The URL can be used to link to this page

Home My WebLink About205-089Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q~ - ~~ ~ Well History File Identifier Organizing (done) ~,.o,ad iuiiiiiiiiiiuuii Re,~a~~eeaea uumuiiuum RES AN DIGI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ~eyscale Items: ^ Other, NolType: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing III IIII~ItIIII IIfII BY: Maria Date: ~ ~ ~ © Js/ Scanning Preparation ~_ x 30 = ~_ + ~ U =TOTAL PAGES__ L~ / (Count does not include cover sheet) BY: _ _ Maria Date: ~ ~ l ~~ lQ f7 /sl Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: __~~YES NO BY: Maria Date: ~ ( ~q (O ~ /s/ ~, 1 14 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II (II lI ~I I I1II II III ReScanned BY: Maria Date: Js! Comments about this file: a~.,„~~~,~ iuumuuiuuu 10/6/2005 Well History File Cover Page.doc ~~rvE~ • STATE OF ALASKA • ,APR ~ ] AKA OIL AND GAS CONSERVATION COMMISSION rbr;~cTION OR RECOMPLETION REPORT AND LOG 1a. Well Status: II ~ ^ SPLUG ^ Other ®Abandoned ^ Suspended 20AAC 25.105 ZOAAC 2s.11o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 3/12/2010 12. Permit to Drill Number: 205-089 309-433 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 8/17/2005 ~ 13. API Number: 50-029-22422-01-00 4a. Location of Well (Governmental Section): surface: ' ' 7. Date T.D. Reached: 8/22/2005 14. Well Name and Number: PBU E-33A 1598 FNL, 883 FEL, SEC. 06, T11 N, R14E, UM Top of Productive Horizon: 2883' FNL, 3337' FEL, SEC. 06, T11 N, R14E, UM g. KB (tt above MSL): 64,12 GL (ft above MSL): 29.4 15. Field /Pool(s): Prudhoe Ba Field / Prudhoe Ba Y Y Total Depth: 3196' FNL, 4868' FEL, SEC. 06, T11N, R14E, UM 9. Plug Back Depth (MD+TVD): 9704' 8718' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 664099 y- 5975457 Zone- ASP4 10. Total Depth (MD+TVD): 11920' 8958' 16. Property Designation: ADL 028304 TPI: x- 661678 y- 5974120 Zone- ASP4 Total Depth: x- 660156 Y- 5973774 Zone- ASP4 11. SSSV Depth (MD+TVD): None 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and tinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / SGRD / SROP, MGR / CCL / CNL 22. Re-DriIIlLateral Top Window MDlTVD: 10023' 8895' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD -HOLE AMOUNT: CASING Wr. PER FT. GRADE TOP BOTTOM TOP' BOTTOM SIZE ,CEMENTING RECORD PULLED": " 1 H-4 11 1 r ~~ ~ ~ ~ ,~ - / " 47# L- 0 4' 4 4' -1/4" 1 I ' 1' 8404' -1/2" I ' 3-1/2" x 33/16" x 2 8.81# / 6.2# J r 1 3-3/4" x 4-1 /8" 1 " 17' nr la ' 24. Open to production or injection? ^ Yes ®No 25. TuailuG RECOao If Yes, list each interval open (MD+TVD of To & Bottom Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / TVD ; p 4-1/2", 12.6#, L-80 9980' 9737' / 8740' & MD TVD MD TVD 9935' - 8855' 26.' `ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ F, ;~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED A ~} 9775' Set CIBP 9747' - 9751' ubin Punch 9740' Set Cement Retainer, Pump 33 Bbls Class'G' Cmt 9704' 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) Acqu ired? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 12/~p, ONTINUED ON REVERSE Submit Original Only i'SCSDMS APR 0 21010 ~~~'YL ~ y' ~~ •! o '~/.<~~~ 29. GEOLOGIC MARKERS (List all formations and ma encountered): 30. NATION 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. Zone 1 B 10188' 8951' None TDF /Zone 1A 10300' 8998' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~ Signed: Terrie Hubble Title: Drilling Technologist Date: PBU E-33A 205-089 309-433 Prepared ey Name/Number. Terris Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Cody Hinchman, 564-4468 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 • E-33A, Well History (Pre Rig Sidetrack) Date Summary 12/25/2009 WELL S/I ON ARRIVAL. DRIFT W/ 3.70" x 20' DMY WHIPSTOCK & TAG 3.813" PX PLUG Q 9741' SLM / 9761' MD. DRIFT WENT WELL WITH NO PROBLEMS. WELL LEFT S/I, PAD OP NOTIFIED. 1/6/2010 1300/560/0 MIT-T to 1500 (CTD Prep) Bled gas off Tbg for 30 min. No pressure change, Pumped into Tbg w/ 40 bbls crude. 1/7/2010 MIT-T FAILED to 1500 psi. (CTD Prep) Loaded tbg to PX pug body w/ total of 105 bbls crude, 40 bbls diesel. ,Established LLR oof 0.5 BPM ~ 1500 psi for 10 bbls. FWHP=300/500/0 1/26/2010 WELL SHUT IN UPON ARRIVAL. (ELINE: JEWELRY, CIBP, TUBING PUNCH, CEMENT RETAINER). INITIAL T/IA/OA=950/550/0. RIH WITH 22' x 2.125" TOOL STRING. TAG FISH AT 9777' ELMD. LOGGED GR/CCL FROM FISH TO 6460'. BHT ~ 9777' = 192°F. LRS PUMPED 200 BBL CRUDE TO LOAD TUBING PRIOR TO RIH WITH THE CIBP. 1/27/2010 Assist E-line: MIT Tubing 3000 psi PASS. MIT Tubing - Pumped 6.5 bbls crude down tubing to reach test pressure. Tubing lost 160 psi in 15 min's, 60 psi in 2nd 15 min's, for a total loss of 220 psi in 30 min's. Bled back 3 bbls. Rig up to IA and pumped 320 bbls crude down IA through pert to verify circulation ability. Taking returns up TBG and down FL. Pumped 5 bbls neat meth and 11 bbls crude down FL for a FP. PE & Pad-Op notified. E-Line in control of well upon departure. FW P=360/360/500 1/27/2010 RUN 2: RIH WITH CIBP TOOL STRING: OAL = 22.4', MAX OD = 3.562". TAGGED FISH (PLUG BODY) AT 9777'. SET WEATHERFORD 4-1/2" CIBP AT 9775' (MID ELEMENT). TOP OF PLUG LOCATED AT 9774.5'. LRS TESTED PLUG TO 3000 PSI (PLUG PASSED). RUN 3: .PUNCHED 4.5" TUBING FROM 9747 - 9751' WITH 4 SPF, 4' TUBING PUNCH. LRS PUMPED 310 BBL CRUDE DOWN IA WITH RETURN~~DT~FLbVP~LZRE-T~~~NFT~i~~IACULATION, THEN FREEZE PROTECTED THE FLOW LINE. RUN 4: SET 4_1/2_" HALLIBURTON CEMENT RETAINER (MID-ELEMENT) AT 9740', TOP OF RETAINER AT 9739.5'. FINAL T/IA/OA: 500/340/240. JOB COMPLETED, WELL LEFT SHUT-IN. 2/16/2010 MU HALCO stinger, RIH w/ stinger to cement retainer. Stab into retainer, confirm set and pump thru up IA 1:1 returns. Batch mix and pump 33 bbls of 15.8# Class G cement. Circ 32 bbl through retainer into IA, dump 1 bbl above retainer. IA cement level should be 8100'. Total fluid circulated into/out of IA=79.5 bbl. Cleanout to 9735' with Bio. Freeze protect wellbore from 2500'. RDMO Notify DSO. Job Complete. 3/1/2010 WELL SI ON ARRIVAL. DRIFTED TO 9709' SLM W/ 3.70" x 20' DMY WHIPSTOCK W/ NO PROBLEMS. LEFT WELL SI TURNED OVER TO PAD OP. 3/1/2010 WELL SHUT-IN ON ARRIVAL. INITIAL T/IA/OA:450/100/0 PSI. RIG UP E-LINE . RIH WITH WHIPSTOCK TOOL STRING: O,AL = 49.3', MAX OD = 3.625", WEIGHT = 500 PSI 3/2/2010 CONTINUED RIH WITH WHIPSTOCK. SET BAKER-4,5" MONO BORE WHIPSTOCK 178 DEG RIGHT OF HIGH SIDE AT 9704' (TOP OF WHIPSTOCK). TIE INTO GAMMA RAY FROM SLB JEWELY LOG DATED 26-JAN-2010. TWO RA PIP TAGS INSTALLED 9.0' BELOW TOP OF WHIPSTOCK (9713'). FINAL T/IA/OA: 350/100/0 PSI. JOB COMPLETE. 