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200-114
, ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. <9úo- - 1 ~ if Well History File Identifier Organization (done) o Two-Sided o Rescan Needed RESCAN o Color items: DI~LDATA £" Diskettes, No.1 OVERSIZED (Scannable) o Maps: o Grayscale items: o Other, NolType o Other items scannable by large scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds TOTAL PAGES: 1/7 NOTES: ORGANIZED BY: BEVERLY BRE~HERYL MARIA LOWELL o Other DATE/Ó-I ¡s'if; Project Proofing o Staff Proof PROOFED BY: BEVERLY BRE~HERYL MARIA LOWELL DATE:(6 ...( BY:4/tate: Scanned (done) PAGES: (at the time of scanning) SCANNED BY: BEVERLY BREN VINCENT~ MARIA LOWELL DATE: Isl ReScanned (done) RESCANNED BY: BEVERLY BR~HERYL MARIA LOWELL DATE: /tl- r I~ßØ General Notes or Comments about this file: Quality Checked (done) PAGES: ~\ L-\ r~ j-81'Ol'\ Rev1 NOT&:anned.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS ON MAR 2 3 2010 WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended zoAACZS.~os zoa-czs.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1b. Well Class: Af3 ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 2/25/2010 12. Permit to Drill Number: 200-114 309-364 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 08/09/2000 - 13. API Number: 50-029-20745-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 08/13/2000 14. Well Name and Number: PBU C-206 774 FNL, 1522 FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 730' FSL, 5136' FWL, SEC. 17, T11 N, R14E, UM 8. KB (ft above MSL): 59.95' GL (ft above MSL): 32.g' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2147' FSL, 178' FWL, SEC. 16, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD): 11647' 8708' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 663843 y_ 5960434 Zone- ASP4 10. Total Depth (MD+TVD): 15012' 8883' 16. Property Designation: ADL 028305 & 028306 TPI: x- 670461 y- 5962085 Zone- ASP4 Total Depth: x- 670746 Y- 5963509 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rioted information r 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): GR, ROP 22. Re-DrilULateral Top Window MDlTVD: 13000' 8940' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MO SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER'FT. GRADE ,TOP 80TTOM `TOP BOTTOM $~ _ CEMENTING RECORD PULLED ` '. i ~ " n ~ - / " -1 /4" 1 1 P ' " 11 1 -1 ' ~~ " 11 " ' 24. Open to production or injection? ^ Yes ®No 25. TUBING RECORD If Yes, Ilst each Interval Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MO PACKER SET MD / TVD 4-1/2", 12.6#, 13Cr80 11017' 10823' / 7965' & MD TVD MD TVD 10961' / 8100' 26. ACID, FRACTURE; CEMENT;SQUEEZE, ETC. R ~~~ s~ ~? ~ , DEPTH INTERVAL (MD AM OUNT AND KIND OF MATERIAL USED ~ 11647 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 summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical. n3sutts per 20 AAC 250.071. None x~ Form 10-407 Revised 12/2009 CONTINUE S ~ R~~~ S~ rv ~ A ~~ ~_~j ' " \ Submit Original Only 29. GEOLOGIC MARKERS (List all formations and mark ncountered): 30. TION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 12N 13020' 8941' None 13N / 14P 13630' 8917' 14P / 13N 13790' 8912' 12N 14640' 8913' 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 come to the best of my knowledge. ~ ~a Signed: Terrie Hubble ~ Title: Drilling Technologist Date: PBU C-20B 200-114 309-364 Prepared By Name/Number. Terrie Nubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: ~Imer Hoffman, 564-4592 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-ARernating-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 • • C-20B, Well History (Pre Rig Sidetrack) Date Summary 11/6/2009 WELL S/I ON ARRIVAL. DRIFT W/ 20' x 3.70" DUMMY WHIPSTOCK TAG BKR DEP SLEEVE Q 11672' SLM + 22' CORK = 11694' MD. WELL LEFT S/I, TURN OVER TO PAD OP. 11/27/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 1500/300/50 PSI RIG UP ELINE TO SET BKR 4.5" MONOBORE WHIPSTOCK. WAITING ON SUPPORT EQUIPMENT. 11/28/2009 T!I/0= 1600/200/60 Pump 4 bbl 60/40 meth spear followed by 88 bbls 1% KCUx slick & Safe Lube. 11/28/2009 RIH WITH TS: HEAD/ERS/SWIVEU 2-CENTRALIZERS/WPP TOOL WITH GR/ WPST /BKR 10/ 12.44' BKR 4.5" MONOBORE WHIPSTOCK. SET DOWN SEVERAL TIMES, PULL UP, WENT ON DOWNHOLE. SAT DOWN AROUND 9112'. TRIED TO GET PAST. PULLED UP PAST 8800' SEVERAL TIMES, TRIED ANOTHER DOWN/UP, STUCK AT 8967' (BOTTOM OF TOOL). LRS PUMPING SLICKEM FLUID IN ATTEMPT TO FREE TS. 11/29/2009 T/I/0= x 1600/280/60 Continue pumping 147 bbls of 1 % KCU x slick down TBG as directed by E-Line. Freeze protect TBG with 40 bbls 60/40 meth. RDMO. E-Line on well Q departure. IA and OA open to gauges. FWHP= 0/120/220 Operator notified. 11/29/2009 LRS PUMPING SLICKEM FLUID IN ATTEMPT TO FREE TOOLS. TOOLSTRING FREED AFTER UNSUCCESSFULLY ATTEMPTING TO RELEASE ERS AND PULLING UP TO 3100 LBS SURFACE TENSION. ALL TOOLS RECOVERED. SETTING TOOL WAS PARTIALLY STROKED. THE SETTING SLEEVE HAD A 3" GAP BETWEEN IT AND THE SETTING TOOL LOWER BODY. TOP OF WHIPSTOCK CAME OUT OF SETTING ADAPTER DUE TO THE 3' GAP AND WAS HELD ON BY SETTING ROD. WPP TOOL IS MISSING ONE WHEEL FROM GRIPPING CENTRALIZER. IT IS STAINLESS STEEL, AND 15/16" IN DIAMETER AND 3/16" THICK. WELL LEFT SHUT IN. FINAL T/I/O = 200 / 300 / 50 PSI. ATTEMPT COMPLETE. TO BE SET AFTER SL D&T, B&F. 11/30/2009 T/I/0=400/240/60 Assist slickline w/brush-n-flush. Pump 2 bbls neat meth followed by 170 bbls 180° diesel down tbg. FWHP's=1100/880/560 S-line in control of well at LRS dep. 11/30/2009 WELL S/I ON ARRIVAL. BRUSH & FLUSH W/ 3.805" G-RING, 4 1/2" BRUSH TO 10889' SLM / 10910' MD, TBG STUB. DRIFT W/ 3.70" x 20' DMY WHPSTK TO 4661' SLM, UNABLE TO GET ANY DEEPER. 12/1/2009 RAN 3.80" CENT., 3' 1-7/8" STEM, 3.80" CENT., 3.75" LIB TO 4681' SLM. IMPRESSION INCONCLUSIVE, METAL MARKS ON CENTRALIZERS. SWAGE RESTRICTION C~? 4681' SLM, W/ 3.80", 3.77", 3.76" SWEDGE W/ NO IMPROVEMENTS. RAN 3.70" x 10' DMY WHIPSTOCK ABLE TO PASS 4681' SLM W/HEAVY JARRING. RAN K.JT, K.JT, 3-1/2" BRUSH, 2.30" G.RING & RATTLE ST. #3, 2, 1 & DRIFTED TO 10870' SLM. DRIFT W/ 3.80" CENT, 3.80", 3.77" & 3.76" SWAGES TO LINER TOP Q 11669' SLM / 11694' MD. DRIFT W/ 3.63" BAKER WHIPSTOCK WORKED THROUGH RESTRICTION C~ 4681' SLM. UNABLE TO PASS RESTRICTION C~ 9011' SLM, W/ 3.63" BAKER WHIP STOCK (possibly dogleg or unknown fish). RAN 3.80" MAGNET TO 10889' SLM, NO REC. Note: 15/16" x 3/16" SS WHEEL STILL IN HOLE. 12/2/2009 B&F W/ 3.805" G.RING, 2 x 4-1/2" BRUSH, 2.50" G.RING, FROM SURFACE TO 10889' SLM. B&F W/ 180 BBLS OF HOT CRUDE, THEN 180 BBLS OF DIESEL @ 5 bpm TO FLUSH TBG. RAN 3.64" BAKER WHIPSTOCK THROUGH RESTRICTION C~ 4681' SLM FOR 15 MIN, THEN COULD NOT GET PAST. RAN KOT W/ 1.70" LIB TO 4678' SLM, GOOD PIC OF RK LATCH. RAN 2.70" x 20' DMY WHIPSTOCK TO LINER TOP C~3 11669' SLM / 11702' MD. RAN 3.70" x 10' DMY WHIPSTOCK TO 4681' SLM, BEAT THROUGH 3 TIMES. WELL LEFT S/I OPER NOTIFIED. 12/2/2009 T/I/0=500/320/40 Assist S-Line W/ Brush & Flush. Pumped 205 bbls 190° Crude down Tbg ®2 BPM while S-Line brushed tbg. Flushed Tbg w/ 180 bbls Diesel Q 5 BPM. S-Line on location upon departure. Casing valves open to gauges. FWHP=500/500/400 1/21/2010 WELL S/I ON ARRIVAL. R/U SLICKLINE. FWHP=200/220/0 Page 1 of 2 C-20B, Well History (Pre Rig Sidetrack) Date Summary 1/22/2010 PUN PDS 40 ARM CALIPER PER PROGRAM. (GOOD DATA) FWHP=170/220/0 WELL LEFT S/I, DSO NOTIFIED. 1/26/2010 MORU CT. Preform weekly BOP test. RIH to 11,702 w/3/70" dummy Whipstock. POOH. MU Baker motor and 3.80" mill assy. RIH. 1/27/2010 RIH w/Baker 3.80" OD mill assy. to 11,702'. No obstructions. POOH. Freeze protect tbg. RDMO. Job completed. 1/30/2010 T/I/O =Vac/230/0. Temp = SI. Bleed IA & OA to 0 psi. No AL. IA FL C«~ surface. Bled IAP from 230 psi to 0 psi in 15 min. Monitor for 30 min. IAP unchanged. FW HP's Vac/0/0. 1/31/2010 T/I/O = 0/0/0 Set 6" CIW J TWC C~?108" w/ 1-2' ext. Torqued tree to spec. (2 nuts on SSV - MV flanged had 1/8 turn movement.) Pressure tested tree to 4800 psi / 5 min. (passed). Pulled TWC. Greased tree 100% Aeroshell. 30% Clare in swab valve. 2/14/2010 T/I/O=SSV/0+/0+. Temp=S1. T FL (for FB). No AL. Note: Requested Grease crew pump open SSV, will be out -0530. Swab platform insufficient for access as per FO. Requested Drilling scaffold from WS, will be out during Dayshift. 2/16/2010 T/I/O = 0/0/0 Load & Kill Tbg. Pumped into the Tbg with a 2 bbls neat methanol spear followed by 292 bbls of 1 % KCI capped with 40 bbls of crude and 5 bbls of diesel. Final W HP's = 0/780/440 2/17/2010 T/I/0= 0/275/50 set 6" CIW BPV #421 C~? 108", 1-2' ext. used. 2/17/2010 T/I/0= BPV/150/5. Temp= SI. WHPs (pre-CTD). IA FL @ surface. No wellhouse. Flowline disconnected. 2/18/2010 T/I/O=BPV/150/0+. Temp=S1. Bleed IA & OA to 0 psi (CTD prep). IA FL C~ Surface. Bleed IAP & OAP to 0 psi. Monitor 30 min. Final WHPs=BPV/0/0. Page 2 of 2 • BP EXPLORATION Page 1 Operations Summary Report Legal Well Name: C-20 Common Well Name: C-20 Spud Date: 8/8/2000 Event Name: REENTER+COMPLETE Start: 2/17/2010 End: 3/10/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: .NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 2/21/2010 100:00 - 06:00 I 6.001 MOB I N I WAIT I PRE 06:00 - 06:15 0.25 MOB N WAIT PRE 06:15 - 18:00 11.75 MOB N WAIT PRE 18:00 - 00:00 I 6.001 MOB I N I WAIT I PRE 2/22/2010 100:00 - 06:00 I 6.001 MOB I N I WAIT I PRE 06:00 - 06:15 0.25 MOB N WAIT PRE 06:15 - 13:00 6.75 MOB N WAIT PRE 13:00 - 18:00 5.00 MOB N WAIT PRE 18:00 - 00:00 I 6.001 MOB I N I WAIT I PRE 2/23/2010 00:00 - 02:00 2.00 MOB N WAIT PRE 02:00 - 02:40 0.67 MOB P PRE 02:40 - 06:00 3.33 MOB N WAIT PRE WAIT ON WIND TO LESSEN TO OPEN CELLAR DOORS. RIG IS STILL ON K PAD. CONTINUE NEEDLE GUNNING AND PAINTING SPILL BASIN AROUND TREE AND GENERAL RIG HOUSEKEEPING. CREW CHANGE. MAKE RIG ROUNDS AND CHECKS. CONTINUE WITH RIG CLEANING AND MAINTENANCE PROJECTS. CONTINUE TO MONITOR WIND CONDITIONS. SUSTAINED WINDS ARE 25-30. GUSTING TO 50 MPH. GPB IN PHASE 1 CONDITONS ON MAIN ROADS, LEVEL 2 ON ALL OTHER. C PAD IS VERY HEAVILY DRIFTED IN. RIG REMAINS ON K PAD. CONTINUE WAIT ON WIND, 25-30 SUSTAINED, GUSTING TO 40 MPH. REMOVE C-PUMP FROM MOTOR ROOM AND REBUILD WITH NEW COMPONENTS. FUNCTION AND PRESSURE TEST IT, GOOD. CONTINUE WAIT ON WIND. RIG IS STILL ON K PAD, UNABLE TO OPEN CELLAR DOORS SAFELY W ITH 25-40 MPH WINDS. CREW CHANGE. DISCUSS WEATHER. MAKE RIG CHECKS AND ROUNDS. CONTINUE CLEANING RIG. REVIEW PROCEDURES FOR ACCURACY AND REFLECTING CURRENT PRACTICE. CONTINUE TO MONITOR WIND. 25 SUSTAINED, GUSTING TO 35-40 MPH. PAINT THE INSIDE OF THE SHAKER TROUGH GOING TO PIT #1. CONTINUE MONITOR WIND. NORDIC CREW CHANGE AT 20:00. AT 21:00 WIND IS SUSTAINED 20 MPH WITH 30 MPH GUST. KEEP MOVING SYSTEM HYDRAULICS WARMED UP BY ROTATING TIRES PERIODICALLY. CLEAR SNOW FROM AROUND TIRES AND CUTTINGS BOX. REMOVE OUTSIDE STAIRS FROM SECOND LEVEL. AT 22:30 WIND IS SUSTAINED 18-20 MPH, GUSTING TO 26 MPH. INSTALL LOUVERS ON DRILLERS SIDE RADIATOR HATCH. WIND IS NOW SUSTAINED 15 MPH GUSTING TO 20. PJSM WITH TP AND DRILLER, DECIDE TO OPEN DOORS AND MOVE OFF WELL. USE LOADER FOR WIND BLOCK, OPEN CELLAR DOORS. MOVE OFF WELL AND DOWN THE PAD ABOUT 100 YDS. SET DOWN RIG, INSPECT ROAD TO C PAD. ROAD TO C PAD IS DRIFTED SHUT. ROADS AND PADS CONTACTED, MOST LIKELY WILL BE AFTER SHIFT CHANGE BEFORE ANY EQUIPMENT IS FREE TO CLEAR IT. Printed: 3/10/2010 1:48:22 PM • BP EXPLORATION Page 2 c#~ Operations Summary Report Legal Well Name: C-20 Common Well Name: C-20 Spud Date: 8/8/2000 Event Name: REENTER+COMPLETE Start: 2/17/2010 End: 3/10/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 2/23/2010 06:00 - 06:15 0.25 MOB N WAIT PRE CREW CHANGE. DISS OPS. MAKE RIG OUTSIDE ROUNDS AND RIG CHECKS. 06:15 - 13:00 6.75 MOB N PRE CONTINUE TO WAIT ON SNOW REMOVAL CREW TO CLEAR E PAD ACCESS ROAD AND C-PAD. 13:00 - 16:30 3.50 MOB P PRE HOLD PRE MOVE MEETING WITH SECURITY, RIG CREW. LEAVE K PAD FOR C PAD. HEAVY EQUIPMENT CLEARING ROADS AHEAD OF THE RIG. 16:30 - 20:50 4.33 MOB N WAIT PRE PULL RIG ONTO EDGE OF C-PAD WAITING ON R&P TO CLEAR ACCESS SNOW SO WE CAN SPOT THE RIG & EQUIPMENT OVER WELL ACCEPTED RIG ~ 16:30 20:50 - 21:20 0.50 MOB P PRE PJSM TO SPOT RIG OVER C-20C WELL 21:20 - 00:00 2.67 RIGU P PRE MOVE RIG & SPOT OVER C-20C WELL SPOT & RU SATELITE CAMP & WELDING SHOP BERM UP AROUND CELLAR INSTALL IA & OA MONITORS INSTALL FUSABLE CAP SPOT & RU 7T WITH HARDLINE 2/24/2010 00:00 - 00:15 0.25 BOPSU P PRE PJSM TO NU BOPE 00:15 - 01:30 1.25 BOPSU P PRE NU BOPE 01:30 - 06:00 4.50 BOPSU P PRE PT BOPE 250 PSI LOW & 3,500 PSI HIGH, 2,500 PSI HIGH ON ANNULAR. TEST WITNESS WAIVED BY AOGCC REP L.GRIMALDI. 06:00 - 06:15 0.25 BOPSU P PRE CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG CHECKS AND OUTSIDE ROUNDS. 06:15 - 13:30 7.25 BOPSU P PRE CONTINUE TO TEST BOP EQUIPMENT. TEST AS PER AOGCC BEGS, DWOP POLICY, PERMIT TO DRILL, AND APPROVED WELLPLAN. RECORD TEST DATA ON NORDIC AND SLB DATA SYSTEMS. ALSO RECORD ON PAPER CHART. E-MAIL COMPLETED TEST FORM TO AOGCC. NO FAILURES NOTED. 13:30 - 15:00 1.50 BOPSU P PRE HOLD PJSM. RIG UP DSM BPV LUBRICATOR. ENGAGE AND PULL BPV. WELL IS ON A VAC. DISPLACE REEL TO KCL. 15:00 - 15:30 0.50 WHIP P WEXIT ATTEMPT TO LOAD WELL WITH KCL. PUMP 50 BLS AT 2 BPM. NO RETURNS. 15:30 - 17:00 1.50 WHIP P WEXIT PU INJECTOR. CUT OFF HEAD. GET ON WELL. PUMP SLACK FORWARD. 4.3 BPM AT 1790 PSI. RU CUTTER. CUT 345' OF COIL AND FIND WIRE. 17:00 - 18:45 1.75 WHIP P WEXIT MU BAKER CTC 18:45 - 19:20 0.58 WHIP P WEXIT PUMP SLACK FORWARD FOR ONE COIL VOLUME 19:20 - 19:45 0.42 WHIP P WEXIT PT CTC TO 3,800 PSI PULL TEST CTC TO 36K LBS 19:45 - 20:00 0.25 WHIP P WEXIT BTT RU TOOLS ON THE CATWALK 20:00 - 20:50 0.83 WHIP N WEXIT WAIT ON SLB MEMORY FOR PIP TAGS 20:50 - 21:00 0.17 WHIP P WEXIT INSTALL PIP TAGS INTO WS 21:00 - 21:20 0.33 WHIP P WEXIT PJSM TO MU WS SETTING BHA 21:20 - 21:50 0.50 WHIP P WEXIT MU WS SETTING BHA Printed: 3/10/2010 1:48:22 PM • BP EXPLORATION Page 3 ~ Operations Summary Report Legal Well Name: C-20 Common Well Name: C-20 Spud Date: 8/8/2000 Event Name: REENTER+COMPLETE Start: 2/17/2010 End: 3/10/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 2/24/2010 21:50 - 00:00 2.17 WHIP P WEXIT RIH WITH WS SETTING BHA 2/25/2010 00:00 - 00:45 0.75 WHIP P WEXIT RIH WITH WS SETTING BHA TO 11,330' 00:45 - 01:45 1.00 WHIP P WEXIT LOG GR FROM 11,330' TO 11,376' -11' CORRECTION RESET DEPTH TO 11,365' PU ON COIL TO GET AN UP WT PULLED 73K LOG CCL FRO 11,359' TO 11,640' 01:45 - 02:15 0.50 WHIP P WEXIT RIH TO 11,664' CLOSE EDC & PRESSURE UP TO 2,900 PSI & BROKE OVER TOWS SET ~ 11 647' SET DOWN ON WS WITH 3.5K TRAY FACE AT 55L. 02:15 - 02:50 0.58 WHIP P WEXIT POH WITH WS SETTING BHA STOP ~ 10,904' 02:50 - 03:20 0.50 WHIP P WEXIT LINE TO TIGER TANK FROZE STOPPED POH AS A PERCAUTION UNTIL THE LINE WAS CLEARED. 