50.3000 -999.2500 11600.0000 58.0000 40.9000 11650.0000 87.9000 104.7000 11700.0000 57.0000 109.8000 11750.0000 73.4000 114.1000 11800.0000 61.8000 59.9000 11850.0000 50.2000 117.0000 11900.0000 ) 5000 130.4000 ) 11950.0000 41.6000 109.1000 12000.0000 45.4000 120.4000 12050.0000 53.1000 79.2000 12100.0000 44.5000 92.5000 12150.0000 48.3000 147.5000 12200.0000 72.4000 72.6000 12250.0000 62.8000 91.3000 12300.0000 68.6000 54.6000 12350.0000 54.1000 42.9000 12400.0000 54.1000 52.8000 12450.0000 46.4000 47.2000 12500.0000 57.0000 83.8000 12550.0000 88.8000 72.9000 12600.0000 59.9000 50.3000 12650.0000 82.1000 51. 5000 12700.0000 46.4000 53.8000 12750.0000 51.2000 47.3000 12800.0000 58.9000 13.4000 12850.0000 60.8000 53.6000 12900.0000 46.4000 103.2000 12950.0000 29.0000 107.0000 13000.0000 33.8000 117.3000 13050.0000 25.2000 22.3000 13100.0000 58.9000 64.3000 13150.0000 46.4000 60.1000 13200.0000 53.1000 73.9000 13250.0000 56.0000 81. 7000 13300.0000 -999.2500 -999.2500 13308.0000 -999.2500 -999.2500 Tape File Start Depth 11501.000000 Tape File End Depth 13308.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet Tape Subfile 4 is type: LIS ) **** REEL HEADER **** MWD 03/03/02 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/03/01 280415 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** ) aOd-O~9 1157~ !! !!!! !! ! !!! !! !!! !! Remark File Version 1.000 ! !!!!! !! !!! !! ! !!! !! Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11300.0000: STOP.FT 13083.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCAT I ON : CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1. 20: NO: ------------------------------- SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKE .F EDF .F EGL .F CASE.F OSI . -Remarks 22 IIN 14E MSL o RF 64 RF N/A 64 N/A N/A DIRECTIONAL CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration Alaska, Inc. 15-30APBl Prudhoe Bay Unit 70 deg 17' 44.570"N 148 deg 33' 50.290"W North Slope Alaska Baker Hughes INTEQ 2 3/8" Coil Trak 01-June-02 500292228270 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ) ) (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is realtime data. (4) Well 15-30A was sidetracked off well 15-30 @ 11534' MD (8701' SSTVD) and was drilled to TD @ 13083' MD (8704' SSTVD) on Run 10. (5) Baker Hughes Inteq utilized CoilTrak downhole tools and the Advantage surface system. (6) The data presented here is final and has been depth corrected per instructions from BP (Doug Stoner). An error was made during data acquisition regarding a depth tie-in between two bit runs. This resulted in an 18' interval being logged and displayed twice. Gamma Ray data from 11492 - 11510' MD was removed with data below 11510' being shifted up 18'. (7) Gamma ray detector type is a scintillator. (8) The interval from 13059' MD (8705' SSTVD) to 13083' MD (8704' SSTVD) was not logged due to sensor to bit offset. MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWÐ-API units) ROPS -> Rate of Penetration, feet/hour SENSOR OFFSETS: RUN GAMMA 3 35.87 ft. 4 34.80 ft. 5 23.85 ft. 6 23.86 ft. 7 23.86 ft. 8 23.86 ft. 9 23.86 ft. 10 23.86 ft. Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 DIRECTIONAL 34.62 ft. 33.75 ft. 22.80 ft. 22.81 ft. 22.81 ft. 22.81 ft. 22.81 ft. 22.81 ft. 70 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration Alaska, Inc. 15-30APB1 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 corrected per instructions from BP Exploration (Doug Stoner). An error was made during data ) ) acquisition regarding a depth tie-in between two bit runs. This resulted in an 18 feet imterval been logged and displayed twice. Gamma Ray data from 11492 - 11510 feet MD was removed with data below 11510 feet being shifted up 18 feet *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRCXOl ROPOl 0.0 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 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 Size Length 4 4 4 4 ------- 8 Total Data Records: 43 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11300.000000 13083.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 ) ) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration Alaska, I 15-30APBl Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !!!!!! !!!! !! !!! !!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRCX ROPS GRCX ROPS GRCX ROP 0.0 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Size Length 4 4 4 4 ------- 8 Total Data Records: 43 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11300.000000 13083.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 3 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes ) **** TAPE TRAILER **** MWD 03/03/01 280415 01 **** REEL TRAILER **** MWD 03/03/02 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 11300.0000 11300.5000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13083.0000 GR -999.2500 -999.2500 8.4798 21. 2468 40.8040 90.4136 50.9968 50.8953 39.2953 51.8556 50.6778 36.2208 52.7855 52.5296 80.4277 35.7879 85.7348 80.7448 22.5076 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ) ROP -999.2500 -999.2500 -999.2500 65.2500 36.0000 14.9400 90.3400 96.0500 81. 