3/3/2010 T/I/0=290/100/0. Temp=Sl. Bleed WHPs to 0 psi (pre CTD). No AL. T FL near surfa~e. IA FL near surface. Bled TP from 290 psi to 0 psi in 2.5 hours (liquid & gas). Bled IAP from 100 psi to 0 psi in 30 min (f-uid). Monitored for 30 min, WHPs unchanged. Final WHPs=O/0/0. Job Complete. 3/5/2010 T/I/O = 40/0/0 Set 4" TWC, P/T tree and torque the tree then pulled the TWC. When torqueing the tubing head and master valve Hang studs it required an addition 3/4 of a turn to meet the required torque specs. We used 1-1 foot ext and tag at 114" and then P/T tree to 4,500 pounds, no loss of psi in a 10 min test. No problems. Page 1 of 1 • • BP EXPLORATION Page 1 Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: REENTER+COMPLETE Start: 3/1/2010 End: 4/30/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2010 00:00 - 04:00 4.00 MOB P PRE 04:00 - 05:30 1.50 MOB P PRE 05:30 - 07:30 2.00 MOB P PRE 07:30 - 10:30 3.00 BOPSU P PRE 10:30 - 12:00 1.50 MOB P PRE 12:00 - 00:00 12.00 BOPSU P PRE 3/11/2010 00:00 - 00:30 0.50 RIGU P PRE 00:30 - 01:30 1.00 RIGU N SFAL PRE 01:30 - 02:00 0.501 RIGU N ~ SFAL ~ PRE 02:00 - 02:20 0.33 RIGU N SFAL PRE 02:20 - 06:00 3.67 RIGU N SFAL PRE 06:00 - 09:30 3.50 RIGU N SFAL PRE 09:30 - 09:45 0.25 RIGU N SFAL PRE 09:45 - 14:00 4.25 RIGU N SFAL PRE 14:00 - 18:30 4.50 RIGU N SFAL PRE 18:30 - 19:00 0.50 RIGU N SFAL PRE 19:00 - 20:30 1.50 RIGU N SFAL PRE 20:30 - 21:20 I 0.831 RIGU I N I SFAL I PRE MOVE RIG FROM C-PAD TO E-PAD. PJSM, SPOT RIG OVER WELL ACCEPT RIG AT 0530. SECURE CELLAR, RU CUTTINGS BOX. INSTALL OUTSIDE STAIRS. PJSM, NU BOPE PJSM, CUT AND SLIP DRILL LINE BEGIN SCHEDULED BOPE TEST. BOP TEST WITNESS WAIVED BY CHUCK SCHEEVE OF AOGCC. TEST ANNULAR, BLIND /SHEARS, UPPER 2-3/8" PIPE / SLIP RAMS, VBR, LOWER 2-3/8 PIPE /SLIP RAMS, CHOKE LINE VALVES, AND BOTH STABBING VALVES. SAFETY MEETING. PJSM FOR PULLING CT BACK TO REEL. PICK UP INJECTOR AND CUT OFF CT CONNECTOR. REMOVE LEGS AND STRIPPER, INSTALL INTERNAL GRAPPLE CONNECTOR. PULL TEST INTERNAL GRAPPLE. PULL CT ACROSS PIPE SHED ROOF, CLAMP IT AT HORSE HEAD. SAFETY MEETING. PJSM FOR LIFTING NEW INJECTOR CHAINS TO RIG FLOOR AND SWAPPING OUT CHAINS. BRING NEW CHAINS UP TO RIG FLOOR. SET INJECTOR ON 12 X 12 SILLS ON THE FLOOR, STRADDLING THE RISER STUMP. LOOSEN AND REMOVE THE LOWER PINS ON THE GUIDE ARCH SUPPORTS. ROLL OLD CHAINS OUT OF INJECTOR AND NEW ONES IN. TAKE GRIPPER BLOCKS OUT OF OLD CHAINS AND INSTALL IN NEW ONES. PJSM TO PULL COILED TUBING ACROSS PIPE SHED. DISCUSS PINCH POINTS, WORKING OVERHEAD AND GOOD COMMUNICATION. BEGIN PULLING COILED TUBING ACROSS TO STAB INTO INJECTOR. MU INJECTOR STRIPPER TO INJECTOR. PREP TO REVERSE CIRCULATE COIL FOR SLACK MANAGEMENT. LINE UP TO REVERSE CIRCULATE THROUGH COIL. CANNOT GET CONTROL OF MUD PUMPS. BEGIN TO TROUBLESHOOT. NO PROBLEM WITH RIG MUD PUMPS. COIL APPEARS TO BE FROZEN. TURN ON ALL HEATERS IN REEL HOUSE. CONTINUE TO LOAD PITS WITH USED GEOVIS SYSTEM. PJSM FOR INSTALLING CT CONNECTOR, CHECK VALVE AND NOZZLE AND RIH. OPEN SSV, INSTALL FUSIBLE CAP. M/U CT CONNECTOR, PULL TEST TO 30K. M/U NOZZLE, CHECK VALVES, STINGER. BHA OAL = 10.5 FT. M/U CT RISER. LINE UP TO PUMP DOWN KILL LINE TO PT CT STRIPPER. PT TO 1500 PSI, GOOD. OPEN WELL. BLEED OFF PRESSURE TO 0. RIH, TAKE RETURNS TO FLOWBACK TANK. HOLD Printed: 3/19/2010 1:31:47 PM • • BP EXPLORATION Page 2 ~- Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: REENTER+COMPLETE Start: 3/1/2010 End: 4/30/2010 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2010 20:30 - 21:20 0.83 RIGU N SFAL PRE 400-500 PSI CIRC PRESSURE ON CT. AT 1650 FT PRESSURE DROPS OFF, ESTABLISH CIRCULATION. 21:20 - 22:20 1.00 RIGU N SFAL PRE PARK AT 1700 FT AND PUMP BOTTOMS UP UNTIL CLEAN FLUID IS SEEN. SHUT DOWN PUMP AND FLOW CHECK WELL 10 MIN, NO FLOW. POOH. 22:20 - 00:00 1.67 RIGU P PRE TAG STRIPPER AND VD NOZZLE AND DBPV. M/U RISER AND LINE UP TO PUMP SLACK BACKWARDS. PUMP BACKWARDS WITH MUD AT 3.9 BPM. POP OFF WELL, RIG UP HYDRAULIC CT CUTTER. CUT 354 FT OF CT TO FIND CABLE. 3/12/2010 00:00 - 01:20 1.33 STWHIP P WEXIT LOAD WINDOW MILL AND MOTOR TO RIG FLOOR. PUT AWAY CT CUTTER. INSTALL CT CONNECTOR, PULL TEST TO 35K, GOOD. 01:20 - 02:20 1.00 STWHIP P WEXIT INSTALL BHI CABLE HEAD. WARM UP CT PERIODICALLY. 02:20 - 03:00 0.67 BOPSU P WEXIT PRESSURE TEST INNER REEL VALVE AND CT CONNECTOR, GOOD. 03:00 - 04:30 1.50 STWHIP P WEXIT INSTALL CHECK VALVES IN UQC. M/U BHA #1 - 3.80" WINDOW MILL + STRING REAMER, MOTOR, 3.50" STABILIZER, 2 JTS PH6, 3" COILTRAK. BHA OAL = 121.52 FT. 04:30 - 06:30 2.00 STWHIP P WEXIT M/U CT RISER. OPEN EDC AND PUMP 1 REEL VOLUME FORWARD. RIH. 06:30 - 07:00 0.50 STWHIP P WEXIT LOG TIE IN FROM 9510'. +11 FEET CORRECTION C~ y ' 07: 0 - 18:0 11.00 TWHIP P WEXIT RIH TO ENGAGE PINCH POINT WHILE PUMPING AT ~7s~ ~ MINIMUM RATE. 1~•3~ TAG AT 9704.6' PUH AND ESTABLISH FREE SPIN OF 2281 PSI AT 2.64 BPM. RIH AND BEGIN TIME MILLING AT 9704.1'. 2.64 BPM 2432 PSI. .26K DHWOB. 9704.7' 2.70/2.56 3058PSI .42k DHWOB 9705.4' 2.69/2.56 2970PSI 1.61K DHWOB 9706.1' 2.71/2.57 3025PSI 2.46K DHWOB 9707.0' 2.70/2.53 3032PSI 3.78K DHWOB 9707.7' 2.70/2.59 3032PSI 4.1K DHWOB INCREASE TIME TO 10 - 12 MINUTES BETWEEN .1' ~ 9708.1' 2.68/2.56 2922PSI 3.73 DHWOB 9708.5' 2.67/2.54 2930PSI 4.01 DHWOB 9709.3' 2.64/2.54 2904PSI 3.94 DHWOB HEAVY METAL SHAVINGS AT SHAKER 9709.8' 2.60/2.47 2878PSI 3.7 DHWOB SLIGHT CEMENT NOTED IN RETURNS 9710.4' 2.61/2.50 2911 PSI 4.54K DHWOB LET WEIGHT MILL OFF 9710.8' 2.59/2.48 2834PS1 3.50K DHWOB 9711.2' 2.59/2.47 2820PS1 3.71K DHWOB 18:00 - 00:00 6.00 STWHIP P WEXIT 9711.7' 2.62/2.52 2845PSI 3.80K DHWOB NO FORMATION YET IN CUTTINGS 9712.2' 2.59/2.46 2780PSI 3.92K DHWOB 9712.6' 2.67/2.53 2988PSI 3.83K DHWOB Printed: 3/19/2010 1:31:47 PM TREE = CIt~ ~~ WELLf•iEAD = F(viC ACTUATOR = BAKER C KB. ELEV = 64.2' BF. ELEV....- 29.4' __ KOP = 10023' Max Angle = u ~ r 1894` Datum MD = 9886' Datum TV D = 8800' SS T 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 3609, ~t11U 1 = 2,377" 10201' 3-3!16;® -7I" 7" SCAB LNR, 26#, L-80 BTGM, ID = 6.180" ~ 9217' TOP OF 7" LNR 9231' ~ 9-5/8" CSG, 47#, L-80 NSCC, ID = 8.681" ~ E-33B 9-5/8" X 7" BKR ZXP LT PKR w /FLEX LOCK LNR HGR, ID = 6.280" TOP OF CEMENT IN IA (02/16/10) 9231' ~-~ 7" BKR LNR HGR, ID ='? 