03:20 - 06:00 2.67 WHIP P WEXIT OPEN EDC POH WITH WS SETTING BHA CLOSE EDC ~ 500' 06:00 - 06:15 0.25 WHIP P WEXIT CREW CHANGE. DISCUSS OPS. MAKE RIG CHECKS AND ROUNDS. TAG UP AT SURFACE. PJSM FOR HANDLING THE BHA. 06:15 - 07:15 1.00 WHIP P WEXIT GET OFF WELL. UNSTAB COIL. LD BHA TOOLS. BTT SETTING TOOL LOOKS NORMAL. MU MILLING BHA WITH 2 JTS PH-6. REMOVE DGT TO . REDUCE TOOL EXPOSURE TO VIBRATION. 07:15 - 09:00 1.75 STWHIP P WEXIT FOUND AN ICE PLUG BELOW WELL HEAD. MU NOZZLE BHA. JET THROUGH SAME. NOTE ALOT OF FINE METAL SHAVINGS IN RTNS. 09:00-09:30 0.50 STWHIP P WEXIT MU WINDOW MILLING BHA. 109.31 OAL STAB COIL. TEST TOOLS. GET ON WELL. 09:30 - 11:00 1.50 STWHIP P WEXIT RUN IN HOLE. CIRC AT MIN RATE THROUGH MILL. 11:00 - 15:00 4.00 STWHIP P WEXIT TAG WHIPSTOCK AT 11,647'. 53K# UP WT, 14 K# DN WT. CONTINUE DISPLACEMENTTO USED GEOVIS FLUID. ~• ~ ~_ MILL AHEAD FROM 11,647'. 37°`~ ~ 3010 PSI FS AT 2.51 BPM IN/OUT. .~ L DHWOB: 1-1.5K# TIME MILL AT 6 MINUTES PER 1/10TH FT. 15:00 - 00:00 9.00 STWHIP P WEXIT CONTINUE TO MILL WINDOW FROM 11,648.8' 3010 PSI FS. 200-300 PSI MOTOR WORK. BHP: 4637 PSI ECD: 10.4 PVT: 328 BBLS. EXTEND TIME INCREMENT TO KEEP DHWOB BELOW 3K#. 18:00 = 11,651', 300 PSI MTR WK, 1.8K WOB, 10.47 ECD 20:00 = 11,653', 300 PSI MTR WK, 1.4K WOB, 10.45 ECD 21:00 = 11,654', 250 PSI MTR WK, 3K WOB, 10.46 ECD 22:00 = 11,655', 300PSI MTR WRK, 1.2K WOB 10.46 ECD 23:00 = 11,656', 300PSI MTR WK, 1.9K WOB, 10.45 ECD FINISHED WINDOW DRILLING 10' OF RAT HOLE 00:00 = 11,658', 500PSI MTR WK, 2.4K WOB, 10.47 ECD 2/26/2010 00:00 - 02:15 2.25 STWHIP P WEXIT CONTINUE MILLING WINDOW /RAT HOLE Printed: 3/10/2010 1:48:22 PM TREE = 6-118" CNV WELC,H~A D = McEl/OY AOTUATOR= KB. ELEV - AXELSON ~ 60.0' BF. ELEV - KO Pm-..-.-..-.-...- - ~ 34.3'. - -~ 1000' Max Angte = 97 @ 13007' Datum MD= Datum TVD 11979. 8890' SS ~13-318" CSG, 72#, L-80, ID = 12.347" ~ 2891' Minimum ID y ~,~'' 1 ~ ~7tI' TQP 01= 3 d ~'~9 ~i" I_I~J E TOP OF 71EBA CK 8832' CAA S (IFT' MA NDRFLS ST MD TVD DEV TYPE VLV 'LATCH PORT DATE 3 4688 3728 54 Iv~1AG [?OME RK 16 03120/10 2 ' 8318 5845' 55 MMG SO RK ': 20 03(20/10 1 :10734 7878'. 13 KBG2 DMY BK 0 01 /24!05 I9-518" X 7" BKR ZXP PKRfI-IEBACK, ~ = 6.3i 3" 7" BKR HMC LNR HGR, 1D = 6.250"" PERFORATION SUMMARY REF LOG: ????? ON n~nfddlyy ANGLE AT TOP PERF: 89° @ 12480' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12480 - 12560 O 03/04/10 2" 6 12750 - 12780 O 03/04/10 2" 6 13110 - 13300 O 03/04/10 2" 6 13460 - 13600 O 03/04/10 2" 6 13660 - 13790 O 03/04/10 2" 6 13840 - 14090 O 03/04/10 2" 6 14170-14270 O 03/04/10 CSG, 47ft, L-80, BTRS, ID = 8.681" I-{ 11705' f 4-1/2" TBG, 12.6#, 13CR:.0152 bpf, ID = 3.958" I 4-112" TBG, 12.6#, L-89,..9152 bpf. ID = 3.958" I LNR, 26#, L-$D; .03$3 bpf, ID = 6.276" P CAF 3-311 fi" x 2-7t$° LNR., !D = 2.300' SAFETY NO WELL FDiCEIDS TO° @ 12000' $~ HORIZ. (ae1' 12fi09'. ' 12"CHROME TBG"` 4-~' .. ' 1' C1 Tt1P t F ~ r T SL ~ 5 v:~ HAND:; I~; Nt;' E DJF?lNti 2605 R~VO 21' 7"X4-1 /2" XIO 1~ ~~~,' ~ 4112" HES X NIP, ID = 3.813" MILLOUT WINDOW (C-20A18192" - 9028' ..1{18{}2'. ~4-112" H£S X NIP iD= 3,813" l 1'.0823' i, 7" BKR S-3 PKR, ID = 3.875" 10889' 4-112" HES X NIP, ID = 3.813" 10910' TBG STUB {01118105} 10911' l7NIQUE MACHINE OVERSHOT 10950' 4-112" OTIS X NIP, ID = 3.81 10961' ~~... - 7 BKR S-3 PKR, ID= 3 875" 10984' 4-172" OT1S X NIP, ID = 3.813" 10910' 11005` 4-112" OTIS XN NIP, MILLED ID = 9.80" 11016' 11017' a-112^ WLEG 11019' 7" X 4-i 12" BKR ZXP PKR/TB, ID = 4.438" 11027' 7" BKR HMC LNR HGR.. ID = 4.438" 11205' ; . 11260" ~ 4-11`.?" BKR KB LTP Ill = 2. 3"` 11:250' ~ t ~ C3~} Cl~ CIT1t '[-~}~ 4._1x2" Mcanahore Whipstock 11648' -' TOP OF 2-718" LNR, ID = 2.372" 1'1702' 4-112" LNR., 12.6#, L-80, .©152 fapf, tD = 3.85$" ~ 13000' PBTD 14949' 2-7/8" LNR, 6.16#, L-80, .0058 bpi., ID = 2.372" --15012' 12599" 3-311'6x2-7J8Xsover'. .~ -°-- ~ 3-3196" X 2-7t8" I'aner 13400' ~-12-7f8" BKR CIBP SET (09!28/06) g DATE REV BY COMMENTS DATE :REV BY COMMENTS 0711218'2 ORIGINAL COMPLETION 03121(10 ' SWC/SV GLV C/O 07112!97 RIG SIE3ET-RACK 0811fi100 CTD SIDETRACK {C-2081 01125145 RWLffLM RWO 43109110 MOF#71C1 ' GTD SIDETRACK {C-20C1 93120110 TLH DRLG HO CORRECTIONS PRUDHOE BAY UNIT WELL: G20C PERMIT No: AI'1 No: 50-029-20745-03 SEC 19, T11 N, R14E, 774' SNL & 1522" VVEi. BP Exploration {Alaska} • • :`~. :.~: e l ;-~ i ~ ` j ;, J ~ ;s t .:: .~ ~ _. ~'~ ~ ~~ ~ ~. 4 ~~~ k ~ ~ ~ ~. t ~ ~° ~~ i 4 r x ~ ~, ~ k ~ ~ ~ ~ ~ ~ ~~' ~ ~ ~' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~s~ ~ ~ ~ ~ ~ ~ .~'~~y ~ ~~'a ~ ~f~~ ~k~ ' ~ ~ ~ SEAN PARNELL, GOVERNOR ~i ~ ~.~.. 4 ~' ~..:.~ 4,~"=., ~~ a ~ ~g r r 4.t.t; ~~.~ 7 ~ ° ~a.~ ~ %~ E~.~ ~a.~ ~~~ ~d~ ~-.7~ ~~ t'~lsi~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5~RQATIOI~T CO1~iII~iISSIOI~T a' ANCHORAGE, ALASKA 99501-3539 ~~ PHONE (907) 279-1433 ~ FAX (907)276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 ~ ~ ~ t ! ~ Anchorage, Alaska. 99519-6612 `~~,, f Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G20B Sundry Number: 309-364 ~t~~,~~~~ ~I~`u ~ ~ ~~~~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 lett~r, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Gommission decision to Superior Court unl.ess rehearing has been requested. Sincerely, ~"~ Daniel T. Seamount, Jr. Cha.ir DATED this _ day of November, 2009 Encl. ~~~'~ STATE OF ALASKA ~ ~~ \ ALAS IL AND GAS CONSERVATION COMM N ,0 ~b ~o ~~~~/ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request aDCh01'~~@ ~ Abandon ~ ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended Well ^ ARer Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Specify: ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Driil Number BP Exploration (Alaska) Inc. ~ Development -^ Exploratory 200-114 - 3. Address: ^ Service ^ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20745-02-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-20B - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: , , 10. Field / Pool(s): _ ADL 028305 & 028306 Prudhoe Bay Field / Prudhoe Bay Oil Pool 1 L PRESENT VYELL CONQlTION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15012' - 8883' - 14949' 8888' 13400' None Casin Size MD ND Burat Ca1Fa Structural Conductor 1 " 1 1 Surface 28 1' 1 /" 89 ' ' 7 Intermediate 9-5/ " ' ' 7 47 Production Liner 2 7' 7" 32' - 11 5' 1'- 83 ' 7 Liner 1 7' 4-1/ " 1101 '- 1 0 0' 1'- 894 ' 7500 Liner ' " ' ' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12560' - 14895' 8931' - 8894' 41 /2", 12.6# 13Cr80 11017' Padcers and SSSV Type: 7" Baker'S-3 packer (2) Padcers and SSSV 10823' / 7965' MD (ft) and ND (ft): 10961' / 8100' 12. Attachments: 13. Well Class after proposed work: ~ Descrip6on Summary of Proposal ^ BOP Sketch ^ Exploratory ~~Deve~opment ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 10, 2009 ~ Oil ^ Gas ^ WDSPL ^ GSTOR ~Abandon 16. Verbal Approval: Date: ~ W~~ ~ G~~ ~ yyq~ ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the going is true and correct to the best of my knowledge. Contact Me1 Rixse 564-5620 Printed Name ~ II Title Engineering Team Leader ~f Z ~ Terr~uH trble, 564-4628 Signature Phone 564-4711 Date ~ Commission Use On C~iti s of approval: Not' Commission so that a representative may witness Sundry Number: ,,,~~~'"~~ ~ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance ~ ~/Q~ ~OSa lJd~ (G$~ Other: qh r~ K-~Gl / eS ~~~ [~ J ~' ~Q~ z 7 ~SC~ / Subsequent Form Required: J~ ~~o ~ / APPROVED BY ~ Approved By: COMMISSIONER THE COMMISSION Date Form 70-403 R~se'd /2 ~$ ~1 ~S t l ~~`~ ; ~ ~~'3~ °! ~~IGIf~~L ~L~.~G~ V I.~~r~~'J`'~ QCT 2 7 20Q9~Do~p~t n Submit In Duplicate '~~s C~ To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: October 22, 2009 • bp Re: C-20B Perforation Abandonment and new CTD Sidetracks Sundry Approval Request Sundry approval is requested for PBU C-20B. Isolation of the existing perforations with a cement abandonment plug followed by a new coil tubing drilling sidetrack is proposed. The CTD side track will be a high angle step-out well to target Z1 A/1 B reserves north and east of C Pad. WELL HISTORY/CURRENT STATUS: C-206 is a horizontal Z1 A CTD toe extension drilled in August 2000. It was completed with 755' of Zi A perforations with the original C-20A perforations cemented and isolated. Production followed a typical Z1A trend, with the oil rates decreasing and the GOR increasing at a gradual rate. 75' of Z1 A perforations were added closer to the parent well, C-20A, in May 2003 and increased the oil rate. C-20B produced fulltime until June 2004 when it was shut-in for TxIA communication. A RWO was completed in early 2005, but the well reached MGOR only four months later and started cycling. In Sept 2005, 150' of additional Zi A perforations were added without notable 'rmpact. A CIBP was set a year later at 13400' MD to shut off all perfs except the 75' shot in 2003, but the plug did not have much of an impact on the GOR trend. Drops in both oil and gas rates were observed. As the well's ontime continued to degrade, 87' were reperfed in the parent C-20A but added no rate. In Aug 2008 all 290' of perfs in C-20A were reperfed without success. The well is currently shut-in for high GOR. During CTD screening in Aug 2009, the well passed a MIT-IA to 3000 psi, a MIT-OA to 2000 psi, and the PPPOT-T. Although the well was completed with 13Cr tubing during the 2005 RWO, the CTD whipstock is planned to be set deep in the old 4-1/2" L-80 liner so a caliper log was run 8/16/09. The caliper log indicated the tubing is in good-to-fair condition and the liner is in average condition with a max wall penetration of 48%. REASON FOR SIDETRACK: ~~nn~v~ ~~`~~O''s P~°`~~"`'~" ~ -~v K-r-GoR , ~~~~~~ weu C-20B is not a competitive well, exhibits no recharge, and has minimal remaining value. ,~~~~~~~.~;,~; ~,~~ ~~J ,~,~ /k~~ f~'vm l:~ .~,~. ~.~; ~4,- y- - Pre-Rig Operetions f ~~, (QI 7k~~ ~'~~ ~-G/~"~''~~~ 1. O MIT-OA - 2000 psi Passed 08/19/2009 DONE ~~d` ~e ~~ ~Pf*{~ GO~f. 2. O MIT-IA - 3000 psi Passed 08/19/2009 DONE 3. O PPPOT-T, AGLDS 08/03/2009 DONE )kp~~'t- "~w ~.'C!l S~v~ld 4. S Drift for 4-1/2" monobore whipstock to ~11,700' MD j~a,,~ ~t^if1,h:'I'•'T~ ~~~°"'~r~/ 5. E Set 4-1/2" monobore whipstock ~ 11,648' MD (see procedure below.) ~c j~t ~ T~e ~~,+~q,~,,,~,~~ v; J~ 6. C Squeeze cement past whipstock. 7. O MIT-Tubing 3000 psi G~~~~~ //~~~p~ 8. O PT tree (MV,SV,WV), function LDS 9. O Bleed gas lift and production flowlines down to zero and blind flange 10. O Remove S-Riser, Remove wellhouse, level pad - Complete ~~. ~ 3~~ Rig Sidetrack Operations: (Scheduled to begin on February 1, 2010) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. at 1 4. Drill build/turn section with 425" l~nter bit, and land well. ` 5. Drill lateral section to 14,300' MD w/ resistivity log. 6. Run 3-1/2"x 3-3/16"x 2-7/8" solid liner w/cementralizers to TD. Place liner top at 10,270' MD. 7. Cement liner from TD to TOL (11,270'MD ) with 15.8ppb cement. 8. Clean out liner/Run MCNUGWCCL log. 9. Test liner lap to 2000 psi. 10. Perforate per geologist. 11. Set liner top packer (if fails liner lap test) 12. Freeze protect well to 2500'. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. el Rixse ~ CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble _ ~.,~- cyw LHFAD= NI~EVOY CTU0.TOR= Al(~S~I . ~e1/ = 60.0' . ELEV = 34.3' P = 1000' Angk = TT ~ 149xi' m ND = 11936' tum ND = 8800' SS 7 3-~8" CSC3, 72k, L-80, ID = t 2.347" 2~1' Minimum ID = 2.372" ~ 11702' TOP OF 2-7/8" LINER T~ OF T~ACK ~32' GA S IIFT MA NDR~S ST NID ND DEV 7YPE VLV LATCH PORT QATE 4688 3728 54 MNG DMY RK 0 08I7 9/09 a as~ e seas ss ~nnc oan ~c o oer~ sros ~ ~oraa ~a~a ~s Ks~z on~n sK o o~nar~ ~9-5lS" X 7" BKR 2XP PI~i/TtEBACK, ID = 6.313" ~ T' RI[O 4YM. I t~tl7 LY317 n= a xm ~ PERFORAl70N SUNMARY REF LOG: SPEf82Y GRIROP ON 08I00 ANGLE AT TOP P6~Fr 89' ~ 12560' Note: Refer to Roduction OB for historical rf data SIZE SPF Ih[f6~1/AL OpnlSqz LIATE S~ PG: 2 F~ ~ORATON d4TA ~ ~ ~ ~ C_~ O~ snFErv ~rES: ~ Exc~s io~ ~~~~ a riowz. xc ~ 1260!'. '"' 4-1/Y CF~iOME T9G" 4-112 WLBf313 N~T INTO TOP ~ LNZ TIBBIICK SLY. 841lAtiE SFIOULDBi~ TOOLS NMIL FU1N0 l~ ON WL~fi. ~~^ 6 SS BANDS IN HOLE IXAi1l~K'a 2006 RWO y~' T' X 41l7' lV0 1~' 41/2" F~S X 1~6P, ~= 3.813•' CSG, 47A, L-80, BTRS, ID = 8.881" H 11T06' ~~~1 41/2" TBG, 72.81i, 13CR .0152 bpt, ~= 3.958" 10910' 41 Y2° TBG, 12.8~, L-B0, .0152 bpi, ~= 3.858" 11016' T' Ll~i, 26A, L-80, .0383 bpf, D= 6.278" ~-{ 11206' ~T~ OF 2-7/8" LP62, ~= 2.37Y H ~~ 41l2" LI~2, 12.8/, L-80, .07 S2 bpf, ~= 3.958" I 13000' I M~~arr NnaiooMi ~c-aoe~ sssr - ~r 1~02' u41l2"F~SXWP, ID=3.813" 10Q23' T' BKR S-3 PKR, ID = 3.875" 1 QB$9' 41 /2" HES X I~, ID = 3.813" -_ 10910' 1'6Ci STUB (01 M 8tt15) 10911' lN-IQUE MqG-I~-E OV HtSHOT 1 pg(p' 4ll2" O71S X I~, ID = 3.813" 10881' 7" BKR S-3 RCR. ID = 9.875" 1 Q9gq` 41/2" OT15 X t~, ~= 3.813" 11005 U41/2" Ol'~ XN NHP, N~ LED ~= 3.80° 1107T 4117' WLEO 11019' u7" X 4112" Blfft ZXP PKRlTB, ~= 4:438" f 11027' 7" Bfa2 F~AC lNR HGR, ~= 4.438" 11884' 3-3/4" BKR DEPLOY SLV, ID = 3.00" \ 13400' 2-7/B" BKR GBP SET f09/28J0~ PBTD 14949' 2-7/8" LNR, B.16R, L-80, .0058 bpf, ID = 2.372" 15012' OAIE RE1/ BY COAAuB~fTS ~4TE RE1f BY (bIM~~Ni'S O7H2fl2 OiidAML GOMPL.ETION OBf22lOD ImBl51/ ADPERF G7112187 EiG SICETWICK 0922A8 RPC/PJC C~I.V CJO (08Pi OM10I00 CTDSIDET~ICK 01/23/05 RINLJTLH (mA1C 12/22106 OOBIPAG PB~F CORf~CTION (OB/13J05) 0&Z6I0~ SRBIPJC PBiFORAT10N5 PRUDFIOEBAY IAJfT 1N~L: G2~ P~7NIT No: "2001140 AR No: 50-0232W45-02 5~ 19, T11 N, R14E, 774' SI~. 81522' ~ 6cpbratia~ (A~ks) ~„~~~, LHEAO= CTUATOR= WbEVOY AXELSON KB. ~EV = -- _ - --. BF. a EV = 60.0' _ __ _- - 34.3' ---- - KOP = - _ - 1000' -- - - -- __ N~x Angle = 37 Q 14923' _ _----- L~tum ND = - 11935 O~tum ND = 8800' SS C~~ 0^ SAFETY NOTES: L D(C~S 70^ ~ ~moo~ a rawz ~~ ~ 12609'. '"' 4-112' Ci#ZDME TBG"' 4-1/2' NI~EG IS NOT INTO TOP OF LNR TIE-BACK SLV. PmDiis~d ~' I'~ S r~:L:~ck SQUARESFIOULDHi~700LSWILLHANGIRONWLEG. 6 SS BANDS IN HOLE DURING 2005 IaIVO ~gg3' N4-12" HES X NIP, ID= GAS LIFT MANDRELS ST MD TVD DEV NPE V~V LATCH PORT LIATE 4688 3728 54 MMG D~AY RK 0 08/19/09 2 8318 5845 55 MAAG CMY RK 0 08/19/09 1 10734 7878 13 KBG2 OMY BK 0 01/24/O5 Minimum ID = 2.300" ~ 11270' TOP OF 3-3/16" LINER PERFOR4T10N SUuNW RY REF LOG: SPERRY GR/ROP ON 08/00 ANGLEATTOP P92F: 89° ~ 12560' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL OpNSqz a4TE SEE PG. 2 FOR PERFORATON DATA 9-5/8" CSG, 471~, L-80, BTRS, ID = 8.681" 10, .0383 bpf, ID = I x 2-7/8" LNR. ID = 11205' TOP OF 2-7/8" INR, ID = 2.372" 11702' 17' PBTO 149~9' \ MILLOUT WINDOW (C-20A) 8892' - 9028' S-3 PKR, ID = : iES X NIP ID = 10950' ~~ 41 /2" OTIS X NIP, ID = 3.813" 10961' ~ 7" BKR S-3 PKR, iD = 3.875" ~ 10984' 41/2" OTIS X NIP, ID = 3.873" 11005' 41 /7' OT1S XN NIP, MLLED ID = 3.80" 11017' 4112" WLEG 11019' ~ x a-~ n• e~rt zxP ~rcwrs, io = a.ase~ 11027' 7" 9KR FiNC LNR FIGR ID = 4.438° ~ s ;> ~. 