7800 81. 4200 96.4500 69.7800 83.8000 101. 4600 64.0500 99.5100 26.4000 6.2400 153.0371 21. 0000 11300.000000 13083.000000 0.500000 feet ) ) Tape Subfile 3 is type: LIS DEPTH GRCX ROPS 11300.0000 5.7054 -999.2500 11300.5000 5.6942 -999.2500 11400.0000 13.2239 -999.2500 11500.0000 22.7802 63.7000 11600.0000 64.2239 52.0000 11700.0000 -999.2500 33.4019 11800.0000 58.0917 68.3900 11900.0000 48.0769 89.3200 12000.0000 53.7532 89.7100 12100.0000 46.1841 64.4400 12200.0000 54.7905 111.1500 12300.0000 42.3068 81.2000 12400.0000 59.8697 97.0000 12500.0000 44.4447 -999.2500 12600.0000 70.3762 -999.2500 12700.0000 30.8644 56.1200 12800.0000 33.2498 85.3400 12900.0000 29.5550 70.8800 13000.0000 -999.2500 113.9800 13083.0000 -999.2500 0.0000 Tape File Start Depth 11300.000000 Tape File End Depth 13083.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet ) ) Tape Subfile 4 is type: LIS ) ) ôJoa..oo'1 Ila3õ **** REEL HEADER **** MIND 02/10/19 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MIND 02/10/11 280415 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11300.0000: STOP.FT 13101.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- ----------------------------- SECT. 22 TOWN.N IIN RANG. 14E PDAT. MSL EPD .F 0 LMF . RF FAPD.F 64 DMF RF EKE .F N/A EDF .F 64 EGL .F N/A CASE.F N/A OSI . DIRECTIONAL ~Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration Alaska, Inc. 15-30A Prudhoe Bay Unit 70 deg 17' 44.570"N 148 deg 33' 50.290"W North Slope Alaska Baker Hughes INTEQ 2 3/8" Coil Trak 01-June-02 500292228201 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ) ) (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is realtime data. (4) Well 15-30A was sidetracked off well 15-30 @ 11534' MD (8701' SSTVD) and was drilled to TD @ 13101' MD (8704' SSTVD) on Run 10. (5) Baker Hughes Inteq utilized CoilTrak downhole tools and the Advantage surface system. (6) The data presented here is final and has been depth shifted 18 ft down per instructions from BP (Doug Stoner) . (7) Gamma ray detector type is a scintillator. (8) The interval from 13077' MD (8704' SSTVD) to 13101' MD (8704' SSTVD) was not logged due to sensor to bit offset. MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 3 35.87 ft. 34.62 ft. 4 34.80 ft. 33.75 ft. 5 23.85 ft. 22.80 ft. 6 23.86 ft. 22.81 ft. 7 23.86 ft. 22.81 ft. 8 23.86 ft. 22.81 ft. 9 23.86 ft. 22.81 ft. 10 23.86 ft. 22.81 ft. Tape Subfile: 1 66 records. . . Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration Alaska, Inc. 15-30A 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 18 ft down ,per instructions from BP (Doug Stoner). *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ) ---------------------------------------------------- GR ROP GR ROP GRCXOl ROPOl 0.0 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GR ROP MWD MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 43 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11300.000000 13101.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VAL U -------------------------------- WDFN LCC CN WN FN mwd.xtf 150 BP Exploration Alaska, I 15-30A Prudhoe Bay Unit ) ) COUN STAT North Slope Alaska *** LIS COMMENT RECORD *** ! ! !! !! ! ! !!! ! !! ! ! ! !! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRCX ROPS GRCX ROPS GRCX ROP 0.0 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRCX MWD ROPS MWD 68 68 1 1 API F/HR 4 4 4 4 ------- 8 Total Data Records: 43 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11300.000000 13101.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 3 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/10/11 280415 01 ) **** REEL TRAILER **** MWD 02/10/19 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 11300.0000 11300.5000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13101.0000 GR -999.2500 -999.2500 8.4798 21.2468 40.8040 90.4136 50.9968 50.8953 39.2953 51.8556 50.6778 36.2208 52.7855 52.5296 80.4277 35.7879 85.7348 80.7448 22.5076 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ) ROP -999.2500 -999.2500 -999.2500 65.2500 36.0000 14.9400 90.3400 96.0500 81. 7800 81. 4200 96.4500 69.7800 83.8000 101. 4600 64.0500 99.5100 26.4000 6.2400 153.0371 7.4500 0.0000 11300.000000 13101.000000 0.500000 feet ) ) Tape Subfile 3 is type: LIS DEPTH GRCX ROPS 11300.0000 5.7054 -999.2500 11300.5000 5.6942 -999.2500 11400.0000 13.2239 -999.2500 11500.0000 22.7802 63.7000 11600.0000 64.2239 52.0000 11700.0000 -999.2500 33.4019 11800.0000 58.0917 68.3900 11900.0000 48.0769 89.3200 12000.0000 53.7532 89.7100 12100.0000 46.1841 64.4400 12200.0000 54.7905 111.1500 12300.0000 42.3068 81.2000 12400.0000 59.8697 97.0000 12500.0000 44.4447 -999.2500 12600.0000 70.3762 -999.2500 12700.0000 30.8644 56.1200 12800.0000 33.2498 85.3400 12900.0000 29.5550 70.8800 13000.0000 -999.2500 113.9800 13100.0000 -999.2500 -999.2500 13101.0000 -999.2500 -999.2500 Tape File Start Depth 11300.000000 Tape File End Depth 13101.000000 Tape File Lever Spacing 0.500000 Tape File Depth Units feet ) Tape Subfile 4 is type: LIS