9537' -13-1/2" BTT DEPLOYMENT SLV, ID = 3.00" 9585 7" MARKER JOINT 3-1/2"LNR, 8.81#, L-80 STL, 9654' .0087 bpf, ID = 2.992" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 9704' .0152 bpf, ID = 3.958" 4-1/2" BKR WS w/ 2 RA TAGS @ 9713' (03/02/10) 9704' PERFORATION SUMMARY REF LOG: MEM CNL / GR / CCL ON 03!25/10 ANGLE AT TOP PERF: 87° @ 10250' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10250 - 10950 O 03/26/10 2" 6 11570 - 11770 O 03/26/10 2" 6 11870 - 12000 O 03/26/10 2" 6 12030 - 12368 O 03/26/10 SAFETY~ES: WELL ANGLE> 70° @ 10409' ***4-1 /2' OME TUBING"** 2090' ~--~4-1/2" HES X NIP, ID = 3.813" CAMCO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3498 6504 3497 6495 0 19 KBG-2 KBG-2 DMY DMY BK BK 0 0 09/12/09 09/12/09 9654' -~ 3-1/2" X 3-3/16" XO, ID = 2.786" MILLOUT WINDOW (E-336) 9704' - 9713' \ 10201' 3-3/16" X 2-7/8" XO, ID = 2.377" 3-3/16" LNR, --~ 10201' 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" PBTD 12409' 2-7/8" LNR, 6.4#, L-80 STL, .0058 bpf, ID = 2.441" 12427' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/94 SJA ORIGINAL COMPLETION 08/25/05 NORDIC 1 CTD SIDETRACK (E-33A) 11/15/08 N4ES RWO 03/26/10 NORDIC 1 CTD SIDETRACK (E-336) 03/28/10 PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: E-336 PERMff No: 2091670 API No: 50-029-22422-02 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP Exploration (Alaska) Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~l~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-33A Sundry Number: 309-433 1'~,~ ~ J,~I~ ~ `~ 2~~ 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 letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Chair DATED this ~ day of December, 2009 Encl. (~ , Z~I STATE OF ALASKA ~ ~ ~ ~ 'c~ "" 12 ~~/G9~?3-Df ALASKA AND GAS CONSERVATION COMMIS ~ ~ C ~ ~ 2 9 ~BAN,QoN ~~vd/.vim APPLICATION FOR SUNDRY APPROVAL ,e~,e~~ ~a09/~~ 20 AAC 2s.2so ~~IS~ca Dil & ~a Golts. Commisstln 1. Type of Request: ®Abandon , ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended Well ^ Alter 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: 3, Permit To Drill Number BP Exploration {Alaska) Inc. ®Development ^ Exploratory 205-089' 3. Address: , ^ Service ^ Stratigraphic ~ API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22422-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest Well Name and Number: property line where ownership or landownership changes: PBU E-33A" Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028304 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 1 L PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11920' - 8958' ~ 11860' - 8958' - 9986 & 11708' 9761' Casin Len th Size MD TVD Burst Colla e Structural Conductor 78' 2 1 110' 1490 7 Surface 3574' 13-3/8" 6 60 ' 4930 2270 Intermediate 9390' 9-5l8" 9424' 8533' 6870 4760 Production Liner 1304' 7" 9231' - 10023' 8404' - 8 5' 7240 5410 Liner 1975' 3-1/2", 3-3/16" x 2-7/8" 945' - 11920' 8860' - 895 ' Scab Liner 3 7' 7" ' - 217' 79' - 5' 7 4 10 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plugs: 10400' -11860' 9025' - 8958' 4-1/2", 12.6# L-80 9979' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer (2) Packers and SSSV 9737' / 8740' & MD (ft) and TVD (ft): gg35' / 8855' 12. Attachments: .Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for .Well Status after proposed work: Commencing Operations: January 1, 2010 ^ Oil ^ Gas. ^ WDSPL ^ GSTOR ®Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that th foregoing is true and correct to the best of my knowledge. Contact Ron Philli s, 564-5913 Printed Name J McMu Title Engineering Team Leader Prepared ey NamelNumber Signature Phone 564-4711 Date C 2 ~ (Q Terrie Hubble, 564-4628 Commission Use Onl Condition of approval: Notify Commission so that a representative may witness ~)~. ~~/ Sundry Number: /~ // ,,__,,,,// ^ Plug Integrity 1/9 BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ 3500 ~~ ~di° ~sf` ~ Other: / ,~_ Subsequent Form Required: , ~ - yd APPROVED BY / ~ Zc~ Approved By: COMMISSIONER THE COMMISSION Date / [[ Form 10-403 R~ i~~67ff2000 ~tt ~ 1~ i~ ~ ~ ~ I V ~ I2•ZY•o~ ~~ Submit In Duplicate ,~ ~/~l~ . • • To: Alaska Oil & Gas Conservation Commission ~~~~.~~~ ~ nr From: Ron Phillips ~~ ,~ CTD Engineer ~ ~~~~;'~ Date: December 18, 2009 Re: E-33A Sundry Approval Request Sundry approval is requested for E-33A. Isolation of the existing perforations of E-33A will be with a cement retainer set at 9722 ft and the primary cement job of the E-33B completion. WELL HISTORY/CURRENT STATUS: E-33A is a September 2005 Z1 CST GD producer with 980' Z1 A and 80' Z1 B toe up. The well came online with a high initial gas rate. The well stabilized with a GOR and produced full time until hitting marginal in 9/06. In July 2007, a CIBP was set at 11,708' MD to shut off the Z1 B toe up. This was done in an attempt to shut off gas production that was associated with Z1 B. After the plug was set and the well put back on production, the gas and oil rate showed little change. A possible source of the gas was thought to be from the liner lap. In December 2007, during a routine cycle POP, the initial well test indicated high fluid rates. A sample was taken and confirmed it to be cretaceous water. The well was kept online to prevent further cross flowing until a XX plug was set at 9,986' MD. After securing the well, a CMIT- TxIA was attempted but fullbore was unable to pressure up. A LLR of 5 bpm was established. Though E-33A had little value at the time, it was thought that setting a LTP would shut off a significant amount of the gas production and thus make a viable RWO candidate. In November 2008, the 9-5/8" cretaceous leak was repaired by a RWO. Post RWO, slickline pulled the ball and rod along with the RHC plug body in the XN nipple at 9812' MD. Following this operation, it was discovered that the TTP set at 9917' MD in the old completion was set in an X nipple (3.813" ID), which was below the new completions' XN nipple (3.725" ID). Coil rigged up to the well and milled out the XN nipple to 3.80" in Dec '08. Coil was then forced to jet down to the TTP thru fill and was unable to get to the plug. In continuation of the coil work, in Dec '08 SL bailed for several days before being able to reach the plug. After pulling the p-prong, it took several more days of bailing to get to the plug profile, which slickline was unable to pull w/ braided line. A releasable spear was planted in the plug, which both coil and slickline tried to pull over numerous rig ups. In April '09, coil was finally able to get the plug out of the profile, thru the milled out XN profile, and made it as far as the X nipple profile at 9761' MD. The plug was unable to pass the X nipple profile and after several days of trying jarring on the plug in both directions with no success, coil rigged down and the plug was left in the X nipple at 9761' MD. Well Integrity: As part of pre rig screening, an MIT-IA passed on 9/26/09 to 3000 psi and an MIT-OA passed to 2000 psi. A PPPOT-T passed to 5000 psi on 9/23/09. No calliper was run as this well has brand new chrome tubing from the Nov'08 RWO. • REASON FOR SIDETRACK: Under current operating conditions this well has no remaining value. The PX plug is stuck in the X nipple at 9761 ft. As a result, no further wellwork can be performed and instead the development team has decided on a new CST target from this wellbore. Pre-CTD Drilling Operations to start January 1, 2010 1. O MIT-OA: Pass (2000 psi) on 9/27/09 2. O MIT-IA: Pass (3000psi) on 9/26/09. 