11,212' 11260' 4-1/2" BKR KB LTP ID = 2.563" ~ of cmt TOL 12800' 3-3/18 r 2-7/8 X-ov er - -~~ ~~ ~, ~ 3-3/18" X 2-7/8" iiner ~ ~3qpp' ~ 2-7/8" BKR CIBPSET (09f DATE Y CAMMENTS PRUDHOE BAY UNR 07/12l82 OPoGINAL COMPLETION 08~22/OB RDB/SV ADPERF (08/03l08) WELL: G20C 07/12/97 RIG StOETRACK 08/22/09 RPCJPJC GLV GO (08/19/09) PERA~i No: 08H8l00 CTDSIDETRACK 09/18109 MSE PROR~SEDCTDSIDEfRACK ARNo:50-029-20745-03 01l25/OS RWLRLH RWO SEC 19, T17N, R14E, 774' SNL 3 1622' WEL 12/22R)6 008lPAG PFRF CORRECTION (08/13/05) 08/26iD7 SR8/PJC PERFORATIONS BP Exploration (Alaska) STATE OF ALASKA ALl~ OIL AND GAS CONSERVATION COM SION ~ ~, -;.. +-.~ • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ;- Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Su1~e~ .,QII 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5 Permit to Drill Number: Name: Development ~ Exploratory ~ 200-1140 3. Address: P.O. Box 196612 Stratigraphic Service s.. 6. API Number: ~ Anchorage, AK 99519-6612 ~,, 50-029-20745-02-00 7. KB Elevation (ft): 9. Well Name and Number: ~~ 59.95 KB PBU C-20B 8. Property Designation: 10. Field/Pool(s): •'\ADLO-028306 '! PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 15012 feet Plugs (measured) 13400' 9/28/06 true vertical 8883.12 feet Junk (measured) None Effective Depth measured 14949 feet true vertical 8888 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20"x30" 30' - 110' 30' - 110' Surface 2862' 13-3/8" 72# L-80 29' - 2891' 29' - 2660' 5380 2670 Production 8964' 9-5/8" 47# L-80 28' - 8992' 28' - 6257' 6870 4760 Liner 2389' 7" 26# L-80 8832' - 11205' 6143' - 8338' 7240 5410 Liner 1973' 4-1/2" 12.6# L-80 11027' - 13000' 8164' - 8940' 8440 7500 Liner 3310' 2-7/8" 6.16# L-80 11702' - 15012' 8743' - 8883' 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR SURFACE - 10910' 4-1/2" 12.6# L-80 10910' - 11016' Packers and SSSV (type and measured depth) 7" BAKER ZXP PACKER 8840' 4-1/2" BAKER S-3 10823' 4-1/2" BAKER S-3 10961' 4-1/2" BAKER ZXP PACKER 11019' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~, ' •'4 ~'~~~ ~ ~ ~ ~ ~'_, ~~~ . A....~.. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 477 37352 43 1232 Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ' Development ~ Service _..' Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ ~ WINJ ~' WDSPL s`"I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 8/7/2008 Form 10-404 Reviled 04/200`"" 1 ~+~f9'lV ~ 'J C ` ~'~ ~~ Submit Original Only ~`~, ~ 3J ~~10~A~ C-20B 200-1140 PERF ATTACHMENT C7 • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-20B 7/31/97 PER 13,890. 14,060. 8,916.98 8,915.67 C-208 7/31/97 PER 14,240. 14,600. 8,920.84 8,913.63 C-20B 7/31/97 PER 14,720. 14,895.. 8,909.32 8,894.26 C-20B 7/31/00 PER 14,130. 14,180. 8,914.62 8,915.9 C-20B 5/11/03 APF 13,095. 13,120. 8,935.51 8,934.42 C-20B 5/11/03 APF 13,150. 13,175. 8,934.37 8,934.97 C-20B 5/12/03 APF 13,070. 13,095. 8,937.35 8,935.51 C-20B 1/15/05 BPS 10,996. 14,949. 8,133.79 8,888.01 C-20B 2/11/05 BPP 10,996. 14,949. 8,133.79 8,888.01 C-20B 8/30/05 APF 13,660. 13,685. 8,914.31 8,912.11 C-20B 8/30/05 APF 13,714. 13,739. 8,910.98 8,911.22 C-20B 8/30/05 APF 13,774. 13,799. 8,911.93 8,912.43 C-206 8/31/05 APF 13,635. 13,660. 8,916.84 8,914.31 C-20B 9/1/05 APF 12,920. 12,945. 8,936.15 8,937.33 C-20B 9/1/05 APF 12,945. 12,970. 8,937.33 8,938.56 C-20B 9/28/06 BPS 13,400. 14,949. 8,929.68 8,888.01 C-20B 6/25/07 APF 12,840. 12,870. 8,932.87 8,933.97 C-20B 6/26/07 APF 12,560. 12,587. 8,930.99 8,931.48 C-20B 6/26/07 APF 12,710. 12,740. 8,932.56 8,932.72 C-20B 8/2/08 APF 12,560. 12,770. 8,930.99 8,932.6 C-20B 8/2/08 APF 12,810. - 12,890. 8,932.38 8,934.83 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE _ MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~J C-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIViTYDATE SUMMARY 7/30/2008 GTU #9 w/ 1.50" OD CT. Spot unit and begin RU. Job continued on WSR 07/31 /08. 7/31/2008;CTU #9 w/ 1.50" OD CT. Continued from WSR 07/30/08. Bleed IAP from 1000 psi Ito 220 psi in 3 hrs, returns all gas. Begin BOPE test. BOP test complete. AOGCC ,'rep. John Crisp declined to witness. MU weld on connector and BOT MHA. Find ;leaking HCR valve on choke line; service valve to no avail. Call out replacement `valve and begin valve c/o. Job continued on WSR 07/31/08. 8/1/200&CTU #9 w/ 1.50" OD CT. Continued from WSR 07/31/08. Replace and PT leaking :HCR valve on choke line. MU and RIH with BOT MHA and PDS pressure/GR/CCL ;memory logging tools. Begin logging correlation pass. Log from 13411' ctmd to ;:12520' ctmd at 30 fpm. Paint white flag. Continue logging at 30 fpm to top of ;.interval at 10700' ctmd. RIH to lay in FloPro across perf interval. Kill well with 240 bbls 1 %KCL and cap with 110 bbls diesel. Lay in 43 bbls FloPro across perf 'interval; PU to max weight to POOH. Re-paint flag at 12513'. PUH to 11552' ctmd Nand perform no-flow test. No flow or losses in 30 minutes. Continue POOH '', replacing coil voidage with diesel. OOH. Conduct no-flo test at surface. PJSM !,with TCP crew, coil crew and CH2MHILL operator. Discuss hand placement, ('overhead loads, good communication and well control procedures. Decide to RBIH' ''with nozzle to displace the sail section of the chrome tubing to safelube to allow ', '!more weight transfer to bottom prior to making gun run. Job continued on WSR ', 08/02/08. ... 8/2/2008 CTU #9 w/ 1.50" OD CT. Continued from WSR 08/01/08. MU and RIH with 2.26" !' OD JSN to circulate safelube into the sail section of the tubing. Lay-in 1 % XS KCL '" w/ 0.6% safelube from 9500' to 2100' ctmd. Lay-in diesel from 2100' ctmd to ', :surface. Perform no-flow test; observed no flow for 30 minutes with ahole fill)-up volume of 0.4 bbls. PJSM in preparation for running guns. Deploy 2.0 "perforating', ;;gun bha open hole. RIH with BTT MHA and SLB 2.0" perf guns. Correct to top ', -shot at coil flag. RIH past shooting depth to 12587. PUH and perforate 12560' to :12770' and 12810' to 12890' with 2.0" 6SPF 2006 PJ Omega perf guns. POOH ! replacing coil voidage with diesel. OOH. Conduct no flow test to 40 bbl gauge iptank. No flow observed at tank, hole fill up volume 0.2 bbls. All guns recovered, all ('shots fired. RIH with 1.75"OD JSN for clean out run. Job continued on WSR '; !' 08/03/08. '' • 8/3/2008 CTU #9 w/ 1 50" OD CT. Continued from WSR 08/02/08. RIH with JSN for flo-pro clean out run. Clean out flo-pro down to liner top with 1 for 1 returns at surface. Continue in hole to 13350' to displace flo-pro from liner. Returns dropped to 80% while in liner. Chased flo-pro to surface at 80%. Pump 98 bbls diesel down tubing. Cap with 10 bbls 50/50 methanol. Secure well and rig back injector. Notify operator of well status. RDMO. ***Job Complete**" __._ FLUIDS PUMPED BBLS 162 1 % XS KCL W/SAFELUBE 66 DIESEL 10 FLOPRO 238 TOTAL V V~~~ ~~~ ~~ _. ~~ T/4~4S~1/1 °7~4L tom.. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Bled. Anchorage, Alaska 99508 and ~~~~~ AUC ~~ ~ 2008 aoo_,~y ProActive Diagnostic_ Services, Inc. Attn: Robert A. Richey l(o~oa 130 West International Airport Road 1(0~~3 Suite C Anchorage, AK 99518 Fax: (907] 245-8952 1) Coil Flag /Jewelry Log 01 Aug-08 C-20B EDE 50-029-2074502 2) Signed : pate Print Name: n.lnfiS'~iu~ /1 ,~ti,,,o,~!{~.~.. PROACTIVE DIAGNOSTIC SERVICES, MC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL C.'~,fS'1~,,..1: ~3 ~~..~e~ ~?~^. J. ;~~~.~~§'~ WEBSITE n~u;1r.3'. ~~ C~ 1'u:'> > ,"?iii C:\Documenffi and Settings\Ownet\Desktop\Tmnsmit_BP.doc .. . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS R12CI2/1./I2D JUL 0 2; S (a n:1 lfìn- 1 . Operations Abandon D Repair Well D Plug Perforations D Stimulate D Other D ., 0{ ó'a.~ t(J Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D 411Ch liS, Corn Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Well D ¡Grage 7( 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory r 200-1140 . 3. Address: P.O. Box 196612 Stratigraphic r Service r 6. API Number: Anchorage, AK 99519-6612 50-029-20745-02-00 - 7. KB Elevation (ft): 9. Well Name and Number: 59.95 KB ' PBU C-20B 8. Property Designation: 10. Field/Pool(s): ADLO-028306 / PRUDHOE BAY Field/ PRUDHOE OIL Pool - 11. Present Well Condition Summary: Total Depth measured 15012 , feet Plugs (measured) None true vertical 8883.12 . feet Junk (measured) None Effective Depth measured 14949 feet SCANNED JUL ø 5 2007 true vertical 8888 feet , Casing Length Size MD TVD Burst Collapse Conductor 80' 20" x 30" 30' - 110' 30' - 110' Surface 2862' 13-3/8" 72# L -80 29' - 2891' 29' - 2660' 5380 2670 Production 8964' 9-5/8" 47# L-80 28' - 8992' 28' - 6257' 6870 4760 Liner 2389' 7" 26# L -80 8816' - 11205' 6143' - 8338' 7240 5410 Liner 1973' 4-1/2" 12.6# 11 027' - 13000' 8164' - 8940' 8440 7500 Liner 3310' 2-7/8" 6.16# L-80 11702' - 15012' 8743' - 8883' 10570 11160 Perforation depth: Measured depth: 12635' - 14895' - - - - True Vertical depth: 8932' - 8894' - - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 20' - 11017' Packers and SSSV (type and measured depth) 7" Baker ZXP Packer 8840' 4-1/2" Baker S-3 10823' 4-1/2" Baker S-3 10961 ' 4-1/2" Baker ZXP Packer 11019' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFL JUL 0 3 2007 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 28 1689 0 0 2242 Subsequent to operation: SHUT-IN 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and SUNeys Run Exploratory r Developm ent ~ Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas r WAG r GINJ r WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Gary Preble Printed Name Gary Preble/ /Î A/? Title Data Management Engineer Yk ,¿//// Signature Y f Phone 564-4944 Date 6/28/2007 .,-'~j----""-~ ' Form 1 0-404 Revi¿;;d 04/2006 Subm' ri inal Onl 418 :/( ~SSi()r. ORIGINAL ;;F~~ . . . ,> C-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/25/2007 CTU #8, Adperf; MIRU CTU #8. MU memory GR/CCL in carrier with 2.3" nozzle on bottom. Load well with 165 bbls 1 % KCL wi 0.6 % SafeLube while RIH. Log from 13100' to 12000' flagging at 12800' and 12500'. POOH. MU and RIH with Gun #1 (30' of 2.0" SLB - PJ2006 HMX gun loaded 6 spf). Correct depth and perforate interval 12840' to 12870' (ref; MCNL - 8/29/05). POOH. Cont' on WSR 6/26/2007 CTU #8, AdPerf; Cont' from WSR 6/25/07... POOH with Gun #1. MU and RIH Gun #2 (30' of 2.0" SLB - PJ2006 HMX gun loaded 6 spf). Correct depth and perforate interval 12710' to 12740' (ref; MCNL - 8/29/05). POOH. MU GR/CCL in carrier wi 2.3" Nozzle. RIH and log from 13100' to 12000' and flagged at 12500'. POOH. Depth correction (-14). MU and RIH with Gun #3 (27' of 2.0" SLB - PJ2006 HMX gun loaded 6 spf). Correct depth and perforate interval 12560' to 12587' (ref; MCNL - 8/29/05). POOH. Cont' on WSR 6/27/07 ... 6/27/2007 CTU #8, AdPerf; Cont' from WSR 6/26/07... POOH with Gun #3. FP well to 2000' with 50/50 methanol. RD CTU #8. Notified Pad Operator and PCC that well is ready to put on production. *** Job Complete *** FLUIDS PUMPED BBLS I 3050/50 METHANOL 30 TOTAL ~:: {~ - . - , ~ ~ t:" J ~j f~ lJ Schlumberger it:EB' ' ' ,,-tþ~I5ÅL ~ !-. (..,'- ~~ NO. 3677 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 02/09/06 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 A~~~~;~ ...;<J¡ ¡:: r ;!~'3JQ¡ , Field: Prudhoe 8ay Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TIN: Beth Received by 6~ð ) Well Job# Log Description Date 8L Color 13-31 A .,:)05- ¡IDO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-038 ~OS ~Of:.G 11057071 S8HP SURVEY 12102/05 1 NK-43 ¿)ð/-CO 10987562 S8HP W/SPINNER PASSES 01/07/06 1 8-13A /C¡<1 - CoS7 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A Iq~3-~C57 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 Iß(c'~ /34- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 /9tt··¡51- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 lfò.7-C(cC¡' 11058541 RST 11/11/05 1 Z-29 ¡M -C~("Ç 11051081 RST 08/10/05 1 L5-09 J V¡C -/.y~ 11090725 RST 11/11/05 1 15-44 ,qú - / f () 11194155 RST 01/15/06 1 C-208 ';¿O()- I 14- 11075913 MCNL 08/29/05 1 02-14A Q03 ~ 1~5 11075901 MCNL 07/29/05 1 Z-21A -901- jO r 11076449 RST 06/30/05 1 F-27 A c205-la4- 10928641 MCNL 09/01/05 1 MPH-15 .!)c'5 -- /5'1 11076486 USIT 12/15/05 13-31 A -::)cS-llL'ö 11133211 SCMT 12/23/05 WGI-04 17Cf-cSD 11183461 US IT 01/26/06 WGI-04 /'7Cf -cost> 11211566 USIT 02/03/06 WGI-08 140"- 044 10987559 USIT 01/02/06 WGI-08 ¡l10 ~- c4Q 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ;~ç/è~NEC FEB 2820Gb Date Delivered: .?/} ~-;;? { 00 I CD - 1 1 1 1 1 1 1 - · STATE OF ALASKA ì RECEIVED AlA"- .1 Oil AND GAS CONSERVATION COMMlvSION P 2 2005 REPORT OF SUNDRY WELL OPERATIONS SE· 6 . . Stimulate D A'asQ~f.m ~üas CO,'S- COmmtSS\On Waiver D Time Extension DAne""a,' Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory C 200-1140 Service r: 6. API Number: 50-029-20745-02-00 9. Well Name and Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 59.95 KB 8. Property Designation: ADL-028306 11. Present Well Condition Summary: Total Depth measured 15012 true vertical 8883.12 Effective Depth measured 14949 true vertical 8888.01 Casing Conductor Surface Production Liner Liner Liner Length 80 2862 8964 2389 1973 3310 Size 20" x 30" 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# L-80 2-7/8" 6.16# L-80 Perforation depth: Measured depth: 12635 - 12685 13774 - 13799 True Vertical depth: 8931.75 - 8932.21 8911.93 - 8912.43 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o 653 x Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Class: Development [;?'! Stratigraphic Ci feet feet C-20B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) None None feet feet SCANNED I!