3. W Check tubing hanger LDS. 4. W PPPOT-T passed to 5000 psi on 9/23/09 5. O PT tree (MV,SV,WV) 6. E Eline punch tubing from 9727-9735' MD ' 7. E Set cement retainer plug at 9722' MD 8. C Pump 32 bbls cement into IA from 9735 to 8100' MD 9. E Eline set whipstock TOW at 9700' MD 10.0 Bleed gas lift and production flowlines down to zero and blind flange 11.0 Remove well house, level pad s `"'"" 3o5-y33 Rig Sidetrack Operations (Nordic 1): (Scheduled to begin on February 10, 2010) -1 1 " CT Drillin BOPE and test to 250 psi low and 3500 psi high 2. Mill 3.80" dual string window at 9700' MD. 3. MIT IA and cement packer to 3000 psi 4. Drill build/turn section with 4-1/4" bicenter bit, and land well. 5. Drill lateral section to 12,420' MD. 6. Run 3-3/16" X 2-7/8" solid liner w/cementralizers to TD. Place liner top at 9550' MD. 7. Cement liner from TD to TOL with 36 bbls cement. 8. Cleanout and MCNL. 9. Test liner lap to 2000 psi. 10. Perforate 11. Set KB Liner Top Packer if needed. 12. Freeze protect well. 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. Ron Phillips CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble ~'?-D ~ao9-~~~ ~A9 OS~or wt ~( tv. ~~~ ~~c q~~. ~~er/ ~ on CN'. I ~vt (f' A., al Tp~q r r 7hi ~~f c ~~, a~f,~-9-- /~fj~/~ " - TRH ~ (/~ IWC3LH6AD= FbIC ACTLWT~R= BAKBZC KB. ELEV = fi4.7 IBF. ELEV = 29.d' ~KOP= ~ ~~ 1DO23' ~N~x Argle o 98' ~ 11815 C®tu m fuD = 9953' D~tumTVD= 88DD'SS i 13-318' CSG, 72#, L-80, ~ = 12.347' i-i 3609' I' ~caB LNR,. a6#, L-so BTG M ~ = s.180" 9217' TOP OF 7" LNR 9231' 9-518" CSG, 47#, L-80 NSCC, ~ = 8.681" 9424' Minimum ID = 2.441 "` @ 10941' 2-7/8" STL LNR L~.o15}u~ ly' P~~' 4-1/2" 7BG, 12.6#,13CR-60 VAM TOP, 9833' .0152 bpf, ~ = 3.958" TOC H 9945' 7' X 4-112 BKR 5.3 PKR ~ = 3.875' 3-112` BOT Dff~LOY SLEEVE, ID = 3. d-'!Yl* M'CC. Y tUP Yl = 3 R'1'~' tRCNb 4-7 f1" i11t31CN N~'(ML[.-tl.7 (llltl, GJ= S.tAD' (BEHlWD P/PEj 4-112` TBG 12.6#, L-8D .0152 bpf, ~ = 3.958" 3!1 R11 M1Y/ fir6 1'f a ~ WS PERFOPATiDN SIJMNARY REF LOG: ChLlCCFtlGR ON 08/23105 ANGLE AT TOP PERF: 78° (a~ 10400' Pbt~a: R~~ to Roduction OB fa$ tlastotical ~rf data s~zE sPF rrrtfftvAL aanls~ DATE SEE PAGE 2 FOR PF32F BR64KDOWN 4-112' PARK62 WLEG (BBIi1ND PIPS ELM1b Tf LOGO 10!04195 3-112' ti0WC0 X htP, ID = 2.813" 3-112" XX PLUG { 10112108) 3-112" X 3-1/16* XO, C? = 2.786' M ILLOtIT VIIiNDOYY {E-33A} 10003' -11131' 10941' H3-3116"' X 2-718" XO, iD= 2.3 E-33A SAfE7Y IrIpTE5: WELL ANGLE> 70° ~ 10078' *~~a-1rr' c~Ran~ETUSiNCC~* !2" F>~S X N9? ~I = 3.813" i CAMICO GAS LET MAN0~5 r .ools b~. n = 2.80" i PBTD 11 2-7/$" LNR, s.16#, L-BD STL, .U056 bpf, ~ = 2.441" DATE RSV BY DATE FiEI/ BY ODNkuIrfYTS 01104/94 SJA t3RlGINAL COMPLETION 08125/05 NOROIC 1 CTD 11H5M8 N4~ RWO 01/26!09 ?tJNO DRLG DRAFT OORR'cCT1DN5 x/27109 PJC DRAWMGfi.C3RRECTIDNS 03!09109 l~+PJC CI~G D42AFT' CORR6/11DNS WRUOFiDE BAY IMItT' WELL.: E-33A PBtMT No: 2050890 APF Pto: 50029-22422-01 SEC 6, 711N, R14E, 1599' FNL & 883' FEi BP 6c~ae~fon (Ai~ka) ST WD TVD CE"1/ TYPE VLV LATCH PORT DOTE 2 1 3498 6504 3497 6495 0 19 2 8Cr2 OOA+~ SO BK 16 BK 20 12107/06 12/07!06 38$0' H 9-518" X T' 8 KR 2XF' LT FKR w 1FLEX LCD !. C Ltt~t FKaR, ~7 = 62~" 9231' t - jl• BK~t Lr~ tit, m a ? ~ 9585 7' M19ARK62 JOWT 9716' 4-112" tiES X NP, D = 3.813' 973T 7"X4.112" Bf(R S-3 PKR N? = 3.875' 9761' 4-1/2" h1ES X NIP, ID = 3.813' 9812' 4-112" FiE$ xN NIP, 17 = 3.725' 984$' 7" X 4112" (.MdgUE OVERSHOT 9917' 4-1l2.OTLS X N~, ~7 = 3.873" Page 1 of 1 • • Maunder, Thomas E (DOA) From: Reem, David C [ReemDC@BP.com] Sent: Monday, January 26, 2009 12:54 PM To: Maunder, Thomas E (DOA) Subject: RE: E-33A (205-089) ~; ~ ~r~ ~~i~ti~ !~ `r` ~Ju Tom. see below From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 26, 2009 10:04 AM To: Reem, David C; Baca, Hank Cc: Regg, James B (DOA) Subject: E-33A (205-089) Dave and Hank, I am reviewing the 404 for the recent workover on the well and have the following questions. 1. Although a 4-1 /2" WRP plug was set at 9915' and successfully tested to 1000 psi, there are numerous times that fluid losses are reported as follows: a. When the hanger is pulled, circulating losses of 60 bph and static losses of 25 bph are reported. The pre-rig MIT-T tested the functionality of the WRP to isolate the lvishak from the Cretaceous and from our repair casing work. Once the tbg was cut pre-rig, we're open to the Cretaceous with 9.8 ppg brine. Not sure what the Cretaceous is pressured up to at E-33's location but it is safe to say it is well under 9.8 ppg. Thus circulation or any other pumping work involving 9.8 ppg brine resulted in losses to the Cretaceous casing leak. b. 23 bph are reported while LD the tubing. c. 155 bbls are reported lost while circulating after milling tight casing. d. 40 bph losses are reported while reversing after polishing the liner top. Similar to my message on M-38A, what is the validity of the KW fluid barrier when fluid losses occur? 2. MASP for this workover is stated as 3200 psi and according to the regulations a RSRRA arrangement is required. Why were 7" rams not employed? Mistakenly reported as MASP....actually is the estimated bottomhole pressure for the Ivishak...thus MASP should`ve been listed as 2120 psi. Thanks in advance. Tom Maunder, PE AOGCC 1 /26/2009 .~6~ y/off I `~''`~ STATE OF ALASKA A OIL AND GAS CONSERVATION CO SION REP RT OF SUNDRY WELL OPE~TIONS ..