~O\# 0 9 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 27178 9 300 15. Well Class after Droposed work: Exploratoryl Development P' 16. Well Status after proposed work: Oil P' Gas r WAG r MD 30 - 110 29 - 2891 28 - 8992 8816 - 11205 11027 - 13000 11702 - 15012 12920 - 12970 13890 - 14060 8936.15 - 8938.56 8916.98 - 8915.67 4-1/2" 12.6# 7" Baker ZXP Packer 4-1/2" Baker S-3 Packer 4-1/2" Baker S-3 Packer 4-1/2" Baker ZXP Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal .. _ í . Signat~/~ Form 10-404 Revised 04/2004 TVD 30 - 110 29 - 2660.21 28 - 6256.95 6142.93 - 8338.01 8164.02 - 8940.11 8743.15 - 8883.12 Burst Collapse 5380 6870 7240 8440 10570 2670 4760 5410 7500 11160 13070 - 13120 14130 - 14180 8937.35 - 8934.42 8914.62 - 8915.9 13150 - 13175 14240 - 14600 8934.37 - 8934.97 8920.84 - 8913.63 13714 - 13739 14720 - 14895 8910.98 - 8911.22 8909.32 - 8894.26 L-80 20-11017 8840 10823 10961 11019 RBDMS BFl SEP 2 8 2005 Tubing pressure o 1180 Service r GINJ l r WINJ r WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 9/23/2005 ) ¡ L. Submit Original Only ) ) C-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/31/2005 Continued from 8/30105 WSR: Memory log and perforate POOH wI gun run #3. All shots fired. Recovered ball. Cut 100' off coil tubing. MU new Weatherford MHA wI PDS Memory logging tools in a 2.2" carrier wI bull nose nozzle. RIH. Tag at 10,974'. Unable to pass obstruction. POOH. Remove 2.2" carrier. MU MHA with 1.688" memory logging tools. RIH. Log from 13,950' to 12,750'. Paint flags at 13,600' and 13,000'. POOH. LD PDS Memory logging tool. MU 25' x 2" guns RIH wI run #4 Perforate interval 13,635 to 13,660... All indications guns fired. Job in progress....... Continued on 9/01/05 WSR 9/1/2005 ***** Job continued from 8/31/05 WSR:***** POOH wI gun run #4. All shots fired. Recovered 1/2" ball. PU 25' x 2" guns. RIH wI perforating gun #5. Shoot 12,945' to 12,970'. POOH. All shots fired. Recovered 1/2" ball. PU 25' x 2" guns. RIH wI perforating gun #6. Shoot 12,920' to 12,945'. POOH. Freeze protect well to 2500'. LD perf run #6. All shots fired. Recovered 1/2" ball. RD SLB TCP. Test BOP equipment.. Passed. Cut - 250' of Pipe. RDMO. Turn well over to pad operator to POP. *****Job Complete***** FLUIDS PUMPED BBLS 205 20/0 KCL 105 50/50 MeOH 60 Lubetex 370 TOTAL F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ALASKA \-1 AND ~::;~g~S~~;~ON CO~JISSION REPORT OF SUNDRY WELL OPERATIONS fEB 14 2005 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 59.95' 8. Property Designation: ADL 028306 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): B Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 15012 8883 14949 8888 110' 2891' 8990' 2373' 1987' 3318' 0 Other 0 Time Extension 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 200-114 6. API Number: 50-029-20745-02-00 9. Well Name and Number: PBU C-20B 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst 20" x 30" 110' 110' 13-3/8" 2891' 2660' 5380 9-5/8" 8990' 6256' 6870 7" 8832' - 11205' 6153' - 8338' 8160 4-1/2" 11013' -13000' 8150' - 8940' 8430 2-7/8" 11694' -15012' 8738',- ~8~3' 5 13450 SCANNE.D FEB 1 J 200, Collapse 2670 4760 7020 7500 13890 13070' - 14895' 8937' - 88941 4-1/2", 12.6# 13Cr80 11017' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" Baker 'S-3 packer; 7" Baker 'S-3' packer; 4-1/2" HES IX' Nipple 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10961' & 10823'; 1993' SCA.NNED FES 1 5 2005 R8DMS 8Ft rr=D'r 7005 RBDMS BFl FtfJ 1 4 2DD5 Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Miller, 564-4746 NIA Printed Name Terrie Hubble Signature ~~ &..~ Form 10-404 Revised 04/2004 Title Technical Assistant ÓhRe I G ìÑÃt Date o;>.f (Lf I Q5 Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ) ) BP (¡)lpè:r~~i~g$§Çlrt"lrn~r~fflêpør~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-20 C-20B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2005 Rig Release: 1/25/2005 Rig Number: Spud Date: 8/8/2000 End: 1/25/2005 Ðâte Frorn~ To Hôurs Tâsk 'Code NPT Phase OØ$Þriptiôrl.öf QÞer~tions 1/19/2005 06:00 - 11 :30 5.50 MOB P PRE Rig move from A-20 to C-20B. 11 :30 - 15:00 3.50 RIGU P PRE Rig up on C-20B. Accept rig @ 1500 hrs. 15:00 - 17:00 2.00 RIGU P PRE R/U and test hard line to Tiger Tank. R/U HCR valve to IA. Install pressure gage on OA. OA has 0 psi. R/U lines for well kill ops; blow air thru all lines. Take on hot seawater to pits. 17:00 - 20:30 3.50 RIGU P PRE Wait on Valve Crew (DS Maint) to pull BPV. 20:30 - 21 :00 0.50 WHSUR P DECOMP P/U lubricator, pull BPV. 21 :00 - 22:00 1.00 KILL P DECOMP H/U, check and test all lines prior to bleed down. Check TT line wI air. Hold PJSM to discuss well bleed down and well-kill fluid circulation. 22:00 - 00:00 2.00 KILL P DECOMP Open well, TP 20 psi, CP 60 psi, OA 0 psi. Bleed down well--fluid levels near surface. Start well kill circulation wI hot seawater at 1 BPM, 30 psi; work up to 3-1/2 BPM, TP 40 psi, CP 210 psi. 1/20/2005 00:00 - 03:00 3.00 KILL P DECOMP Continue well-kill circulation. OA pressure climbed from 0 to 500 psi during circulation--quickly bled to 0 psi into Bleed-down Trailer. Well started to clean up after full wellbore volume of 670 Bbls pumped. Sent 580 Bbls of crude oil and diesel to GC-2 Dirty Water Tank to reclaim crude oil. 03:00 - 04:30 1.50 KILL P DECOMP Stop pumping and well went on vacuum, then a short time later, began a light blow of gas from both tubing and annulus. Would not stop blowing, so SI well, and tubing pressure built to 90 psi. Ordered 2 loads of hot seawater to resume well-kill circulation. Suspect that the crude oil and diesel freeze protect fluid was strung up the wellbore. Waiting on seawater will allow the fluids to rebalance. 04:30 - 06:00 1.50 KILL P DECOMP Wait on hot seawater to resume well-kill cleanout circulation. 06:00 - 06:30 0.50 KILL P DECOMP Service rig. 06:30 - 09:30 3.00 KILL P DECOMP Take on additional Hot Sea Water. Pump down Tubing at 6.0 bpm/750 psi. Continue to circulate until returns were clean. Monitor Well...dead. 09:30 - 10:00 0.50 WHSUR P DECOMP Install and test TWC. 10:00 - 12:00 2.00 WHSUR P DECOMP Cameron perform Pre-RWO "Check List" on Wellhead. Checks both sets of Lock-Down Screws. Test both sets of Pack-Ofts. 12:00 - 14:30 2.50 WHSUR P DECOMP Nipple down Production and Adaptor Flange. Inspect Hanger threads...rough and pitted. Order out 4-1/2" Double Spear. 14:30 - 16:30 2.00 BOPSUP P DECOMP N/U test spool and BOP stack. 16:30 - 21 :00 4.50 BOPSUP P DECOMP RlU lines and test BOPE per AOGCC and BP requirements, 250 psi low and 3500 psi high. 21 :00 - 21 :30 0.50 BOPSUP P DECOMP P/U lubricator and pull TWC, UD same. 21 :30 - 22:30 1.00 PULL P DECOMP M/U landing joint and Baker 4-1/2" Double Spear, RI and engage 4-1/2" tubing below hanger. BOLDS. P/U on landing joint and hanger pulled free @ 125K. Break-out and UD landing joint and Baker Spear. 22:30 - 00:00 1.50 PULL P DECOMP RlU Camco control line Spooling Unit. Clear and clean Rig Floor. Change out Elevators. Break circulation and fill hole wI 33 Bbls of hot seawater from Pits. Gas and water vapor breaking out in BOP Stack while circulating. SID pump, fluid level slowly fell downhole and gas and water vapor stopped. Well dead. 1/21/2005 00:00 - 03:00 3.00 PULL P DECOMP Continue POOH and UD 4-1/2" tubing. 03:00 - 03:30 0.50 PULL P DECOMP RID Camco Spooler. Recovered 32 of 57 SS bands and all of Printed: 1/31/2005 8:00:54 AM ') ) BP (¡)p~.r~t~,..ø~~..,.$~~~~.ry....'.,I=t~pørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-20 C-20B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2005 Rig Release: 1/25/2005 Rig Number: Spud Date: 8/8/2000 End: 1/25/2005 Date From - To Hours Task Code NPT Phase Description of Operations 1/21/2005 03:00 - 03:30 0.50 PULL P DECOMP the SS control lines. 03:30 - 10:00 6.50 PULL P DECOMP Continue POOH and UD 4-1/2" tubing. Recovered 259 Jts,SSSV, 3 ea GLM, and a 18.37' Chemical Cut Stub. Clean cut...normal O.D./I.D. 10:00 - 12:00 2.00 PULL P DECOMP Rig down 41/2" handling equipment. Install Wear Bushing. Clear and clean floor. 12:00 - 15:30 3.50 FISH P DECOMP Spot SWS unit, R/U sheave and W/L. M/U WIL Jars, Junk Basket and 8.5" Gage Ring. 15:30 - 18:00 2.50 FISH P DECOMP RIH wI W/L. Find several tight spots, but work thru them wIno difficulty to tag top of 7" liner @ 8,838' WLM. 18:00 - 21 :30 3.50 FISH P DECOMP POOH. Clean out Junk Basket and recover 10 of the missing 25 SS bands. Also recover a 3" square chunk of rubber and 1 quart of scale and sludge. 21 :30 - 22:30 1.00 FISH P DECOMP RIH wI same Junk Basket and 8.5" Gage Ring. Tag fluid @ -400'. See one tight spot @ -3,200'. 22:30 - 00:00 1.50 FISH P DECOMP POOH, clean Junk Basket, recover 5 more SS bands. Total recovered, 15 of 25 missing bands. 1/22/2005 00:00 - 01 :00 1.00 FISH P DECOMP RIH wI same Jars, Junk Basket, and 8.5" Gage Ring. Tag fluid @ -400'. Don't see any restrictions while RIH. 01 :00 - 02:30 1.50 FISH P DECOMP POH and clean-out Junk Basket. Recover 3 SS bands. Total 18 of 25 bands. Fill hole to top of BOP Stack wI 33 Bbls seawater. 02:30 - 03:30 1.00 FISH P DECOMP RIH wI same Jars, Junk Basket, and 8.5" Gage Ring. 03:30 - 04:30 1.00 FISH P DECOMP POH and clean-out Junk Basket. No additional SS bands recovered; total recovery, 18 of 25 lost SS bands. Change Gage Ring to 6.055". Fluid level at bottom of BOP Stack. 04:30 - 05:30 1.00 FISH P DECOMP RIH wI same Jars, Junk Basket, and 6.055" Gage Ring to enter 7" Liner and cleanout to 4.5"Stump @ 10,910'. Couldn't enter TOL @ 8,838' after repeated attempts. 05:30 - 07:00 1.50 FISH P DECOMP POH to check basket. No Band recovery. 07:00 - 09:00 2.00 FISH P DECOMP Change Gage Ring on Junk Basket to a 5.750". SWS Crew change-out. RIH to 8,842'. Attempted several times to enter top of 7" Liner. No joy. 09:00 - 12:00 3.00 FISH P DECOMP Make-up 6" Brush w/5.750" Tapered Swedge. RIH to top of 7" Liner. Enter Liner Top continue pushing remaining Bands down to top of 41/2" Tubing stump at 10,914' slm. 12:00 - 14:00 2.00 FISH P DECOMP POOH. Recovered 2 Bands "tangled" in Brush. 14:00 - 15:00 1.00 FISH P DECOMP Lay down tools. Rig down S-Line Unit. Total Bands recovered = 20. 5 Bands remain in hole, probably behind 41/2" Tubing Stump. 15:00 - 16:30 1.50 FISH P DECOMP Make-up BHA #1 as follows: Shoe, WP Ext, WP Ext, Boot Basket, Double Pin Sub, Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, 6 ea Drill Collars. 16:30 - 23:00 6.50 CLEAN P DECOMP TIH wI BHA #10n 3-1/2" DP from Pipe Shed. Tag TOL @ 8,832' DPM, 15' in on jt #272. 23:00 - 00:00 1.00 CLEAN P DECOMP Continue TIH wI BHA #1 on DP from Pipe Shed. 1/23/2005 00:00 - 00:30 0.50 CLEAN P DECOMP Continue TIH wI BHA #1 on DP from Pipe Shed. 00:30 - 01 :30 1.00 CLEAN P DECOMP P/U Kelly and M/U to TIW valve. P/U 150K, S/O 105K. Tag Stump @ 10,917' DPM. Pump 3 BPM @ 500#. Slowly rotate and swallow to 10,931', pressure builds another 50 psi. P/U to 10,917' and repeat swallow and P/U another 4 times to verify wi 14' swallow each time. 01 :30 - 04:00 2.50 CLEAN P DECOMP Circulate Hi-Vis sweep throughout well bore, 650 Bbls, 4 BPM Printed: 1/31/2005 8:00:54 AM ) ) BP (¡)p~~atipns...$ljrnrn~~y....ffl~ppr~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-20 C-20B WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/19/2005 Rig Release: 1/25/2005 Rig Number: Spud Date: 8/8/2000 End: 1/25/2005 Date From - To Hours Task Code NPT Phase Description of Operations 1/23/2005 01 :30 - 04:00 2.50 CLEAN P DECOMP @ 825 psi. 04:00 - 08:00 4.00 CLEAN P DECOMP TOH with 31/2" Drill Pipe and SIB DP in Derrick. 08:00 - 09:00 1.00 CLEAN P DECOMP Lay down BHA #2 09:00 - 10:00 1.00 FISH P DECOMP Pick-up BHA #3 as follows: 3.700" Mill, Bit Sub,S ea 2 7/8" Drill Collars, XO Sub, Bumper Jar, Oil Jar. 10:00 - 13:00 3.00 FISH P DECOMP TIH with 3 1/2" Drill Pipe from Derrick. (336 jts): 13:00 - 13:30 0.50 FISH P DECOMP Pick up 5 singles from Pipe shed. Pick up Kelly. 13:30 - 17:30 4.00 FISH P DECOMP PUW = 150K. SOW = 100K. RW = 120K. PR = 2 bpm/450 psi. Tag top of Fasdrill Plug at 10,996'. start milling on top of Plug. WOB = 2 - 4K. Finished drilling plug and continued past end of tailpipe @ 11,017' to TD of 11,043'. 17:30 - 00:00 6.50 FISH P DECOMP TOH UD DP. 1/24/2005 00:00 - 01 :00 1.00 FISH P DECOMP TOH UD Drill Pipe. 01 :00 - 02:00 1.00 FISH P DECOMP UD Drill Collars and BHA #3. 02:00 - 04:00 2.00 RUNCOMP RUNCMP Clear and clean Rig Floor. R/U 4-1/2" handling equipment. RIU Torque Turn Equipment. 04:00 - 04:30 0.50 RUNCOMP RUNCMP Pre-Job Safety Meeting with all Nabors personnel, Nabors Casing Service, Baker Packers, Tour Pusher and Co-Man. 04:30 - 18:30 14.00 RUNCOMP RUNCMP RIH new 4-1/2",13 Cr 80, Vam-Top Completion. M/U two connections below packer wI Baker-Lok. Torque all Vam-Top connections to 4,440 ft-Ibs. Drift all Tubing Joints. 18:30 - 20:30 2.00 RUNCOMP RUNCMP P/U jt #257, P/U wt 120K, S/O wt 80K. Slowly work down over stump, see wt drop off to -72K, then swallow 8.5'. P/U to -120K to get space-out length. POOH joints #257, #256, and #255. P/U 3-pups: 3.63', 9.86', and 19.07' and RIH under jt #255. P/U Tubing Hanger Landing Joint and M/U to jt #255 and land tubing hanger. Final landing depth 10,910' 4ES RKB. 20:30 - 21 :30 1.00 RUNCOMP RUNCMP UD Landing Joint. RILDS. Set TWC. RID Torque Turn and 4-1/2" handling equipment. 21 :30 - 23:30 2.00 BOPSUP P RUNCMP Nipple down BOPE. 23:30 - 00:00 0.50 WHSUR P RUNCMP Begin to N/U Adaptor Flange and Tree. 1/25/2005 00:00 - 02:30 2.50 WHSUR P RUNCMP N/U and test Tubing Hanger, Adaptor Flange, and Tree to 5000 psi. 02:30 - 03:00 0.50 WHSUR P RUNCMP P/U Lubricator and pull TWC. 03:00 - 09:00 6.00 RUNCOMP RUNCMP R/U to take on 120F seawater to Pits. Reverse Circulate at 3 BPM @ 250 psi, 300 Bbls 120F seawater, followed by 600 Bbls 120F seawater mixed with 3-Bbls Corrosion Inhibitor. Blow down lines. 09:00 - 11 :00 2.00 RUNCOI\rP RUNCMP Drop Packer setting Ball/Rod. Wait 30 min. for Ball/Rod to go on seat. Bring Pump on line and build pressure. Set Packer and test Tubing at 3,500 psi/30 mins. Bleed tubing pressure down to 1 ,500 psi. Pressure up on Annulus to 3,500 psi/30 mins. Bleed Tubing pressure down and observed DCR Shear Valve shear at -900 psi. Test recorded on a Chart. Pump both directions to confirm SV open. 11 :00 - 14:00 3.00 RUNCOMP RUNCMP Rig up Lil' Red and pump 145 bbls of Diesel down Annulus...taking returns up tubing. U-Tube diesel. Suck out Tree. Rig down Lit' Red. 14:00 - 16:00 2.00 WHSUR P RUNCMP Set and Test BPV. Blow down lines. Secure Cellar. Release Rig at 16:00 hrs. Printed: 1/31/2005 8:00:54 AM ) J.f'EE :::: .'.. 6-1/8" CW WB-LHEAD = McEVOY 'ÃCiúÁrOR;-- 'ÄXELSON 'KB~ ELEV';;' " ," ,,' "60.0' i3F.ELËV;---~--~ 34.3";' KOP = " 100iY 'Max-Ãògle ~." 97 @'''14923; batum'Mb~ "11936' Datum Ño'= 88ÒO' SS I 13ø3/8" CSG, 72#. L-80. ID = 12.347" 1-1 2891' ~ Minimum ID = 2.372" @ 11702' TOP OF 2.7/8" LINER I TOP OF TIEBA CK 1-1 9-5/8" x 7" BKR ZXP PKRI -I TIEBACK, ID = 6.313" I 7" BKR HMC LNR HGR, 10 = 6.250" l-i ) C-20B FROM DRLG - DRAFT 1992' 1-1 4-1/2" HES "X" NIP, 10 = 3.813" I ~ L GAS LIFT MANORB-S ST MD TYÆ VLV LATCH 3 468 4.5" x 1.5" OCR RK 2 8317 4.5" x 1.5" OMY RK 1 10733 4.5" x 1" OMY BK 8832" 1 I 8840" ~ 8846' ~ ~ ~ 10802" 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 /'./1 10823" 1-1 7" BKR S-3 PKR, 10 = 3.875" V~ 10888' IJ 4-1/2" HES X NIP, Ð = 3.813" I V' /1 10910" IJ UNIQUE MACHINE OVERSHOT 1 - r../ 10950" - 4-1/2" OTIS X NIP, 10 = 3.813" I ~ 10961" , 7" BKR S-3 PKR, 10 = 3.875" 1 11",~~:~~"u'?