~~~ ia~sa~ 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 205-089 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22422-01-00- 7. KB Elevation (ft): ~ 12, 9. Well Name and Number: P BU E-33A' 8. Property Designation: 10. Field /Pool(s): , ADL 028304 ~ Prudhoe Bay Fieki / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11920' - feet true vertical 8958', feet Plugs (measured) 9915', 9986 i~ 11708' Effective depth: measured 11860' - feet Junk (measured) None true vertical 8958' ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 110' 110' 1490 470 Surface 3574' 13-3/8" 3609' 3608' 4930 2270 Intermediate 9390' 9-5/8" 9424' 8533' 6870 4760 Production Liner 1304' 7" 9231' - 10023' 8404' - 8895' 7240 5410 Liner 1975' 3-1/2", 3-3/16" x 2-7/8" 9945' - 11920' 8860' - 8958' Scab Liner 533T 7" 3880' - 9217' 3879' - 8395' 7240 5410 Perforation Depth MD (ft): Below Plugs: 10400' - 11860' Perforation Depth TVD (ft): 9025' - 8958' 4-1/2", 12.6# L-80 9979' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 packer 973T 7" x 4- 1/2"'SAB' packer 9935' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 9850'. Run 7 (26#, L-80, BTC- M) scab liner. Cement w/ 175 bbls Class 'G' w/ Gas-Blok (983 cu ft /847 sx). Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 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 Hank Baca, 564-5444 308-348 Printed Na Sondra Stewman Title Drilling Technologist ' ~ Prepared By Name/Number ~ "fi Sign re Phone 584-5743 Date b Sondra Stewman 56a-4750 2 Form 10-404 Revised 04/2006 i Submit Original Onry M TREE = Y CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 64.2' BF. ELEV = 29.4' KOP = 10023' Max Angle = 98°@11815' Datum MD = 9953' Datum TV D = 8800' SS S NOTES: WELL ANGLE> 70° @ 10078' E -3 3 A ***C OME TUBING"** 2090' ~4-1/2" MES X NIP: ID = 3.813" CAMCO GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347° 3609' Minimum ID = 2.441" @ 10941' 2-718" STL LNR 7" SCAB LNR, 26#, L-80, BTC-M, ID = 7.68" ....9217' TOP OF 7" LNR 9231.' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9424` 4-112" TBG, 12.6#, 13CR, VAM TOP .0152 bpf, ID = 3.958" 4-112" TUBENG STUB (11!14;08) ESTIMATED TOC I-I 9945' ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" 1 3-1/2" XX PLUG (10/12/08) MECHANICAL WS (06-20-05) ~ 10023' RA PIP TAG 10033' ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3498 6504 3497 6495 0 19 KBG- KBG- DCK DMY BEK BK 4 0 11!14/08 11;14108 3880' 9-5/8" x 7-5I8" BKRZXP LT PKR, ID = 6.28„ 97~~ 4-1 /2" NES X NIP: ID = 3.813" 973'T' 7" x 4-1J2" BKR S-3 CR PKR, ID = 3,875„ 9781' 4-1i2" HES X NIP, ID = 3.813" 9812' 4-1i2" HES XN NIP, ID = 3.725" 9833® 4-112°' UNIGtUE OVERSI-10T, ID = 4.654" 9915' 4-1/2" OTIS X NIP, ID = 3.813" 9915' 4-1/2"PXTTP (10/12108) 9933' 4-1/2" SEAL ASSY 9935' 7" X 4-1/2 SAB PKR, ID = 3.875" 9945' BOT DEPLOY SLEEVE, ID = 3.00" 9954' 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND PIPE; 9967' 4-1/2" OTIS XN NIP (MILLED OUT), ID = 3.80" (BEHIND PIPE) 9979' 4-1/2" PARKER WLEG (BEHIND PIPE) 9985' ELMD TT LOGGED 10/04/95 9986' 3-1/2" HOWCO X NIP, ID = 2.813" 10018' 3-1/2" X 3-1/16" XO, ID = 2.867 MILLOUT WINDOW (E-33A) 10023' - 11131' 10941' 3-3/16" X 2-7/8" XO, ID = 2.441" 11708' I--12x18" CIBP ~7" LNR, 26#, L-80, .0383 bpf, ID=6.726" i-j 10535' ~- 4-1/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.953" 11551' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 10104!95 ANGLE AT TOPPERF:78° @ 10400' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10400 - 10740 C 08/24/05 2" 6 10880 - 11230 C 08/24/05 2" 6 11300 - 11320 C 08/24/05 2" 6 11360 - 11630 C 08/24/05 2" 6 11780 - 11860 C 08/24/05 3-3/16" LNR, 6.2#, L-80 TCII, I~ 10941' i .0076 bpf, ID = 2.80" PBTD -~ 11860' ~~ 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11920' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04!94 SJA ORIGINAL COMPLETION 08/25!05 NORDIC 1 CTD 11/15/08 N4ES RWO PRUDHOE BAY UNfT WELL: E-33A PERMfT No: 2050890 API No: 50-029-22422-01 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP Exploration (Alaska) C~ Well History n Well Date Summary E 33A 9/25/2008 T/V0=2330/570/40. Temp=Sl. TBG & IA FL (for FB). No AL. TBG FL @ 9764' (150 bbls). IA FI @ surface. SV , WV=closed. SSV , MV=open.lA,OA=OTG.NOV P E-33A 9/27/2008 T/V0=2330/570/40. Temp=Sl. Bleed Tubing < 500 psi (pre RWO). No AL. TBG FL @ 9764' (150 bbls), Bled TP to production from 2330 psi to 1650 psi in 1.5 hrs. SI bleed._TP increased to 2420 psi in 10 mins~ During TBG bleed IAP increased 30 psi, OAP increased 500 psi. Fbst bleed TBG FL unchanged. Final WHPs=2420/600/540. SV, WV=closed.SSV,MV=open. W,OA=OTG.NOVP. E 33A 10/6/2008 T/V0=2300/600/70, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (1500 psi), bled void to 0 psi. Functioned LDS (2.25) (Ef style), all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min. Bled void to 0 psi. PPPOT-IC: Stung into test port (200 psi), bled void to 0 psi. Functioned LDS (2.5) (ET style), two were tight but moving, all the rest moved freely. Unable to pump through void, single port. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 rrin, bst 0 psi in second 15 min. Bled void to 0 psi. E 33A 10/8/2008 '**WELL SHUT IN ON ARRNAL*** (pull & reset plug) RIG UP SLICKLINE TO PULL TTP & RESET '**JOB CO * E-33A 10/9/2008 ***JOB CONT. FROM 10/8/08*** (secure well) MADE MULTIPLE RUNS BAILING ASPHALTINES FROM 9925' SLM TO 9952' SLM, W/ 2.65" CENT, 10' RECOVERED APPROX 2 GALS. ***WSR CONT ON 10/10/08*** E-33A 10/10/2008 T/V0=2320/640/0 Assist SL as dircted (RWO screen complete, eval poss PC leak) Pump 5 bbls meth, 190 bbls 190* crude for brush & flush. FWHPs=0/640/500 Annulus valves left open. Pad op notified. E-33A 10/10/2008 ***WSR CONT FROM 10/9/08*** (secure w ell) MADE MULTIPLE RUNS W/ 10 x 2-1/2" PUMP BAILER (RECOVERED APPRX 2 1/2 GALS OF ASPHAULTINES) B&F W/LRS (180 BBLS HOT CRUDE) 2.65" GAUGE RING & BRUSH, FOLLOWED BY 2.84" GAUGE RING & BRUSH. TO 9965'SLM. " RAN 3.5 EO. PRONG S/D 9967 SLM, NO MARKS ON EQ PRONG. _RA1~1265" CENT 10' x 2-1/2" PUMP BAILER (RECOVERED 2 CUPS SAND) ***WSR CONT ON 10/11/08*** E-33A 10/11/2008 T/V0=340/620/0 temp=s/i Assist s/I w/Brush-n-flush, load tbg, & MIT T (Eval. poss. PC leak) Pump 2 bbls 60/40 meth spear, 180 bbls 190* crude while SLB brush tbg. Called to otherjob. FWHPs=920/620/420 E-33A 10/11/2008 ***WSR CONT FROM 10/10/08*** (secure w ell) MADE MULTIPLE RUNS W/ 10'x 2-1/2" P. BAILER & 5'x 2-1/4" P.BAILER (SNORKEL BTM) TO XX PLUG @ 9967' SLM. L .5" PLUG 9967'SLM. PACKING AND O-RINGS LOOKED GOOD -PLUG SCALED UP BRUSH & FLUSH W/ 180 BBLS HOT CR E, 3.5" BRUSH & 2.65" GAUGE RING TO 10.000' SLM. SET 3.5" PX PLUG BODY @ 9967'SLM, (4x 3/16" EQ PORTS. 