~~'~~~~:":'~~'?'~'~!~~'ml~,:,~,:~~,~.::J-iTmu~'~17-{o",~.,I',m, Þ' /,' ~~~:: ~ :~~~~:: ~~:~ ~:~~.IO = 3.813" 1 4-1/2" TBG, 12.6#. 13Cr-80. ID = 3.958" ,--,-~o /" MILLED ID = 3.80" I 4~1/2" TBG, 12.6#, L-80. .0152 bpf. ID = 3.958" l-f 11016" I' 11017" 1- 4-1/2" WLEG 1 I 7"X4ø1/2"BKRZXPPKR/TIEBACK,ID=4.438" 1-1 11019' 1 ~ ~ NOTE: 4-1/2" WLEG IS NOT INTO TOP OF I 7" BKRHMCLNRHGR, 10=4.438" 1-1 11027" 1 ~ r LNRTIE-BACKSLV. SQUARE SHOULDERED TOOLS WILL HANG UP ON , 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 11205' ~ It.. WLEG. ~ ALSO POSSIBLE DEBRIS FROM DRLG & 1 3-3/4"BKRDEPL.OYMENTSLV,10=3.00" 1-1 11694" 1 ~ FASDRlLLPLUG I TOP OF 2-7/8" LNR, 10 = 2.372" 1-1 11702' I 4-1/2" LNR, 12,6#, L-80, .0152 bpf, 10 = 3.958" 1-1 13000' I I PBTD 1-1 14949" 1 ÆRFORA TION SUMMARY REF LOG: SPERRY GRlROP ON 08/00 ANGLE AT TOP PERF: 89 @ 12560' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE . 2-3/4" 4 12560 - 12770 S 08/14/00 2-3/4" 4 12810 - 12890 S 08/14/00 2" 6 13070 - 13120 0 05/12/03 2" 6 13150-13175 0 05/11/03 2" 4 13890 - 14060 0 08/16/00 2" 4 14130 - 14180 0 08/16/00 2" 4 14240 - 14600 0 08/16/00 2" 4 14720 - 14895 0 08/16/00 DATE 07/12/82 07/12/97 08/16/00 01/26/05 02/08/05 REV BY COMl\t1ENTS ORIGINAL COM PLETION RIG SIDETRACK CTD SIDETRACK RWO /TLH ORLG HANDWRITTEN DEPTHS ~ I ""'" _8" !""""" --. r &  I ... I ~ .& r 920" ----------- 2-7/8" LNR, 6.16#, L-BO, .00579 bpf, 10 = 2.372" Ii. 15012" DA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: C-20B ÆRMfT No: 2001140 API No: 50-029-20745-02 SEC 19, T11N, R14E, 774' SNL & 1522' WB- BP Exploration (Alaska) WELL LOG TFIANSM/TTAL ProActive Diagnostic Services, Inc. To: RE' State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FiLM COLOR Open Hole I I I 'Res. Eval. CH I ,~ "~'/1 1 ,\ C-20B 5-11-03 Mech. CH 1 Caliper Survey Signed · Print Name: Phone:(907) 245-8951 Fax:(907) 245-8952 Date · Permit to Drill 2001140 DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. PRUDHOE BAY UNIT C-20B Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20745-02-00 MD 15012 'I-VD 8883 Completion Dat 8/15/2000 ~ Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_9o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH / Type Media ~.rnt Name Scale Media No Start Stop CH 'ED- .... b-~ -~-(~r---I-"lS Verification 1 (data taken from Logs Portion of Master Well Data Maint) Dataset Received Number Comments 12898 14984 Open 5/9/2002 10801 ED D~"'"""~"Cn See Notes 1 12898 15012 Open 6/5/2002 10839 ~gital Log Images Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / (~ Chips Received? ---Y-~N---- Analysis -Y:/~I--- RP. cP. ivP. d? Daily History Received? ~.~/N Formation Tops (~y N Comments: Compliance Reviewed By: ............... _ ./,~.~--~_.~_. ............................................. Date: ..... To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. _Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 04, 2002 Formation Evaluation Logs · C-20B, AK-MW-00124 C-20B: Distal Log Images 50-029-20745-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNLNG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED WELL LOG TRANSMITTAL To: State of Alaska April 29, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs C-20B, AK-MW-00124 1 LDWG formatted Disc with verification listing. API#: 50-029-20745-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. ,~achorage, Alaska 99508 Date: RECEIVED A!.~ska Oil & ~s Cons° Comm~on MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie r~eusser,~ Commissioner Tom Maunder, P. I. Supervisor DATE: April 23, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit C Pad ,.Monday, April 23, 2001- I traveled to BPXs C Pad and witnessed a portion of the 30-day retest of the safety valve systems. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with 1 failure. The Surface ,Safety Valve on well C-20B failed to pressure test. This valve is a repeat failure from the previous test. An attempt was made at this time to service the valve but the subsequent retest~aiso failed. This well was shut in Until repairs could be completed. I departed location prior to completion of the testing on this Pad due to a required BOP test on Nabors Rig 9ES. I spoke with Merv Liddelow on the morning of 4-24-01 and he indicated there were no further failures on remainder of the wells tested. Merv Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. su. mmary: I witnessed a potion of 30-day SVS testing at BPXs C-Pad. PBU C Pad, 11 wells, 22 components, 1 failure 4,$$% failure rate on the witnessed portion of the pad. Attac. hment;. SVS PBU C Pad 4-23-01 CS X Unclassified Confidential (Unclassified if doc. removed ) SVS PBU C Pad 4-23-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/UniffPad: Prudhoe / PBU / C Pad Separator psi: LPS 174 Date: 4/23/01 HPS 644 We~ Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or C¥CL~ C-01 1720300 C202 1730040 ........ C-03A 1981840 644! 550 500 P P ' ' OIL C-0~X 1960920 C-0~' 1730110 174 125 100 'P" 'P OIL C-06A 1981570 C-07A 2000520 644 550 520 " P P " OIL C-08A 1950280 '174 125 120 P e ' OILi C.0~ ' 1790260 ..... C-10 1790'550 .... C-11 1790460 ' '' C-12A 1981160 C-13A 1971430 . C-15 1791090 C-16 1800100 C-17A "'1980236 ~ . , , , C-18A 1991290 d-19B 2000050 644 550 525 e e " ' 0iL ~-20B 2001140 174 125 110 "' e 4 '" OIL ~-21 1820810 174 125 115 P P OIL , C-22 1820880 644 550 550 P P OIL , ,, C-23A 1961190: ~-24 1821410 644 550 525 ~ e oIL C-25A 1950110! 644 " 550 475' p p '1 OIL iC-26A 198i450 ........ C-27A 1961390 ,, , , ,, , C-28 1821950 C-29A 1961700 ' , ,, , , C-30 1871360 C-31A 1950060 C-33 1930~70 ...... , , C-34 1880150 I , , RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 4-23-01 CS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or C¥CLF~ C-35A 1952000 C-36A 2000020 '1 C-37 1930550 , . C-38 1860660 C-39 1930940 644 550 500 'i) P OIL C-41 1930990 , , C-42 1930500 , , Wells: 11 Components: 22 Failures: 1 Failure Rate: 4.55% ['-I 9o oar Remarks: Surface Safe. ty Valve on Well C-20B failed when pressure tested. Retest after valve serviced also failed, well was shut in pending repairs. This is a p ,artial pad test. RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 4-23-01 CS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, 3~"- i0\ Commissioner ~\\~ Tom Maunder, ~ P.. I. Supervisor O~/o%- 0 [ , DATE: March 23, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests PBF/PBU C Pad Mar,ch 23, 2.00.1' I traveled to Prudhoe Bay Field to witness Safety Valve System tests on BPX's C Pad. Well house inspections were also conducted. Merv Liddelow was the BPX representative in charge of testing, and performed the tests in a professional manner. Twenty-one wells on C-Pad were tested with five failures witnessed. The SSV on. well C-04A tripped below 50% of the separator psi, the SSV on well C-07A failed to hold D/P, the pilot on well C-19B was frozen, the pilot on well C-20B failed to trip and the SSV failed to hold D/P. Mr. Liddelow indicated to me that al! failures were repaired within 24 hours. I inspected 21 well houses and noted leaking wing valves on wells C-03A, C-13A and C-19B. A hydraulic fluid leak on the SSV control line of well C-05 and a slight crude oil leak from the SSV on well C-25A were also noted. Mr. Liddelow indicated he would have these items corrected. The AOGCC test forms are attached for reference. SUMMARY: I witnessed the SVS tests on twenty-one oil producing wells on C Pad in the Prudhoe Bay Field. 21 wells tested 42 components, $ failures witnessed, and 11.9% failure rate. 21 well houses inspected. Attachments: SVS PBU C-Pad 3-23-01 JJ CC: SVS PBU C Pad 3-23-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/C Pad Separator psi: LPS 174 ., , Date: 3/23/01 HPs 662 . i . i i iii !i !'~! ~SS~i! SSSV~ 'i?:Retest~; . Well Type:. Well Permit Separ Set L/P Test Test Test Date oa, WAG, Number Number PSI PSI T~p Code Code Code Passed ~AS or CVCL~ ~-0~ ~7:0300 C.o: ~q30040 ~2 ' ~0~ "5:~ e p " OIL , ,, , , C-03A 1981840 662 550 530~ P P OIL C-04A 1960920 662 ' 550!' 220 3 P 0IL c-05 1730ii0' 174 125 ~15: p P " O~L C-0~A ~9S~70 ~2 ~50: ~S0~p p ' O~Li i , . , C-07A 2000520 662 550i 5451P 4 OIL! c_osn' ~9~o2So ,, ,, ,, , t C-09 1790260 , C-10 1790350 C-II 1790460 662 550 '595! P P OIL C-12A 1981160 C-13A 1971430 662 550! 590'? P o~L ,, , , , , , , C-15 1791090 C'16 1800100 , c-~9~:oooo~o ~: ~o :~o: P " OiL' C~20BC~-~%:~ ~ ,2001140 66~ ,, 550 0 I 4 ,, ' OIL C-21 1820810 174 125 120 P P OIL , , C-22 1820880 662 550 560 P P OIL C'23A 1961190 C-24 1821410 662 550 545 P P OIL , , , , ,, C-25A 1950110 662 550 510 P P OIL C-26A 1981450 ,, C-2S 1821950 C-29A 1961~00 ' ' C-30 ' 1871360 662 550 525 P ' P 0IL C-31A 1950060 6'62 550 560 P P ...... OI~ C-33 1930770 C-34 1880150 C-35A '195}000 174 i25 120 "P P OIL C-36A 2000020 174 125 115 P' "P .... OIL , RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 3-23-01 JJ1 Well Pemit Separ Set ~ T~t Test Test Date Oil, WAG, G~J, Number Number PSI PSI T~p,, Code Code ,C°de Passed GASorCVC[E C-37 1930550 662 550 550 P P OIL C-38 1860660 C-39 1930940 C-41 1930990 C-42 193'0500 662 ' 5501 590 P P ' , , . Wells: 21 Components: 42 Failures: 5 Failure Rate: 11.90°/~] 9o Day Remarks: Op.,erator reports all ,failures repaked and passed retest. RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 3-23-01 JJ1 -: ~ STATE OF ALASKA ALASK,~,~ ,.. AND GAS CONSERVATION COMI~ .~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 200-114 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20745-02 4. Location of well at surface 9. Unit or Lease Name 774' SNL, 1522' WEL, SEC. 19, T11N, R14E, UPM At top of productive interval i ~-~/.57-..-.~ ~ "'~~ Prudhoe Bay Unit At total depth " 10. Well Number 2146' NSL, 178' EWL, SEC. 16, TllN, R14E, UPM ~:-7~ ......... C-20B 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 59.95' ADL 028306 12. Date Spudded8.9.2000 113' Date T'D' Reached 114' Date C°mp?~usp" °r Aband' 115' Water depth' if °fish°re 116' N°' °f C°mpleti°ns8-13-2000 8;;.t~2000~ N/A MSL One 17' T°tal Depth (MD+TVD)118'15012 8883 FT Plug Back Depth (MD+TVD)14949 8888 FTII 19' Directi°nal Survey 1 20' Depth where SSSV setl 21' Thickness °f Permafr°st[] Yes [] No 2212' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, ROP 23. CASING, LINER AND CEMENTING RECORD CASING SETrlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2891' 17-1/2" 4466 cuft Arctic Set II 9-5/8" 47# L-80 Surface 8990' 12-1/4" 1565 cuft Class 'G', 167 cu ft PF 'C' 7" 29# L-80 8832' 11205' 8-1/2" 213 cuft Class 'G' 4-1/2" 12.6# L-80 11013' 13000' 6" 258 cuft Class 'G' 2-7/8" 6.16# L-80 11694' 15012' 3-3/4" 129 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 11017' 10961' MD TVD MD TVD 13890' - 14060' 8917' - 8916' 14130' -14180' 8915' - 8916' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 14240' - 14600' 8921' - 8914' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14720' - 14895' 8909' - 8894' 2000' Freeze Protect with 20 bbls of MeOH 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 23, 2000 Flowing --- i Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED SEP 1 2. 000 Ata~ 0~; & (Cas uo~. ,,;omrnissier~ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. 12N 13020' 8941' 13N / 14P 13630' 8917' 14P / 13N 13790' 8912' 12N 14640' 8913' 31. List of Attachments: Summary of Daily Ddlling Reports, Surveys ' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~/7~ ~ Title Technical Assistant Date (~(~"/,~'0(.~ C-20B 200-114 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In. Other-explain REC'EIVED ITEM 28: If no cores taken, indicate 'none'. ~ Form 10-407 Rev. 07-01-80 SEP 1 2 2000 Gas Cons. OoBmJ~ion Arlcho.ra§e : :;; :operations Summary Report Legal Well Name: C-20B Common Well Name: C-20B Spud Date: 8/8/2000 Event Name: DRILL+COMPLETE Start: 8/8/2000 End: 8/16/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 8/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: ~tei:~ ~ro~i~i~° HO~:rs IActi~i~: ~Od~l phase tl ~ Description of Operations 8/8/2000 05:00 - 06:00 1.00 RIGU PROD1 ACCEPT RIG ON C-20 B AT 05:00 HRS, 08/08/00. N/U BOPE. 06:00 - 11:30 5.50 RIGU PROD1 Perform initial BOPE pressure / function test. 2 7/8" pipe/slips in 11:30 - 13:00 1.50 RIGU PROD1 R/U hardline inside reel. Cut CT. M/U DS CTC. Pull test w/35K 13:00 - 14:00 1.00 RIGU PROD1 Press test hardline and inner reel valve with 4000 psi. 14:00 - 16:00 2.00 RIGU PROD1 Adjust rollers on CT guide arch. 16:00 - 16:20 0.33 STKOH PROD1 MU milling BHA 3.80" dia mill, motor, MHA 16:20 - 17:00 0.67 STKOH PROD1 Stab onto lub. Open mstdswab and CT packoff leaked with WHP of 170 psi. LD BHA 17:00 - 21:00 4.00 STKOH BARR PROD1 WO DS mechanics. Replace O-ring seal in packoff assy. PT @ 3500 psi. Install new CTC. PT @ 3500 psi, 35K. PU same milling BHA. 21:00-23:30 2.50 STKOH PROD1 Stabinj. Open master. WHP--150 psi. Bleedthru buster. SI. No pressure build-up. RIH. 23:30 - 00:00 0.50 STKOH PROD1 Tag and stall at 10,973' CTM. Mill thru. Tag and stall at 10,983' CTM. Mill thru. 8/9/2000 00:00 - 00:30 0.50 STKOH PROD1 RIH. Tag PBTD 12883' CTM. Correct to 12913' (+30'). 00:30 - 02:00 1.50 STKOH PROD1 Mill shoe track to 12917'. 02:00 - 02:45 0.75 STKOH POWR PROD1 SD #1 gen. Turbo failure. Air filter on fire. Extinguish. Discuss. 02:45 - 08:20 5.58 STKOH PROD1 Continue milling working off#2 gen to 12963' and started stacking with little progress 08:20 - 10:05 1.75 STKOH PROD1 Wiper to tubing tail 2.5/2400 10:05 - 10:35 0.50 STKOH PROD1 Unable to make any progress. 400 psi motor work, no drill off 10:35 - 13:00 2.42 STKOH PROD1 POOH to check BHA. Found diamond mill worn smooth on gauge and out of gauge at 3.65" 13:00 - 14:20 1.33 STKOH PROD1 WO mill. MU 3.80" Baker 4 bladed bullnose junk/cmt mill 14:20 - 16:25 2.08 STKOH PROD1 RIH w/BHA #2 16:25 - 17:50 1.42 STKOH PROD1 Mill out XN nipple at 11020' CTD. Precautionary ream 30'/min to TD 2.5/2560 40K, 15.6K 17:50 - 21:30 3.67 STKOH PROD1 Resume milling from 12965' CTD at 30-50 FPH. Little more aggressive work at 13013', then 20 FPH with 800 psi diff. Stall 13024'. Unable to work past this point. Stacking, no drill off. Should be in formation. Dry tag clean. 21:30 - 23:00 1.50 STKOH PROD1 POOH. 23:00 - 23:30 0.50 STKOH PROD1 LD milling BHA. Obvious formation wear and debris on mill. 23:30 - 00:00 0.50 DRILL DRAW PROD1 Replace drum brakes on draw. 8/10/2000 00:00 - 03:30 3.50 DRILL DRAW PROD1 Replace drum brakes on draw. 03:30 - 06:30 3.00 DRILL DATA PROD1 Trace and fix depth encoder problem. 