24" OAL), CURRENTLY RUNNING~If W~/ "P' PRONG TO SEf IN PLUG BODY ***WSR CONT ON 10/12/08*** E 33A 10/12/2008 T/V0=120/620/180 Assist SL, MT-T (1000 psi) (RWO screen complete, eval poss PC leak) Pumped 33 bbls crude down tbg. Never pressured up. SLB set another plug -40' higher. Pumped 6.5 bbls crude to pressure up to 1000 psi. TP lost 20 psi in 1st 15 min, 20 psi in 2nd 15 min, 0 psi in 3rd 15 rrin. Annulus valves left open tags hung on master & w ing, pad op notified. FWHPs=100/620/50 E-33A 10/12/2008 ***WSR CONT FROM 10/11/08*** (secure w ell) SET 3-1/2" PX PRONG (a7 9959' SLM (97" OAL. 1.85" OD. 1.75" FN). ATTEMPTED MITT ON 3 1/2~fFA1C~ (SEE LRS WSR). SET 4.5" PX PL ODY & "P" PRONG (97"LNG, 8x 3/16" PORTS, 100# SIP) @ 9893' SLM (9915'MD) MIT-T TO 1000# (PASSED) (SEE IL 1 GGITS ON TOP OF 7TP @ 9915' MD CURRENTLY RUNNI "JUNK CATCHER ***WSR CONT ON 10/13/08*** Print Date: 12/12/2008 Page 1 oft i Well Date Summary E-33A 10/13/2008 ***WSR CONT FROM 10/12/08*** (pre RWO) SET 4 1/2" JUNK CATCHER ~ 9868-'. SLM (3.87" O.D. / 116" OAL /HAS 4 1/2 G FISHING NECK) ***WELL S/I ON DEEP ~ 1 TIFY DSO*** E-33A 10/16/2008 ***WELL SHUT-IN ON ARRNAL*** INITVaL PRESSURES 500/625-0. SSV OPEN. RAN 3.65" CUTTER TO 9849'. TAGGED HIGH AT 9882', CALLED APE TO INFORM, SAID TO CUT TUBING AT 9849'. ALSO FOUND CCL ANOMALY AT 9865'. CUT TUBING AT 9849' TBG PRESSURE IN .RFASLD FROM ~~~ rn 500 PS(. FINAL PRESSURES, 450/600/0. DSO NOTFIED OF WELL STATUS. LEFT SHUT-IN AND SSV OPEN. ***JOB COMPLETE"** E-33A 10/18/2008 T/V0=750/600/0 Temp=Sl Bullhead/Clrc Well (RWO Frep) Bullheaded dow n tbg w/ 2 bbls neat meth followed by 242 bbls 9.8 ppg brine thru cut to PC leak. At 242 bbls aw ay w hp's began to increase. Slowed rate to 2 bpm as TP & VaP increased to 1850/2850 psi. SD pump and monitored. TP & VaP decreased to 900/1800 psi in 5 mins. Attempted to pump at 1 bpm as pressures slowly increased. Called for hardline crew to rig up jumper from Va to casasco. Resumed pumping a total of 900 bbls 9.8 brine followed by 3 bbls diesel dow n tbg thru cut up IA to production. RU to the V~1 and bullheaded 150 bbls of 9.8 ppg brine down IA capped w ith 11 bbls of diesel. Freeze protect flow line w ith 5 bbls of neat methanol and 3 bbls of diesel. Rnal WHPs = Vac/Vac/Vac Valve positions at the time of departure: Swab, Wing = Gosed / SSV, Master, IA, OA =Open. E-33A 10/19/2008 T/V0= 50/40/40 Temp= SI MIT-OA PASSED to 2000 si Pr RWO Pumped 4.5 bbls of diesel dow n OA to reach test pressure. OA lost 70 psi 1st 15 mins and 30 psi 2nd 15 mins for a total loss of 100 psi in the 30 mins. Bled OAP Final WHPs= 50/40/40 DSO notrfied of w ell status and valve positions. Sw ab- closed, Wing-closed, Master-open, Va&OA- open to gauges. E-33A 10/21/2008 T/VO = VAGVAGVAC. Temp = SI. Bleed WHPs to 0 (pre RWO). Circ out hardline rigged up between Va companion & cosasco, SI @ casing valve & hardline. SV, WV shut. SSV, MV open. Va & OA otg. NOVP. E-33A 10/22/2008 T/V0=0/0/0. Set 4" CNV H BPS/. FYe Rig_ E-33A 11/2/2008 T/VO=Vac/0/0. Pull 4-1/8" CNV H BPV thru tree, rig move over well. 1-2' ext. used, tagged @ 98". No problem. E-33A 11/3/2008 T/VO=Vac/0/0. Pull 4-1/8" CNV H TWCthru stack, post BOPtest. RKB=19.75'. 15' ext used, tagged @106". No problems. E-33A 11/15/2008 T/VO = VAGO/0 Pulled 4 1/16" CNV H TWC post 4ES tree test. E-33A 11/16/2008 T/VO 0/0/0 Set 4' ciw bpv used t bar to set on rig 4es w ant good E 33A 11/24/2008 T/V0=0/0/0. Pull 4" CNV H BW thru tree. Fbst Rig. E-33A 12/7/2008 *** WELL S/I ON ARRNAL***(Post RWO) Pt1LLED BALL & ROD FROM 4-1/2" RHC PLUG BODY AT 9.812' MD. PULLED BK-DGLV FROM ST #1 (6,504 MD), & BEK-DCK FROM ST #2 (3,498' MD). SET BK-LGLV AT ST #2 (3,498' MD), & BK-OGLV AT ST #1 (6,504' MD). PULLED EMPTY 4-1 /2" RHC PLUG BODY FROM XN NIPPLE 9,812' MD RAN K. , 3.b`b'rB='+J'DI~"liT JDC & SD @ 9,838 S~ (igh, p-prong 9,915' md) CURRENTLY RIH W/ 3.70" CENT, 2-1/2" JDC TO PULL P-PRONG @ 9,915' MD ***JOB IN PROGRESS, CONTINUED ON 12/8/08 WSR*" E-33A 12/8/2008 ***CONTINUED FROM 12/07/08 WSR***(post rig) UNABLE TO GET PAST 9,840' SLM W/ 3.70" CENT, 2 1/2" JDC (fine metal in RAN 3.60" SWEDGE TO 9.840' SLM UNABLE TO GET PAST (no metal marks RAN 3.67" CENT, 2.25" x 5' LRTO 9,840' SLM (1/2"tsp. metal shavings) MADE HOLE FROM 9 840' TO 9,853' SLM W/ 2.25" x 10' - ver a a d fine metal RAN 3.50" x 10' P-BLR 9, ERPAC BEGAN KNOCKING, CALL MECHANIC OUT THREW ROD ON UNIT POWERPAC, USED MOBILE POWERPAC TO POOH ***WELL S/I ON DEPARTURE, NOTIFIm PAD OPERATOR OF WELL STATUS** NOTE 4-1/2" PX PLUG STILL IN HOLE @ 9,915' MD Print Date: 12/12/2008 Page 2 oft • BP EXPLORATION Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date 'From - To I~ Hours '~ Task Code NPT 11/1/2008 22:00 - 00:00 2.OO~RIGD P 11 /2/2008 00:00 - 06:00 6.00 ~ MOB P 06:00 - 09:00 3.00 ~ RIGU ~ P 09:00 - 11:30 ~ 2.50 ~ KILL ~ P 11:30 - 12:30 I 1.001 KILL I P 12:30 - 13:30 1.00 KILL P 13:30 - 17:30 4.00 KILL P 17:30 - 18:00 0.50 KILL P 18:00 - 18:30 0.50 KILL P 18:30 - 22:30 4.00 KILL P 22:30 - 00:00 1.50 KILL P 11/3/2008 00:00 - 02:30 2.50 BOPSUF~ P 02:30 - 03:30 1.00 BOPSU~{ P 03:30 - 08:30 5.00 ~ BOPSUFj P 08:30 - 09:00 0.50 BOPSUF~P 09:00 - 10:00 1.00 PULL P 10:00 - 11:00 ~ 1.00 ~ PULL ~ P 11:00 - 12:00 ~ 1.00 ~ PULL ~ P 12:00 - 14:00 I 2.001 PULL I P 14:00 - 14:30 ~ 0.50 ~ PULL i P Page 1 of 9 ~ Spud Date: 12/11/1993 Start: 11 /2/2008 End: 11 /15/2008 Rig Release: Rig Number: N1 Phase Description of Operations PRE RDMO of D-29, Scope down derrick and lower, blow down steam and prep units to move. Hold PJSM with Peak and Nabors and pull units off of D-29 and organize on pad for move. PRE Move sub, pipe shed, camp, aux. equip. from D-29 to E-33. Peak truck on pits module broke down on D pad. PRE Spot sub over E-33. Level sub, Spot pipe shed. Raise and scope up derrick while waiting on pits and shop to move from D-29. Spot pits, Hook up electrical, steam. water and mud lines between modules. Set stairs and walkways. Ria spotted at 09:00 hours on 11/2/2008. DECOMP Insta I secondary annulus valve, spot tiger tank, run return line to tiger tank, hook up circulating lines for killiing the well. Take on 110 degree 9.8 ppg brine into the pits. DECOMP R/U DSM lubricator and ressure test to 500 si for 5 minutes. Good test. Pull BPV tubing and IA on a slight Vac. OA = 0 psi. DECOMP o wi all personnel involved. Pressure test return line to tiger tank to 250 psi. Test circulating lines to 3,500 psi. DECOMP Pump down the tubing taking returns out the IA through the choke out to the tiger tank. pumped 700 bbls of 110 degree 9.8 ppg brine at 4 bpm with 490 psi. 15 to 20 bbls of diesel in returns. DECOMP Monitor well, 0 psi on IA, 0 psi on tbg, both IA and tubing DECOMP FMC set TWC with T-b r DECOMP Test T C from above, acuator on tree leaked, called DSM to grease ree. Test TWC from below. pumped 3 BPM C~ 500 psi for 10 charted min ood test . Greased tr from above to 3500 si for 10 charted min. ood test DECOMP M/U TIW an -O to Landing Jt. N/D Tree and Adapter flange - TWC is barrier on tubing side and tubing hanger is barrier on IA DECOMP N/U BOPE DECOMP Weekly safety meeting with night crew. Reviewed incidents from BP and Nabors. Discussed traction devices, STOP card summary. DECOMP Test BOPE to 250 si low 3500 si high hold each test for 5 min on chart use 3.5" and 4.5" testjts. and 3.5" on annular, Test upper and lower kelly valves. No failures. Test waived by Chuck Scheve with AOGCC. Test witnessed by BP WSL and Nabors Tool pusher. Test gas alarms. DECOMP R/D test assemblies. DECOMP R/U DSM lubricator and pressure test to 500 psi. Pull TWC. 0 psi pressure on the tubing. 0 psi on the IA. VD lubricator. DECOMP Hold safety meeting with day crew. Reviewed safety slats and incident list from BP and Nabors. Discussed use of traction devices. Discussed stop cards with crew. DECOMP M/U landing joint with TIW valve. Back out Lock Down Screws and pull hanger to rig floor. Hanger came off seat at 125K, tubin ulled free 4 . Up weight 125K. DECOMP Circulate bottoms up, 5 bpm with 500 psi. Losing 60 bph while, circulatin . DECOMP ow down and R/D circulating lines. Monitor well. Losses ~ 25 BPH Nrmtea: tyveuus aasasHnn • BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: WORKOVER Start: 11/2/2008 End: 11/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 -Date .From - To Hours Task Code'. NPT ~~, Phase I Description of Operations 11/3/2008 14:30 - 17:30 3.00 PULL P DECOMP Pull and UD 4.5" L-80 BTC tubing and spool Control line. Pulled 40 K over ~ 8829'. Recovered 30 Stainless steel bands. Maintain constant hole fill with 9.8 ppq brine, 17:30 - 18:00 0.50 PULL P DECOMP UD Schlumberger control line spooler. 18:00 - 19:00 1.00 PULL P DECOMP Service rig, Check PVT, Derrick inspection. 19:00 - 20:30 1.50 PULL P DECOMP Nabors drug testing in satelite camp. 20:30 - 00:00 3.50 PULL P DECOMP Pull and UD 4.5" L-80 BTC tubing and jewelery. (Static losses ~ 23 BPH) 11/4/2008 00:00 - 02:00 2.00 PULL P DECOMP Pull and UD 4.5" L-80 BTC tubing and jewelery, recovered 245 jts.and 18.95' cutjt. OD 4.75" 1) SSSV 2) GLM's. Joints. # 236-239 bent. (Static losses C~3 23 BPH) 02:00 - 03:00 1.00 PULL P DECOMP Clear and clean rig floor of tubing handling tools. 03:00 - 03:30 0.50 PULL P DECOMP P/U and set wear bushing (8 1/8" ID) 03:30 - 06:00 2.50 FISH P DECOMP M/U BHA #1 1)6"x4 9/16" shoe 2) Wash pipe ext. 1)4 3/4"x3 7/8 ress o tool, wash over boot basket, dbl pin sub, 7" scraper, bit sub, bumper sub, pump out sub, 9) 4 3/4" collars. 06:00 - 15:30 9.50 FISH P DECOMP Held crew change and performed pre-tour checks of PVT system and derrick. RIH with dress-off BHA #1. PU 3-1/2" DP. Worked into top of 7" liner at 9217'. Made intial to at 9731'. 15:30 - 17:30 2.00 FISH P DECOMP PU kelly and established parameters: PU/SO/Rot 161 k/124k/140k; 3 bpm, 580 psi; 180a, 4000 Ib-ft. SO past initial tag point with no resistance. Washed down 3 jts from 9731' to top of stum at 9837' at 5 BPM and 1500 psi. Dressed about 6 inches of stump; shoe at 9850'. 17:30 - 18:00 0.50 FISH P DECOMP Pumped a 30 BBL sweep at 5 BPM and 1500 psi. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Check PVT alarms. Service rig. 18:30 - 20:30 2.00 FISH P DECOMP Continue to circulate at 5 BPM 1360 psi, 740 BBLs pumped. 20:30 - 21:00 0.50 FISH P DECOMP Finished circulating. DP U-tubing. Monitor well. 21:00 - 22:00 1.00 FISH P DECOMP R/U and Rev. Circulate at 6 BPM and 1520 psi. Pumped 236 BBLs; circulated out sand cuttings and ccal?_ 22:00 - 22:30 0.50 FISH P DECOMP Monitored well and verified well was dead. 22:30 - 00:00 1.50 FISH P DECOMP TOH, standing back DP in derrick. 11/5/2008 00:00 - 02:00 2.00 FISH P DECOMP Continue to TOH, standing back DP in derrick. 02:00 - 03:30 1.50 FISH P DECOMP Crew held a PJSM prior to laying down the Dress Off BHA and clean out the boot basket. 03:30 - 05:00 1.50 CASE P TIEB1 Crew held a PJSM prior to picking up and making up the 7" Halliburton 3L RBP to 3 stands of 4-3/4" spiral collars. 05:00 - 06:00 1.00 CASE P TIE61 Run in hole with the 7" RBP and collars on 3-1/2" DP from the derrick. 06:00 - 11:30 5.50 CASE P TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. Continued RIH with 7" RBP on 3-1/2" DP. Worked RBP carefully into 7" liner. Set RBP at 9333' TOFN. 11:30 - 13:30 2.00 CASE P TIEB1 POH 1 stand. Dumped 1150 Ib sand down 3-1/2" DP. Pumped 1 DP volume 9.8 ppg brine at 2 bpm and 180 psi. 13:30 - 14:00 0.50 CASE P TIE61 Allowed sand to fall onto 7" RBP. RIH 1 stand and tagged sand at 9283'. 14:00 - 18:00 4.00 CASE P TIE61 POH with setting tool, standing back 3-1/2" DP. 18:00 - 19:00 1.00 CASE P TIEB1 Crew change. Service rig. Check PVT alarms. Inspect derrick. 19:00 - 19:30 0.50 CASE P TIE61 Finish POOH & stand back 3 1/2 DP & 3 stands of DCs. 19:30 - 20:00 0.50 WHSUR P TIEB1 Break out & UD retreiving tool. P/U running tools & pull Wear Bushing. UD same. 20:00 - 21:00 1.00 CASE P TIE61 Clear & clean rig floor. Hold PJSM prior to next operation. Printed: 12/1/2008 9:43:43 AM • BP EXPLORATION Operations Summary Report Page 3 of 9 ~ Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: WORKOVER Start: 11/2/2008 End: 11/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT ~ Phase. ' Description of Operations 11/5/2008 21:00 - 21:30 0.50 CASE P TIEB1 P/U & M/U 9 5/8" Halliburton RTTS packer on 3 1/2" DP pup. Check operation. 21:30 - 00:00 2.50 CASE P TIEB1 RIH w/ 9 5/8" RTTS packer w/ 3 stands of 4 3/4" DCs & 3 1/2" DP from derrick. RIH 60 stands to 5883' and packer began to take weight, observed 10K ove~ull. Attempted to work through 11/6/2008 00:00 - 03:00 3.00 CASE P TIEB1 03:00 - 04:30 1.50 CASE P TIEB1 04:30 - 06:00 1.50 CASE P TIEB1 06:00 - 08:00 2.00 CASE P TIEB1 08:00 - 10:30 2.50 CASE P TIE61 10:30 - 13:30 3.00 CASE P TIE61 13:30 - 18:00 4.50 FISH P TIEB1 18:00 - 19:00 1.00 FISH P 19:00 - 19:30 0.50 FISH P 19:30 - 23:30 ~ 4.00 ~ FISH ~ P 23:30 - 00:00 0.50 FISH P TIEB1 11/7/2008 00:00 - 01:00 1.00 FISH P TIE61 01:00 - 04:30 3.50 FISH P TIEB1 04:30 - 06:00 1.501 FISH P TIE61 tig t s'~po~,Tottomed out same spot. Called engineer and it was decided to POH and make a bit and scraper run down to the liner top. OH standing back DP in derrick. Lay down 9-5/8" RTTS packer, element is in good condition. Crew held a PJSM prior to picking up and making up BHA #2: 8-1/2" bit, 9-5/8" casing scraper, bit sub, bumper sub, oil jar, (9) 4-3/4" collars. Total BHA length = 303.24' RIH with BHA #2, 8-1/2" bit and scraper assy, on 3-1/2" drill pipe from