06:30 - 07:35 1.08 DRILL PROD1 MU drilling BHA (2.0 deg SR motor, M09 RR) 07:35 - 09:40 2.08 DRILL PROD1 RIH w/BHA #3 to 13027' CTD. PUH 50K 09:40 - 10:30 0.83 DRILL PROD1 Begin tie-in to GR @ 12835' CNL 2.4/2720 43.7K. Subtract 3.6'. RIH 16K and tag TD at 13019.5' w/117R 110:30 - 11:30 1.00 DRILL PROD1 Orient around to left. Getting 230 deg reactive 11:30 - 12:00 0.50 DRILL PROD1 Drilling 56L 40-120'/hr. GR showed drilling in the 12N shale from 13020-060'. A few overpulls. Drill to 13067' and TF flopped to right 12:00 - 12:45 0.75 DRILL PROD1 Orient around several times parked just below liner at 13011' 12:45 - 15:10 2.42 DRILL PROD1 Drilling and orienting to stay around 90 deg and turning hard left 15:10 - 15:40 0.50 DRILL PROD1 Wiper to liner shoe from 13204' 2.3/2700 51.7K, clean 15:40 - 16:00 0.33 DRILL PROD1 Drilling in a good sand at 120'/hr 16:00 - 17:40 1.67 DRILL DS PROD1 Drilled to 13234' and started stacking. PUH and diff stuck BHA. Circ @ min and work occasionally while WO dead crude 0.4/1480 17:40 - 20:00 2.33 DRILL DS PROD1 Pump 13.5 bbls dead crude and displace w/mud. Spot 5 bbls out, let soak, pull free. Wiper trip thru shoe (60k). Log tie-in up at 12835' GR !spike 2.5/2950/49k. Correct depth +16' minus 4' stretch. RIH and tag 13234'. Printed: 8/30/2000 2:12:27 PM Legal Well Name: C-20B Common Well Name: C-20B Spud Date: 8/8/2000 Event Name: DRILL+COMPLETE Start: 8/8/2000 End: 8/16/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 8/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: i:i i Fr°m~T0 H°~:rs Act?i~ COde Phasel Description of Operations 8/10/2000 20:00 - 20:15 0.25 DRILL PROD1 Orient around. 65k up w/no pumps. 20:15 - 21:15 1.00 DRILL PROD1 Drill 2.6/3100/85L to 13338'. Building a little too much. 21:15 - 21:30 0.25 DRILL PROD1 Orient around. 21:30 - 22:15 0.75 DRILL PROD1 Drill to 13390. Not getting desired turn (will get us too close to fault). POOH for stronger motor. Flag pipe 12800' EOP. 22:15 - 22:45 0.50 DRILL PROD1 Log MAD pass 12880' - 13040'. 22:45 - 00:00 1.25 DRILL PROD1 POOH. Difficult pulling thru tailpipe 11018'. Pull to 70k, no motor work. Clean SO. Worked it thru. POOH. 8/11/2000 00:00 - 01:30 1.50 DRILL PROD1 POOH for stronger motor. 01:30 - 02:30 1.00 DRILL PROD1 Adjust motor from 2.0 to 2.3 deg. (70 mph wind). 02:30 - 05:00 2.50 DRILL PROD1 RIH with BHA #4. Correct depth at flag (-0.5'). 05:00 - 06:00 1.00 DRILL OTHR PROD1 Clamp holding end of coil in inner reel came loose. Suck coil back in and reclamp. 06:00 - 06:10 0.17 DRILL PROD1 Orient. 06:10 - 07:25 1.25 DRILL PROD1 Drill 2.5/3100/90L to 13476' and started stacking 07:25 - 08:15 0.83 DRILL PROD1 Wiper to liner shoe 58K @ 30'/min 08:15 - 08:35 0.33 DRILL PROD1 Orient around at 70-75K 08:35 - 08:50 0.25 DRILL PROD1 Attempt to make hole. Drilling wi neg wt 08:50 - 10:50 2.00 DRILL PROD1 Wiper from 13480' to 10950' while WO new mud. Saw flag on depth. 10-20K overpulls at 11076', 11063', 11054', 11030', 10980'. RIH from 10950' 10:50 - 11:15 0.42 DRILL PROD1 RIH from 13000' (7k dn wt at 30'/min 2.5/3330) displacing to new mud (50 mph winds, 33F, 0 CF, snow-almost Phz 1) 11:15 - 13:30 2.25 DRILL PROD1 Drilling again at 13480' @ 60-120'/hr w/positive wt. Completley displaced at 13514'. 2.5/3200/97L 47K orienting, 41K pumping, 10K drilling-love new mud 13:30 - 14:00 0.50 DRILL PROD1 Fin drilling to end of turn at 13631'. Wiper to window 14:00 - 16:00 2.00 DRILL PROD1 POOH for smaller bend motor 16:00 - 17:15 1.25 DRILL PROD1 CCH. Change bit, motor, MWD probe 17:15-19:35 2.33 DRILL PROD1 'RIH w/BHA #5 19:35 - 19:55 0.33 DRILL PROD1 Log tie-in down at 12834' GR spike (correct +2.5'). 19:55 - 20:15 0.33 DRILL PROD1 Wash to TD. 20:15 - 20:35 0.33 DRILL PROD1 Drill to 13670' with 128L. Surveys showing 96 deg inc. Need to point it down. 20:35 - 21:00 0.42 DRILL PROD1 Orient around. 21:00 - 22:30 1.50 DRILL PROD1 Drill 2.7/3500/175R to 13730'. In¢ back to 92 deg. Get a couple of clicks. Drill 2.6/3300/130L to 13800'. Diff stuck pulling off bottom. Pull free at 75k. 22:30 - 23:15 0.75 DRILL PROD1 Wiper trip to shoe. Overpulls 13700' and 13652'. 23:15 - 23:30 0.25 DRILL PROD1 Orient for right turn. 23:30 - 00:00 0.50 DRILL PROD1 Tag 13792'. Add 8' to correct to 13800'. Drill 2.6/3300/105R to 13850'. 8/12/2000 00:00 - 00:30 0.50 DRILL PROD1 Drill 2.6/3250/105R to 13880'. 00:30 - 00:45 0.25 DRILL PROD1 Orient around to build inclination. 00:45 - 02:00 1.25 DRILL PROD1 Drill to 13980' working TF from 50R to 90R. 02:00 - 03:00 1.00 DRILL PROD1 Wiper trip to shoe. Pull heavy 13730'. 03:00 - 03:45 0.75 DRILL PROD1 Drill 90R to 14030'. Stack then stuck differentially. 03:45 - 04:45 1.00 DRILL DS PROD1 Work pipe. Call for crude. Pulled free without it. Cancel crude. 04:45 - 05:00 0.25 DRILL DS PROD1 Orient around. 05:00 - 05:30 0.50 DRILL PROD1 Drill to 14065'. Stack, stuck. 05:30 - 06:55 1.42 DRILL DS PROD1 Work pipe. Get crude coming again. 06:55 - 08:20 1.42 DRILL PROD1 Work free w/o us ng crude, put truck on standby to save tires. Wiper to 12000', clean. RIH 08:20 - 08:30 0.17 DRILL PROD1 Tie-in, add 9.0' Printed: 8/30/2000 2:12:27 PM Operations summary Report Legal Well Name: C-20B Common Well Name: C-20B Spud Date: 8/8/2000 Event Name: DRILL+COMPLETE Start: 8/8/2000 End: 8/16/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 8/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: i: ~Date From ~ To Hours ~ActiVityi~Codei PhaseI Description of Operations 8/12/2000 08:30 - 09:05 0.58 DRILL PROD1 I RIH to TD 2.4~3200 09:05 - 09:55 0.83 DRILL PROD1 Tag at 14067'. Orient around from 159R 09:55 - 12:20 2.42 DRILL PROD1 Drilling thru a few shales trying to find correct sand 2.4132001110R to ~ 14218' 12:20 - 13:10 0.83 DRILL PROD1 !Wiper to shoe before orient around 13:10 - 14:00 0.83 DRILL PROD1 Orient around from 119R 14:00 - 17:00 3.00 DRILL PROD1 Drilling 2.3/3400/67R-in and out of shales to 14350' 17:00 - 18:35 1.58 DRILL PROD1 Wiper to 11900', clean. RIH 18:35- 18:50 0.25 DRILL PROD1 Tie-in at 12850', add 10.0' 18:50 - 19:40 0.83 DRILL PROD1 RIH to TD 2.6/3850. 19:40 - 20:00 0.33 DRILL PROD1 Orient. 20:00 - 22:00 2.00 DRILL PROD1 Displace well to new mud. Drill sand to 14450', trying to hold 91 deg inclination. 22:00 - 22:30 0.50 DRILL PROD1 Drill slow (shale?) to 14490'. New mud conditions 2.5/3700psi. Don't know why pressure is so high. Swap filters. No change. 22:30 - 23:45 1.25 DRILL PROD1 Wiper trip to shoe. RIH 2.6/4000/34 FPM/12k. 23:45 - 00:00 0.25 DRILL PROD1 Drill 2.4/3600/120L to 14510'. 8/13/2000 00:00 - 01:00 1.00 DRILL PROD1 Drilling 2.4/3600/110L to 14560'. Stacking. 01:00 - 01:15 0.25 DRILL PROD1 100' wiper. 01:15 - 01:45 0.50 DRILL PROD1 Drill w/neg weight to 14600'. Unable to get bit to bottom. Overpulls off bottom. 01:45 - 03:10 1.42 DRILL PROD1 Wiper trip to shoe. Hole is in good shape. 03:10 - 03:50 0.67 DRILL PROD1 Drill 2.4/3600 to 14635' working TF up to get out of ratty stuff. 03:50 - 04:00 0.17 DRILL PROD1 100' wiper. Get TF up. ~04:00 - 05:30 1.50 DRILL PROD1 i Drill 2.4/3600/55L. Difficult getting bit to bottom. Perform short wiper trips, then stack wt running back to bottom, then overpull to 70k. High pressure not helping any. Appears that slow 100' wiper trips help. Drill to 14692' 05:30 - 05:45 0.25 DRILL PROD1 !Got desired inclination. Orient around to hold. 05:45 - 06:15 0.50 DRILL PROD1 Try drilling. Stack. 100' slow wiper. 06:15 - 07:20 1.08 DRILL PROD1 Drill 2.2/3500/115L to 14750' 07:20 - 09:20 2.00 DRILL PROD1 Wiper to 10900' while tune up mud. 20k overpulls in shale 14640-690'. 20k overpull at WLEG-acts like there is a gap between TOL and WLEG and WLEG is off center 09:20 - 09:50 0.50 DRILL PROD1 RIH 09:50 - 10:15 0.42 DRILL PROD1 Tie-in, add 13.0' 10:15-11'10 0.92 DRILL PROD1 RIH to TD at 14760' corr 11 '10 - 11:20 0.17 DRILL PROD1 Drilling 2.4/3380/72R 40K to 14770' 11:20 - 12:00 0.67 DRILL PROD1 Orient around 12:00 - 14:35 2.58 DRILL PROD1 Drilling 2.3/3300/89L to 14918' in and out of sands 14:35 - 16:25 1.83 DRILL PROD1 Wiper to shoe 16:25 - 16:45 0.33 DRILL PROD1 Orient around from 89L 16:45 - 19:00 2.25 DRILL PROD1 Drilling (spudding) rathole. Drill to 14995'. 19:00-20:15 1.25 DRILL PROD1 Do final wiper trip to try and get last15 ish ft. Small OP14210' and at shoe 13000'. 20:15-20:30 0.25 DRILL PROD1 Tie-in 12850'. Add 7'. 20:30 - 21:40 1.17 DRILL PROD1 Wash to bottom 2.6/4100/36 FPM/10k. Took wt 14110'. 21:40 - 22:00 0.33 DRILL PROD1 Drill to 15010' easy, decide to go to 15020' for bottom perf at 14950'. ,Stack at 15012'. PU. RIH. Stack and stuck off bottom 15008'. 22:00 - 23:45 1.75 DRILL DS PROD1 iWork pipe to 80k. No go. Call for crude. Let relax. Continue working pipe. Circulate 2.0/3150 while waiting on crude. 23:45 - 00:00 0.25 DRILL DS PROD1 Pump 15 bbls crude. Displace with mud. 8/14/2000 00:00 - 00:30 0.50 DRILL DS PROD1 Circulate 15 bbls crude to bit. Put 5 bbls out. Let soak 10 min. Pull i Printed: 8~30~2000 2:12:27 PM i operations Summary Report Legal Well Name: C-20B Common Well Name: C-20B Spud Date: 8/8/2000 Event Name: DRILL+COMPLETE Start: 8/8/2000 End: 8/16/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 8/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: ~°~rsIActivi~ COde: phase: i of Operations ~te Fro~ ~T0 I: Description 8/14/2000 00:00 - 00:30 0.50 DRILL DS PROD1 free at 55k. Circulate remaining crude out of coil. Tag TD 15007'. Correct to 15012'. 00:30 - 01:30 1.00 DRILL PROD1 Wash hole to shoe. Slight overpull 14,110', otherwise clean. 01:30 - 01:50 0.33 DRILL PROD1 Log tie-in. We're 3' shallow. Close enough. No correction. Corrected TD 15012'. 01:50 - 04:15 2.42 DRILL PROD1 i POOH, washing slow in cased-hole horizontal. Flag pipe 11700' and 9700' EOP. Bobbled thru tailpipe. 04:15 - 06:00 1.75 DRILL =ROD1 SB injector. LD drilling BHA. Bit 1-1-1. 06:00 - 06:30 0.50 CASE PROD1 RU to run liner. 06:30 - 06:45 0.25 CASE PROD1 Safety meeting. 06:45 - 10:00 3.25 CASE PROD1 MU 109 its 2-7/8" 6.16# L-80 STL liner 10:00 - 11:15 1.25 CASE PROD1 MU Baker CTLRT. Intall Baker CTC. PT @ 35K, 3500 psi 11:15-13:05 1.83 CASE PROD1 RIH w/liner on CT 13:05-13:50 0.75 CASE PROD1 47K, 15.5K@ 13150' RIH w/ liner thru open hole. Work last S0' to TD at 15022' CTD. 62K, -12K 13:50 - 14:20 0.50 CASE PROD1 Load 518" steel ball and circ to seat w/mud. Ball hit at 52.6 bbls. Release from liner at 33.5K. RU DS cementers 14:20 - 15:45 1.42 CASE ! PROD1 Displace FIo Pro mud to 2% KCI water. PJSM on cmting. Mix cement 15:45 - 16:20 0.58 CASE PROD1 PT DS @ 4000. Load CT w/23.0 bbls 15.8 ppg G cmt w/latex. Load wiper dart 16:20 - 16:50 0.50 CASE PROD1 Displace w/2% KCI. Dart seated at 59.2 bbls. Wiper plug in place at 77.5 bbls w/21.5 of 23 bbl returns. Held 2200 psi, unsting 35K, floats held 16:50 - 18:40. 1.83 CASE PROD1 POOH with CTLRT 18:40 - 19:15 0.58 CASE PROD1 LD CTLRT 19:15 - 19:45 0.50 CASE PROD1 RU to run CSH. 19:45 - 20:00 0.25 CASE PROD1 Safety meeting. 20:00 - 00:00 4.00 CASE PROD1 MU 105 its 1-1/4" CSH on 2-1/4" mill and 2-1/8" motor. 811512000 00:00 - 01:00 1.00 CASE PROD1 Finish MU 105its 1-1/4" CSH on motodmill. 01:00 - 01:30 0.50 CASE PROD1 MU DS MHA, stab inj. 01:30 - 04:00 2.50 CASE PROD1 RIH. Wash liner 1.7/200. No stringers. Correct at flag (-9'). Tag solid 14940' CTM, no motor work. Take a run at it. Same tag, no work. Repeat. Finally got a stall. Latch collar. 04:00 - 04:15 0.25 CASE PROD1 POOH, laying in 21 bbls 150k LSRV FIo-Pro in liner. 04:15 - 04:30 0.25 CASE PROD1 Difficult pulling GTC through tailpipe (10951' EOP). Work with and without pumps. Finally skipped through. 04:30 - 06:30 2.00 CASE PROD1 Continue POOH. 06:30 - 07:00 0.50 CASE PROD1 SB inj. Drop 5~8" ball to open Baker circ sub. Shear at 2950 psi. 07:00 - 07:45 0.75 CASE PROD1 Standback CSH workstring 07:45 - 08:00 0.25 CASE DRAW PROD1 Adjust drawworks brakes 08:00 - 09:00 1.00 CASE PROD1 Fin standback CSH workstring 09:00 - 09:30 0.50 CASE PROD1 Press test liner lap @ 2200 psi w/623 on IA w/1.5 bbls for 20 min. Cmt comp str@ 2764 psi + 09:30 - 14:00 4.50 BOPSUR PROD1 Perform weekly BOPE test 14:00 - 17:00 3.00 PERF PROD1 !PJSM. PU Schlumberger perf guns 17:00 - 19:45 2.75 PERF PROD1 MU firing head and hyd disconnect. RIH with 52 stands of 1 1/4" CSH workstring. 19:45 - 21:50 2.08 PERF PROD1 MU coil conn. Stab Inj. RIH. PU at 14800' - 52 klbs. Cont RIH and tag latch collar. PU and correct to PBTD (+13') 21:50 - 22:15 0.42 PERF PROD1 i Adjust charge pressure on hydraulic power pack. 22:15 - 22:30 0.25 PERF PROD1 I Load ball for firing head and pump to CT. 22:30 - 23:00 0.50i PERF PROD1 Pump ball down to firing head at 2.1 bpm/2900 psi. on seat at 68 bbls. 23:00 - 23:30 0.50 PERF PROD1 Pressure up and fire guns at 3050 psi. Start up hole immediately and -.. Printed: 8/30/2000 2:12:27 PM ; :~ ~ ~:~ i~;:~::~:~; :;~ ~ ~:,:operations Summary Report Legal Well Name: C-20B Common Well Name: C-20B Spud Date: 8/8/2000 Event Name: DRILL+COMPLETE Start: 8/8/2000 End: 8/16/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 8/16/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: : : : : : : : :: : :: : i :Date From~T°: H6~S A~tigi~ Code i:phaseI i: Description of Operations 8/15/2000 23:00 - 23:30 0.50 PERF PROD1 pull up to 13900' pumping at min rate. Circ & confirm loss to perfs - guns appear to have fired OK. 23:30 - 00:00 0.50 PERF PROD1 POH with guns circulating across top of hole. Printed: 8/30/2000 2:12:27 PM : ? oPerationssUmmaryReport Legal Well Name: C-20B Common Well Name: C-20B Spud Date: 8~8~2000 Event Name: DRILL+COMPLETE Start: 8/8/2000 End' 8/16/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 8/16/2000 Group: RIG Rig Name: NORDIC 1 Rig Number: ::: :Date: ::1 :Fr°m::~ T°:: ::H°urs !Activity COde:: PhaseI Description of Operations 8/16/2000 00:00 - 01:30 1.50 PERF PROD1 Cont POH with coil. Disconnect coil from workstring. Stand back injector. 01:30 - 01:45 0.25 PERF PROD1 PJSM prior to LD CSH workstring. 01:45 - 05:45 4.00 PERF PROD1 LD 103 singles 1 1/4" CSH workstring. 05:45 - 10:30 4.75 PERF PROD1 PJSM and LD perf guns. All shots fired 10:30 - 12:00 1.50 RUNCO~ PROD1 TIH to 2000' and freeze protect tubing w/MeOH 12:00 o 17:00 5.00 RIGD PROD1 Purge CT w/N2,unstab injector and set back. Clean pits, ND BOP. Release rig at 14:00 8/16/00 Printed: 8/30/2000 2:12:27 PM North Slope Alaska Alaska State Plane 4 PBU WOA C Pad C-20A - C-20B Surveyed: 13 August, 2000 SURVEY REPORT 08/22/2000 14:35:42 PM Your Ref: API-500292074502 Surface Coordinates: 5960433.85 N, 663842.88 E (70° 17' 53.7066" N, Kelly Bushing: 59.95ft above Mean Sea Level 148° 40' 23.0898" W) Survey Ref: svy9943 Sperry-Sun Drilling Services Survey Report for C-20A - C-20B Your Ref: API-500292074502 Surveyed: 13 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 12898.15 87,540 141,600 8875.22 8935.17 13001.00 87,150 138.270 8879.99 8939.94 13030.56 92,030 137.950 8880.20 8940.15 13058.96 95.430 137.500 8878.35 8938.30 13098.16 93.420 128.080 8875.32 8935.27 13125.56 90.720 122.970 8874.33 8934.28 13160.96 88.330 114.300 8874.63 8934,58 13191.76 89.300 107.090 8875.26 8935,21 13280.56 90.750 87.130 8875.23 8935.18 13312.76 93.080 79.320 8874.15 8934.10 13349.36 93.690 72.110 8871.98 8931.93 13381.96 92.020 62.440 8870.36 8930.31 13411.96 92.360 52.440 8869.21 8929.16 13454.16 94.570 41.170 8866.65 8926.60 13486.56 93.960 31.430 8864.23 8924.18 13540.76 90.530 12.520 8862.09 8922.04 13574.76 92.200 2.850 8861.28 8921.23 13605.16 94.390 349.670 8859.52 8919.47 13634.73 95.890 349.320 8856.88 8916.83 13668.73 95.620 344.920 8853.46 8913.41 13701.33 92.020 344.750 8851.29 8911.24 13732.13 88.770 345.270 8851.08 8911.03 13765.33 88.860 341.410 8851.77 8911.72 13797.73 88.860 334.900 8852.41 8912.36 13830.93 87.540 339.120 8853.46 8913.41 1600.97 N 6575.95 E 1522.35 N 6642.06 E 1500.35 N 6661.80 E 1479.38 N 6680.86 E 1452.87 N 6709.51 E 1436.97 N 6731.78 E 1420.02 N 6762.82 E 1409.14 N 6791.61 E 1398.21 N 6879.28 E 1402.00 N 6911.21 E 1411.01N 6946.59 E 1423.57 N 6976.58 E 1439.69 N 7001.82 E 1468.47 N 7032.48 E 1494.48 N 7051.58 E 1544.47 N 7071.74 E 1578.11N 7076.29 E 1608.33 N 7074.31 E 1637.28 N 7068.94 E 1670.25 N 7061.41 E 1701.64 N 7052.90 E 1731.39 N 7044.93 E 1763.18 N 7035.42 E 1793.23 N 7023.37 E 1823.77 N 7010.41 E 5962177.80 N 670382.36 E 5962100.65 N 670450.18 E 5962079.08 N 670470.38 E 5962058.54 N 670489.89 E 5962032.65 N 670519.12 E 5962017.24 N 670541.73 E 5962000.97 N 670573.13 E 5961990.73 N 670602.15 E 5961981.71 N 670690.04 E 5961986.20 N 670721.88 E 5961995.97 N 670757.06 E 5962009.19 N 670786.77 E 5962025.85 N 670811.65 E 5962055.29 N 670841.67 E 5962081.71 N 670860.20 E 5962132.13 N 670879.27 E 5962165.86 N 670883.08 E 5962196.03 N 670880.45 E 5962224.86 N 670874.45 E 5962257.66 N 670866.19 E 5962288.86 N 670857.00 E 5962318.42 N 670848.39 E 5962350.00 N 670838.18 E 5962379.78 N 670825.49 E 5962410.03 N 670811.87 E Dogleg Rate (°/100ft) 3.256 16.544 12.076 24.500 21.081 25.403 23.615 22.536 25.296 19.735 30.064 33.328 27.165 30.037 35.427 28.853 43.876 5.208 12.900 11.055 10.686 11.627 20.089 13.312 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment 4104.44 4058.95 4046.71 4035.15 4022.36 4016.72 4013.65 4015.24 4040.39 4056.67 4079.12 4102.66 4127.54 4166.20 4197.69 4251.57 4284.21 4311.10 4335.47 4362.65 4387.99 4412.04 4437.35 4460.04 4482.82 Tie-on Survey Window Point Continued... 08/22/2000 14:35:44 PM -2- DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for C-20A - C-20B Your Ref: API-500292074502 Surveyed: 13 August, 2000 North Slope Alaska Measured Depth (ft) Incl, Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 13878.73 85.780 343.690 8856.24 8916.19 13915.53 88.590 346.510 8858.05 8918.00 13949.13 90.610 350.900 8858.28 8918.23 13979.73 90.790 354.590 8857.91 8917.86 14010.33 91.540 357.100 8857.29 8917.24 14039.13 91.930 359.340 8856.42 8916.37 14067.53 92.200 4.790 8855.39 8915.34 14091.93 90.790 7.070 8854.76 8914.71 14118.73 89.970 10.140 8854.58 8914.53 14146.93 88.860 11.640 8854.87 8914.82 14176.73 87.660 16.100 8855.77 8915.72 14212.13 83.930 14.630 8858.37 8918.32 14242.93 86.040 18.670 8861.06 8921.01 14282.13 90.090 25.000 8862.38 8922.33 14313.73 90.880 26.930 8862.12 8922.07 14343.13 92.110 32.910 8861.35 8921.30 14379.93 93.080 31.150 8859.68 8919.63 14418.93 92.460 23.240 8857.79 8917.74 14448.53 91.760 17.970 8856.70 8916.65 14483.73 90.790 15.860 8855.92 8915.87 14520.33 91.360 12.550 8855.23 8915.18 14559.53 91.140 6.370 8854.38 8914.33 14589.53 91.050 1.620 8853.80 8913.75 14625.13 89.910 355.120 8853.51 8913.46 14656.13 92.020 352.480 8852.98 8912.93 Local Coordinates Northings Eastings (ft) (ft) 1868.99 N 6995.20 E 1904.50 N 6985.75 E 1937.44 N 6979.17 E 1967.79 N 6975.31 E 1998.30 N 6973.09 E 2027.07 N 6972.20 E 2055.42 N 6973.22 E 2079.68 N 6975.74 E 2106.17 N 6979.75 E 2133.86 N 6985.08 E 2162.77 N 6992.22 E 2196.81 N 7001.57 E 2226.20 N 7010.36 E 2262.54 N 7024.92 E 2290.94 N 7038.76 E 2316.41N 7053.41E 2347.57 N 7072.91 E 2382.19 N 7090.69 E 2409.87 N 7101.10 E 2443.53 N 7111.34 E 2479.00 N 7120.32 E 2517.64 N 7126.75 E 2547.56 N 7128.84 E 2583.12 N 7127.83 E 2613.93 N 7124.48 E Global Coordinates Northings Eastings (ft) (ft) 5962454.90 N 670795.67 E 5962490.20 N 670785.45 E 5962522.99 N 670778.15 E 5962553.25 N 670773.63 E 5962583.70 N 670770.75 E 5962612.45 N 670769.23 E 5962640.81N 670769.63 E 5962665.12 N 670771.62 E 5962691.70 N 670775.05 E 5962719.50 N 670779.77 E 5962748.55 N 670786.28 E 5962782.79 N 670794.89 E 5962812.36 N 670803.04 E 5962849.01 N 670816.81 E 5962877.71N 670830.02 E 5962903.48 N 670844.11 E 5962935.07 N 670862.92 E 5962970.07 N 670879.95 E 5962997.96 N 670889.75 E 5963031.85 N 670899.25 E 5963067.50 N 670907.46 E 5963106.27 N 670913.05 E 5963136.22 N 670914.49 E 5963171.76 N 670912.70 E 5963202.49 N 670908.68 E Dogleg Rate (°/lOOff) 10.230 10.811 14.381 12.072 8.559 7.891 19.201 10.984 11.856 6.617 15.492 11.321 14.753 19.160 6.599 20.759 5.457 20.320 17.948 6.596 9.175 15.772 15.833 18.536 10.901 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment 4518.13 4546.87 4574.41 4600.65 4627.71 4653.71 4680.09 4703.32 4729.20 4756.70 4786.05 4820.98 4851.42 4890.55 4922.12 4951.32 4987.69 5026.54 5056.07 5091.01 5127.11 5165.08 5193.32 5225.49 5252.37 Continued... 08/22/2000 14:35:45 PM - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for C-20A - C-20B Your Ref: API-500292074502 Surveyed: 13 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 14693.13 94.130 351.600 8851.00 8910.95 2650.52 N 7119.37 E 14725,93 92.720 344.570 8849.04 8908.99 2682.53 N 7112.61 E 14752.73 95.270 341.580 8847.17 8907.12 2708.11 N 7104.83 E 14783.13 95.180 340.700 8844.40 8904.35 2736.75 N 7095.05 E 14820.33 94.310 335.610 8841.32 8901.27 2771.15 N 7081.25 E 14851.33 95.010 332.270 8838.80 8898.75 2798.90 N 7067.68 E 14882.13 96.420 326.820 8835.73 8895.68 2825.31 N 7052.16 E 14923.13 97.120 321.370 8830.90 8890.85 2858.28 N 7028.29 E 14952.13 95.470 319.630 8827.72 8887.67 2880.52 N 7009.96 E 14986.93 93.950 316.450 8824.86 8884.81 2906.30 N 6986.77 E 15012.00 93.950 316.450 8823.13 8883.08 2924.43 N 6969.54 E 5963238.96 N 670902.77 E 5963270.82 N 670895.32 E 5963296.21N 670886.98 E 5963324.64 N 670876.57 E 5963358.73 N 670862.03 E 5963386.18 N 670847.86 E 5963412.24 N 670831.76 E 5963444.68 N 670807.18 E 5963466.52 N 670788.37 E 5963491.79 N 670764.63 E 5963509.54 N 670747.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.032° (22-Aug-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 23.650° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15012.00ft., The Bottom Hole Displacement is 7558.23ft., in the Direction of 67.237° (True). Dogleg Rate (°/100ft) 6.177 21.822 14.642 2.898 13.835 10.973 18.192 13.310 8.242 10.100 0.000 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment 5283.83 5310.45 5330.75 5353.07 5379.05 5399.02 5416.99 5437.61 5450.63 5464.95 5474.64 Projected Survey Continued... 08/22/2000 14:35:46 PM - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for C-20A - C-20B Your Ref: AP1-$00292074502 Surveyed: 13 August, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA C Pad Comments Measured Depth (ft) 12898.15 13001.00 15012.00 Station Coordinates TVD Northings Eastings (~) (~) (~) 8935.17 1600.97 N 6575.95 E 8939.94 1522.35 N 6642.06 E 8883.08 2924.43 N 6969.54 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (~t) 15012.00 8883.08 Survey Tool Description MWD Magnetic 08/22/2000 14:35:46 PM - 5- DrillQuest 1.05.05 MEMORANDUM TO: THRU' FROM: Dan Seamount J/-'~ /-~. ¢2 Co mmission er o¢'~'/°// · Blair Wondzell ~ P.I. Supervisor Jeff Jones~'/)4,,~/~ Petroleum qflsp'c~fNON- CONFIDENI~L State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 8, 2000 SUBJECT: Blowout Preventer Test Nordic Rig #1 BP/C-Pad C-20B 200 1140 PBFIPBU Operator Rep.: Rick Whitlow Contractor Rep.: Shawn McKiernan Op. phone: 659-4433 Rig phone: 659-4434 Op, E-Mail: pbuctdsupervisor@bp.com Rig E-Mail: Test Pressures Rams: 250/4000 Annular: 250/3000 Choke: 250/4000 P/F P/F Location Gen.' P Well Sign F Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P / Standing Order Posted P BOP STACK: Stripper Annular Preventer #1 Rams #2 Rams #3 Rams CfA Rams #5 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quantity Size/Type P/F N/A P I 7 1/16 P I Blind/Shear P 1 2 3/8 PIS P 1 2 7/8 P/S P 1 2 3/8 Pipe P N/A 1 3 1/8 P 1 3 1/8 P 2 2 1/16 P 1 2 1/16 P CHOKE MANFOLD: Quantity P/F No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P Upper Kelly Lower Kelly Ball Type Inside BOP Quantity P/F N/A N/A N/A 1 P Visual Alarm P P P P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector P P P P F F Quantity P/F Inside Reel valves I NFF ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3040 P Pressure After Closure 2000 P 200 psi Attained 23 sec. P Full Pressure Attained 2.1 mb P Blind Switch Covers: All P Nitgn. Bottbs (avg): 3(~2010 P Tuesday Aul~ust 8, 2000: I traveled to BPX's PBU C Padto witness the hitial BOPE test tn Dowell Schlumberger/Ncrdic Rig # 1, grepm~g to dh31 well C-20B. The test hsted 5 hours andI observed three fatures. The H2Sgas detecter in the inudpits faied to activate the audo and visual alarms, t was relmired and cah~orated andpass~-d dr~teSt'whte iWas'cn locatian. There was nowell__sign_ p~sted on~--o~ near the r~ identifying the wel being Oalled. tn addition, I could not witness a test (f the h~ide reelvalve on the call tubing because the t/ping t~-~ had-not Yet ~en cmnectec[ Rick Whitlow, the BPX relxesentati~e on location, sent cbcumentatx)n--~t the reelvalva~testedandpassedto the AOGCC North Slope office prior to dn21ing operatbns. The rig and it's equipment appeared clean and in good condition, and the bcation is well organized. SummaD.': I witnessedthe hitial BOPE test tn DS/Nordic Rig # 1 drying BPX's C-20B well. Total Test Time: 5 hrs,. Number of falures: 3 cc: PBU Drip. End. Attachments: none V01j1721.:XlS 8/9/00 ALASKA OIL AND GAS CONSERVATION COPiMISSION · TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mark Stanley CT Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit C-20B BP Exploration (Alaska) Inc. Permit No: 200-114 Sur Loc: 774'SNL, 1522'WEL, Sec. 19, T11N, R14E, UM Btmhole Loc. 2061'NSL, 297'EWL, Sec. 16, T11N, R14E, UM Dear ]Vf~-. Stanley: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / J ~ day of August, 2000 dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .' ~--. STATE OF ALASKA /-;4-h,, ~,~._/.. ALASK~ IL AND GAS CONSERVATION COMk..SSION PERMIT TO DRILL 20 AAC 25.005 , , la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone , , 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE - 59.95' Prudhoe Bay Field / Prudhoe , , 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028306 4. Location of well at surface ,/. ¢' ,/' 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 774' SNL, 1522' WEL, SEC. 19, T11N, R14E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number 1854' NSL, 4125' EWL, SEC. 17, T11N, R14E, UPM C-20B Number 2S100302630-277 At total depth 9. Approximate spud date 2061' NSL, 297' EWL, SEC. 16, T11N, R14E, UPM 08/01/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028305, 297' MDI No Close Approach 2560 14858' MD / 8828' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12913' Maximum Hole Angle 90 o Maximum surface 2294 psig, At total depth (TVD) 8800' / 3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Wei,qht Grade Coupling Len.qth MD TVD MD TVD (include sta,qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 3158' 11700' 8682' 14858' 8828' 121 cu ft Class'G' 19. To be c~mpleted for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13001 feet Plugs (measured) true vertical 8940 feetORIGINAL Effective depth: measured 12914 feet Junk (measured) true vertical 8936 feet Casing Length Size Cemented MD TVD Structural BKB Conductor 110' 20 X 30 8 cu yds concrete 110' 110' Surface 2658' 13-3/8" 4466 cu ft Arctic Set II 2891' 2660' Intermediate 8957' 9-5/8" 1565 cu ft Class 'G', 167 cu ft PF 'C' 8990' 6256' Production Liner 2373' 7" 213 cu ft Class 'G' ~ ~-.--' .-:."~: :~-'~ ~: .."8832' - 11205' 6153' - 8338' Liner 1987' 4-1/2" 258 cuft Class 'G' ~'"~": ~ ...... '~'""? ?:iib13' - 13000' 8150' - 8940' Perforation depth: measured 12560'- 12770', 12810'- 12890' ,t~.~ti~, 2 ~ 2000 true vertical 8931' - 8933', 8932' - 8935' ?~;:~...:.,~:.-4~-'~ ~' '¢': 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that the f~¢~:~j¢11~ an¢c(~rrect to the best of m~ knowle'dge Signed Mark Stanley ]~t N (~~,"( Title CT DrillingSuperintendent Date ~/-,~/oZ~-'/ o Permit Number I APl Number ~ I Ap.p[ovsI I~teI See cover let{er -- 150- 029-20z '¢02 I I Ifor other requirements Conditions of Ap~)roval: Samples Required [] Yes J~ No Mud Log Rt~qulred [] Yes ,~ No Hydrogen Sulfide Measures ~'Yes [] No Directional Survey Required z[~'Yes [] No Required Working Pressure for BOPE •2K; r-13K; •4K; F-C, 5K; •10K; []15K Other: ~ ~,'~'~ '~-~ -,~--~.k- I~..~,.~"~ ORIGINAL SIGNED BY by order of Approved By n m,-,,,~^, o ......... Commissioner the commission Date Form 10-401 Rev. 12-01-85 ~) ~Oui-,t Su )r ~il in Triplicate BPX C-20b Sidetrack Summary of Operations: Co20a is currently shut in due to high GOR. C-20b will extend the C-20a wellbore in the 13P sand to improve access to remaining Zone 1 reserves. This sidetrack will be conducted in two phases. Phase 1: Liquid pack IA, Kill well: Planned for July 28, 2000. · The Inner Annulus will be liquid packed and the well killed with seawater followed by 8.7 ppg FIo-Pro. Phase 2: Mill shoe track, Drill and Complete sidetrack: Planned for August 1, 2000. Drilling coil will be used to mill existing 4 ~" float equipment then drill and complete the directional hole as per attached plan. The extension will be completed with a cemented liner. Top of 2 7/8" to be approx. 11,700' MD (8682'ss) with top of liner cement approx. 12,160'MD (8854'ss). This will leave top of liner cement approx. 400 ft above the existing C-20a perfs. Approx. 21.5 bbls cement will be used for this liner cement job. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L cemented liner will be run from TD to approx. 11,700' MD. Top of liner cement will be at approx. 12,160' MD. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · Either a real time Resistivity or a Memory Induction will be run in open hole. Hazards Milling the existing float equipment is a mechanical risk. No faults will be crossed. Res. pressure is normal. Reservoir Pressure Res. press, is estimated to be 3350 psi at 8800ss. Max. surface pressure with gas (0.12 psi/It) to surface is 2294 psi. TREE: 6 1/8 .... - Camron WELLHEAD: McEvoy ACTUATOR: Axelson C-2' Proposed Completion KB. ELEV = 67.50' c3F. ELEV = 34.30' 13-3/8" 72# L-80 BUTTRESS I 2891' FOC BakerZXP /8832' I--- Liner Top Packer 7' Liner Top 26# L-80 IBT Mod Whipstock on top of EZSV I 9018' IHOWCO 9 5/8" I EZSV 4 1/2" HES (HXO) SSSV 3.813" ID 2212' Gas Lift Mandrels 4 1/2" x 1" Camco GLM KBG2-LS Mod 3.909" ID Intearal MD 5591' 9691' _arch TVD 4202' 6797' 42 6 4 1/2" L-80 12.6# IBT-Mod. 3.958" ID Max. Hole Angle 90 AT 12,802 Top P&A cement plug I11,167' 9-5/8" 47# L'80 BTRS 111,705' PERFORATION SUMMARY 12810-12890 tOEN/SQZ'D PEN PEN ~ X Nipple 3.813" ID I10,950' ---Baker S-3 Packer 3.875 ID 110,961' --~ X Nipple 3.813" ID 110,984' ~XN Nipple 3.750" ID 111,005' WLEG 3.958" ID I 11,017' Back SIv. I11,01 3' ZXP Liner Top Packer I11,019' 7" Liner Shoe I11,205' Top of Liner approx. 11,700' PBTD 12,913'I 4 1/2" Liner TD 12.6# L-80 IBT Mod. ~ 13,000' I I 2 7/8" liner to be cemented to approx. 400 ft above the top existing perforation at 12,560' leaving TOC approx. 12,160'. 4,000 3,500 3,000 E ~2,500 2,000 1,500 1,000 C-20A ~8,826 5,500 I I I 6,000 6,500 7,000 X distance from Sfc Loc 7,500 IWell Name C-20A I CLOSURE Distance 7,636 ft Az 67 de9 NEW HOLE E/W (X) N/S (Y) Kick Off 6,549 1,732 TD 7,025 2,992 State Plane 670,868 5,963,426 Su~ace Loc 663,843 5,960,434 DLS de~ll00 Tool Face Length Curve 1 - 0 0 1;16 Curve 2 24 -55 20 Curve 4 24 -90 659! Curve 5 9 89 399 Curve 6 9 -89 274 Curve 7 9 90 459 1,9461 Drawn: 7/17/2000 15:51 Plan Name: Case 102 C-20A Vertical Section 0 500 1,000 8500 8550 8600 8650 8700 8750 ~8800 8850 8900 8950 9000 9050 9100 Path Distance (Feet) 1,500 2,000 2,500 Angle @ K,O.= 87 deg MD:12913 3,000 3,500 4,000 Tot Drld:1945 ft 14858 TD Marker Depths {~Orig Wellbore ol ol 8,8481 8,848J~t TVD 8,8681 8,8681ftTVD Kick Off 8,876 ft TVD 12,913 ft MD Deprtr @KO 6,789 ft MD KO Pt 12,913[ MD New Hole 1945I I Total MD 1~ TVD TD 8,8281 Curve t DLS de~lll00 Tool Face Length 116 0; 0 24 -55 24. ~77 24 -90 9 89 9 -89 9 90 Curve 2 20 Curve 3 19 Curve 4 659 Curve 5 399 Curve 6 274 Curve 7 459 1,946 Drawn: 7/17/2000 15:51 Plan Name: Case 102 LU '"r 0 Z · 22.5" 18" 38"I 2 3/8" CT ~ C-20b CT Drilling & Completion BOP 7 1/16" Annular 7 1/16" 5000 psi ] I 7 1/16" Pipe/Slip -~ 2 3/8" I ~ I r--I r--I ~..~ ~_l t--iI ~ 17 ~/-16j' 'x 5:0-00- P' si: ~.~ ~, s,,,~s ~ = ~ 7/~,, 7 1/16" ~ Pipe ~ ~ 2 3/8" 7 1/16" x 5,000 psi I SWAB OR MASTER VALVE · .- ~.~ ,. :~ /., ~.;~,, ;~- STATE OF ALASKA ALASK~' ~'')IL AND GAS CONSERVATION COk SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 774' SNL, 1522' WEL, SEC. 19, T11N, R14E, UPM At top of productive interval 1854' NSL, 4125' EWL, SEC. 17, T11N, R14E, UPM At effective depth 811' NSL, 5069' EWL, SEC. 17, T11N, R14E, UPM At total depth 744' NSL, 5124' EWL, SEC. 17, T11N, R14E, UPM 5. TyPe of well: [] Development [] Exploratory " [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 59.95' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C -20A 9. Permit Number 197-114 10. APl Number 50- 029-20745-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 13001 feet 8940 feet 12914 feet 8936 feet Length 110' 2658' 8957' Size 20 X 30 13-3/8" 9-5/8" 2373' 7" 1987' 4-1/2" Plugs (measured) Junk (measured) Cemented 8 cu yds concrete 4466 cu ft Arctic Set II 1565 cu ft Class 'G', 167 cuft PF 'C' 213 cu ft Class 'G' 258 cu ft Class 'G' Perforation depth: measured 12560'- 12770', 12810'- 12890' true vertical 8931'- 8933', 8932' - 8935' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 11017' ORIGINAL MD TVD BKB 110' 110' 2891' 2660' 899O' 6256' 8832' - 11205' 6153' - 8338' 11013' - 13000' 8150' - 8940' RECEIVED JUL 2 = · 2000 _Alaska 0N & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 4-1/2" HES 'HXO' SSSV at 2212'; Baker 'S-3' packer at 10961' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation August 1, 2000 Date Approved 115. 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas []Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 Signed Mark StanleyI~¥[..'.~ ~ ~,~__ Title CT Ddlling Superintendent Date.(.!. !!I~'~ I ~nd,ionsofApprova,: Noti, Oommi,ion so~en~tive ~ayw,n~-- ' IApproval No. ~00 -- /~ Plug integd~ __ BOP Test Lo~tion clear, ce __ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate H 170953 VENDOR ALl ~SKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET )&~900 CKO&~900C 100. O0 100. O0 HANDLIN~ INST' PH iERRI HUBBLE X46~8 E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. &(elf!liE ] ! OO. OO l OO. OO ~AY H1 :~i,,T'"~,,o~.,,,K'-':o,,,~,~o NO:. :;: .... ~'::7:'0 95 3 ...'::i :?: .. ';{:'::';::i '.".:"!: .A!~:';~I~FILIATE:.OI~ ?i:;;]'. :~.:':~..~: CONSO[:iD~EO ~M~:~BCi~:.AccoU~.;:.;:~: QE~ND. OHIO .;::";' .:'. ;'." · ......... . .. .... '.::~:.:':~s-38..-:-;. .::'-.;:' ..... :OOz 70~53::'::''~ ....... ' 412 AK 99501-3120 ANCHORAGE NOT'i~VALID AFTER 120 DAYS :' ...-:. :': .-. :::'::2 . :i:i. ":i' ...: -.ili~'.':'-::':::'."~. :. : i. .:/ '. '.-' :: : ::::!::' : :.: C-20b Subject: C-20b Date: Fri, 28 Jul 2000 22:44:43 +0100 From: "Stagg, Ted O (ORBIS)" <StaggTO@BP.com> To: '"Tom_Maunder@admin.state.ak. us'" <Tom_Maunder@admin.state.ak. us> CC: "Stanley, Mark J (ANC)" <StanleMJ@BP.com> Tom, As we discussed by phone, our Permit to Drill application for C-20b did not include information on the H2S status of C-20a. North Slope records since 1992 have shown very Iow H2S readings for C Pad with the highest being 38 ppm on C-09. Future Permit applications will include a current H2S measurement. Ted Stagg 1 of 1 7/28/00 2:32 PM WELL PERMIT CHECKLIST FIELD & POOL ~"-~.~. COMPANY ADMINISTRATION 1. Permit fee attached ....................... ~ 2. Lease number appropriate ................... WELL NAM~ ~'-~?_z~Z? PROGRAM: exp. dev.~<'~ reddl~ serv GEOL AREA ? ?~) UNIT# N N ENGINEERING 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 ......... 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... .DATE 14: Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg .... · .... 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage, or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~::~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. wellbore seg ann. disposal para req ON/OFF SHORE N Y GEOLOGY 30. 31. 32. AP_J3R DATE 33. Data presented on potential overpressure zones ....... Y ./'7 Seismic analysis of shallow gas zones. ' Y Seabed condition survey (if.off-shore) ............. ,Y'"' N Contact name/phone for weekly progress reports [exploratory on~l]~Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIG/~nnular COMMISSION: Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02117100) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. · . No special'effort has been made to chronologically organize this category of information. ,o Sner_~v-S'~r 2r!llilc c~-~= Reel Header Service name ............. LiSTPE Date ..................... 22/04/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation N'~T~er ...... O! Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LiSTPE Date ..................... 02/04/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: F~TL: ELEVATION (Fi FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-00124 B. JAHN R. WHITLOW/ C-20B 500292074502 BP Exploration (Alaska), Inc. Sperry Sun 09-APR-02 MWD RUN 2 MWD RUN 3 AK-MW-00124 AK-MW-00124 B. JAHN B. JAHN R. WHITLOW/ J. MCMULLEN/ 19 llN 14E 774 1522 59.95 .OC .0C OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN~ DEPTH (FT) !ST STRING 4.500 13000.0 2ND STRING 3RD STRING PRODUCTION STRING REM~.RKS: i. ALL DEPTHS ARE MEASURED DEPFHS (MD) UNLESS OTHERWISE NOTED. 2 . MWD RUNS=* - 3 ARE DIRECTIONAL WITH NATURAL GA~MA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. G~-2,_~,2~. F~.Y SSRE' LOSSEi EEHiND CASING FROM 12898' HE, 8~-~' SSTV2 ?S ' 3005' MD, 88~' ' SSTVi. ~ G~/,~,2~ F~!' ~SGR! -~c~ ~- A }~DPASS WHILE il{ THE HOLE ....... ,~,=~=~,~= RUN 0l FROM!2898' 8876' 12990' MD, 8881' SSTVi TC OBTAIN DATA ABOVE KiCK OFF POINT. DEPTH SHIFTING / ~R~,~=~, WAIVED BY J WiLLIeS OF PER THE E~IL FROH D. SCNORR OF 12/04/0i. ~D CONSIDERED PDC. THIS WELL DRILLED OUT OF THE 4.5" SHOE FROM C-20A AT 13000' MD, 8604' SSTV ALL ~D LOG HEADER DATA RETAINS THE ORIGINAL DRILLER' S DEPTH ~FERENCES. 7. ~D RUNS 1 - 3 REP~SENT WELL C-20B WITH API 50-029-20745-02. THIS WELL ~ACHED A TOT~ DEPTH OF 15012~ MD, 8824~ SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12898.0 14984.0 ROP 13020.0 15012.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD t 12898.0 13389.5 MWD 2 13390.0 13630.0 MWD 3 13630.5 15012.0 $ # REMARKS: MERGED ,MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data SpecificaTion Block Type ..... 0 Logging DirecTion ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefines Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum ~-~ ficaticn Blosk sub-xype...6 Name Service Crier Unils Size Nsam Re? Ccde Offset Channe' DEPT Fi ' i 68 C ' ROP MW2 FT~H 4 ' 68 4 ~ Name Service Unlz Mln Max Mean Nsam DEPT FT 12898 15012 13955 4229 ROP !,YW? FT/H 0.~! 1889.98 113.91! 3985 GR N~KD AP1 19.6 312.65 63.9542 4173 First Reading For Entire File .......... 12898 Last Reading For Entire File ........... 15012 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Reading 12898 13020 12898 Las~ ReadLng 15012 15012 14984 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCRF~MENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12898.0 13359.0 ROP 13020.0 13389.5 $ LOG HEADER DATA DATE LOGGED: 10-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TiME): Memory TD DRILLER (FT): 13390.0 TOP LOG iNTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLiNATiON (DEG MINIM~JM ANGLE: 88.3 M~XIMUM ANGLE: 95.4 # TOOL STRING .TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ NATURAL GAF/4A PROBE BOREHOLE AND CASING DATA TOOL NUMBER 002 OPEN HSLE 51T a:.: .iN~: ERiiLER'S SASiNS DEPTH :FTi : ~OREHOiE S.ONZ iTZONS HUE TYPE: MUE 2ENSiTY {L~ 'S'. : HU3 VlSSSSiTY ~.S : MUD PH: FLUiE LOSS C3}: RESiSTiViTY (OH~,:i' AT TEMPEPJeTURE fDEGF' MUD AT MEASURED TEMPE~TURE {MT} : uUr AT b~X C=R=~.~= TE~4PE~.TURE: MU2 FiLT~.TE AT MT: MUD CAKE AT MT: NEUTRON TOOL !¢~TRiX: M~TRiX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3. 750 FLC PRO 8.65 .0 i0.O 21500 5.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 t 68 8 3 .C 171.2 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 12898 13389.5 13143.8 984 ROP MWD010 FT/H 16.73 1630.78 118.091 740 GR MWD010 API 19.6 312.65 65.2943 923 First Reading For Entire File .......... 12898 Last Reading For Entire File ........... 13389.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of GeneraTion ....... 02/04/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLiB.003 First Reading 12898 13020 12898 Last Reading 13389.5 13389.5 13359 Physical EOF File Header Service name ............. STSL!B.003 Service Sub Level Name... Version Number ........... !.0.0 Date of Seneration ....... 02/04/09 Maximum Physzca! Record..65535 File Type ................ LC Previous FiLe Name ....... STSLZS.O0~ Co.men5 Recsrd FiLE HEADER FiLE NUMBEP.: Curves and its header data for each bit run in separate files. BiT RUN NUMBER: 2 DEPTH iNCREMENT: FILE VENDOR TOOl 2TDE START DEPTH STOP DEPTH GR !33}9.5 13599.5 ROP 13390.0 13630.0 $ # LOG HEADER DATA DATE LOGGED: il-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 13630.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.5 MAXIMUM ANGLE: 94.6 TOOL STRING (TOP TO. BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER 002 3.750 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): .0 MUD PH: 10.0 MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORREiTION (IN): .0 162.8 .0 .0 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Reccrd Tvue .................. 0 Data Specification Block Type ..... 0 Logging Direr5ion ................. Down Optical log depth units ........... Feet Data Referense Point .............. Undefined Frame Spacin~ ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datuan Specification Block sub-type...0 Name Service Or,er Yr. iss Si-e Nsam Rep Co~e Cffse~ Ckanne! DEPT Fi ROP ~{DC 2 'i FY 'H GR ~WDO20 AFl 4 Name Service Unz~ Hzn Ma>: Mean Nsam DEPT F? 13359.5 13630 13494.8 542 ROP N~DO2C F?/H 9.38 1271.37 111.584 481 GR !~WDC2O AP1 46.18 128.84 ~0.6187 481 First Reading For Entire File .......... 13359.5 Last Reading For Entire File ........... 13630 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Firs~ Reading 13359.5 13390 13359.5 Reading 13632 13635 13599.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13600.0 14984.0 ROP 13630.5 15012.0 $ LOG HEADER DATA DATE LOGGED: 13-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15012.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 83.9 MuAXIMUM ANGLE: 97.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOCL CODE TOOL TYPE NGP ¢ NATURAL GAbgZ~. PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER 033 3.750 ~ROREHOLE CONi iTiONS MUi TYPE: HUE EENS-TY LE/G' : MUD ViSCOSiTY S' : MUE CHLORIDES FPM' : FLUiE LOSS C3 : HUE AT MEASURED TEMPE~TURE (MT' : HUD AT F~.X .... ~ ..... ~ ~_m~,~=.. =N~ TE~4PEF~.TURE: HUD FiLTP~.TE AT MT: ~UD CAKE AT MT: NEUTRON TOOL F~TRiX: M~TRiX DENSITY: HOLE CORRECTION (iN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type,..0 TLC PRO 6.65 .C 8.5 24000 4.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 167.0 .O .O Name Service Unit Min Max Mean Nsam DEPT FT 13600 15012 14306 2825 ROP MWD030 FT/H 0.71 1889.98 113.205 2764 GR MWD030 API 28.5 185.77 62.3498 2769 First Reading For Entire File .......... 13600 Last Reading For Entire File ........... 15012 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/04/09 Maximum. Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Last Reading Reading 13600 15012 13630.5 15012 13600 14984 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/04/09 Origin ................... STS Tape Name ................ UNKNOWN Continua%ion Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. L!S?PE ~/04'~ Da~e ..................... ~ /u~ Origin ................... STS Reel Name ................ UNKNOt{ Continuation N~m~er ...... 0! Nex~ Reel Name ........... UNKNOWN Comments ................. STS LiS Writing Library. Scientific Technzcal Services Physical EOF Physical EOF End Of LIS File ·