derrick. Held crew change and performed pre-tour checks of PVT system and derrick. Continued RIH with 8-1/2" bit and scraper BHA #2. At 59 stands in, taaaed at 5884' (same depth as TTS to .Discussed with WO Engr and fishing supervisor; planned for string mill and bull nose. POH with bit and scraper BHA #2, standing back 3-1/2" DP. LD bit and scraper. PU string mill BHA #3: bull nose, upper string mill, XO, bumper sub, oil jar, 9 x DC. RIH with BHA #3 on 59 stands 3-1/2" DP. PU kelly and established parameters: PU/SO/Rot 100k/100k/103k; 100a, 2000 Ib-ft, 63 rpm; 3 bpm, 290 psi. Tagged obstruction at 5884'. Milled with 1k WOB, for ue varying to 150a, 00 Ib- earned & milled to 5889', then fell thru. Worked pipe through tight spot, some drag (1-2K) noted pulling through 5884'. Crew change. Service rig. Inspect derrick. Check PVT alarms. Continue to RIH with string mill BHA #3 on 3-1/2" DP from derrick to 60 6 . Tagge at 6006', set down 50K had 15K TIEB1 TIEB1 PU kelly and established parameters: PU/SO/Rot 104k/104k/102k; 70a, 1200 Ib-ft, 60 rpm; 3 bpm, 310 psi. Tagged obstruction at 6006'. Milled with 2-3k WOB, torque varying to 150a, 3000 Ib-ft. Reamed & milled to 6008" wnrkar pipe through tight spot until clean. Continued to an tagged obstruction at 6124'. Reamed and milled with same parameters from 6124' to 6146'. Worked pipe through tight spot until clean. Continued to RIH and tagged obstruction at 6242'. Reamed and milled with same parame ers from 6242' to 6245'. Worked pipe through tight spot until clean. Continue to RIH on 3-1/2" DP from derrick. Continue to RIH on 3-1/2" DP from derrick and lightly tapped liner top at 9217'. Reverse circulate 40 BBL Hi-Vis sweep. Initial circulating conditions: 6 BPM and 1200 psi. Final circulating conditions: 3 BPM and 360 psi. Lost 155 BBLs during circulation, pumped 814 BBLs total. Recovered scale, rust, and millings. Crew held a PJSM and stood back two stands prior to cutting TIEB1 Printetl: 12/1/2008 9:43:4:f AM ' • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: WORKOVER Start: 11/2/2008 End: 11/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ~ Task Code NPT Phase Description of Operations 11/7/2008 04:30 - 06:00 1.50 FISH P TIEB1 and slipping. Cut and slip 64' of drilling line. 06:00 - 11:30 5.50 FISH P TIEB1 Held crew change and performed pre-tour checks of PVT system and derrick. POH with string mill BHA #3, standing back 3-1/2" DP. LD string mill and bull nose. Very little wear visible on mill; mill OD 8-1/2". Cleared and cleaned rig floor. 11:30 - 16:00 4.50 CASE P TIEB1 PU 9-5/8" RTTS. RIH on 72 stands 3-1/2" DP. Worked RTTS slowly past trouble spots at 5884' - 6245'. Set RTTS at 6998'. 16:00 - 16:30 0.50 CASE P TIEBi RU to pump down DP. Tested below RTTS (down to 7" RBP) to 1000 psi for 10 charted minutes. Unset RTT 16:30 - 18:00 1.50 CASE P TIEB1 POH 32 stands with RTTS. 18:00 - 18:30 0.50 CASE P TIEB1 Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 CASE P TIEB1 Finish pulling up hole w/ DP. Space out RTTS to 4017' 19:00 - 20:30 1.50 CASE P TIEB1 R/U test equip. Set RTTS w/ 20K down weght. P/U & S/O Wts =40K. Pressure up & test casing from 4017' to surface w/ 3500 psi. Tested 30 min, test ood. Monitored OAP Burin test no increase rom 40 psi. (caused by balloning). Bleed off pressure & R/D test equip. Unseat RTTS & allow rubber element to relax. Monitor well. 20:00 - 23:00 3.00 CASE P TIE61 POOH & stand back 40 stands of DP & 3 stands of 4 3/4" DCs. UD RTTS. 23:00 - 00:00 1.00 CASE P TIE61 P/U & M/U BHA #4 t as follows: Polish Mill, Spacer Sub, XO, Top dressing Mill, DP Pup, Bumper Sub, Jars & 9 - 4 3/4" DCs. TL = 309.83'. 11/8/2008 00:00 - 03:00 3.00 CASE P TIEB1 RIH w/ BHA #4 to polish liner receptacle. RIH w/ 95 stands of 3 1/2" DP. P/U 24' DP pup & kelly. 03:00 - 04:00 1.00 CASE P TIEB1 Break circulation & establish polish mill parameters. Polis_ h 6:~f_ liner receptacle from 9217 to 9223' several times. P/U Wt = 146K, t = 4K, Rot Wt = 135K. 3 BPM ~ 490 psi, WOB 2-3K. 55 RPMs. F/Torq = 3500 ft-Ibs, Rot/Torq = 4500 ft-Ibs. 04:00 - 05:00 1.00 CASE P TIEB1 Set back kelly. Space out string & R/U to reverse hole clean. Pump 3 BPM @ 460 psi. losing 2 bbls in 5 min while circulating. blow down & set back kelly. 05:00 - 06:00 1.00 CASE P TIEB1 POOH & stand back 3 1/2" DP. 06:00 - 12:00 6.00 CASE P TIEB1 Held crew change and performed pre-tour checks of PVT equipment and derrick. Continued POH with polish mill BHA #4, standing back 3-1/2" DP. LD BHA #4. 12:00 - 14:00 2.00 CASE P TIEB1 Cleared and cleaned rig floor. RU to run 7" scab liner. 14:00 - 18:00 4.00 CASE P TIE61 Held PJSM. Ran 7" 26# L-80 BTC-Mod scab liner. Used Best-of-Life 2000 thread compound. MU connections to mark. Ran 1 centralizer per joint, and filled liner each 5 joints. RIH w/ 48 jts. 18:00 - 18:30 0.50 CASE P TIEB1 Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 23:30 5.00 CASE P TIEB1 Con't to RIH w/ 7" 26#, L-80 BTC-M scab liner. Ran 1 centralizer per jt. Used Best-O-Life thread compound. Fill liner every 5 jts. Ran total of 132 jts. P/U Wt = 130K, S/O Wt = 125K. 23:30 - 00:00 0.50 CASE P TIEB1 P/U & M/U 7" liner hanger & Packer Assy. Inspected &RIH w/ same. 11/9/2008 00:00 - 00:30 0.50 CASE P TIEB1 R/D 7" liner tools. R/U to P/U & run 4 - 6 1/4" DCs. 00:30 - 04:00 3.50 CASE P TIEB1 P/U &RIH w/ 4 - 6 1/4" DCs. Drift all collars w/ 2.00" drift. M/U X-overs to 4 3/4" DCs. Attempt to drift stands of 4 3/4" DCs, drift hanging up. Break down stands as neccessary & drift 4 Printed: iznvzuos s:a3:a3ann • BP EXPLORATION Operations Summary Report Legal Well Name: E-33 Page 5 of 9 ~ Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: WORKOVER Start: 11/2/2008 End: 11/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To 'Hours Task Code ~ NPT i Phase Description of Operations 11/9/2008 00:30 - 04:00 3.50 CASE P TIEB1 3/4" DCs w/ 2.00" drift. RIH w/ DCs. 04:00 - 06:00 2.00 CASE P TIE61 Change out handling equip &RIH w/ 7" liner on stands of DP. Fill DP every 5 stands. 06:00 - 08:00 2.00 CASE P TIEB1 Held crew change and performed pre-tour checks of PVT system and derrick. Resumed RIH with liner on 37 stands 3-1/2" DP. PU/SO 200k/168k. PU DP pup joints, worked seal stem into 7" tieback receptacle. SO on seal stem o- o wi 08:00 - 10:30 I 2.501 CASE I P 10:30 - 15:00 I 4.501 CEMT I P 15:00 - 17:30 2.50 CEMT P TIEB1 17:30 - 18:00 0.50 CASE P TIEB1 18:00 - 18:30 0.50 CASE P TIE61 18:30 - 19:30 1.00 CASE P TIEB1 19:30 - 20:30 1.00 CASE P TIEB1 20:30 - 21:00 0.50 CASE P TIEB1 21:00 - 23:00 2.00 CASE P TIEB1 23:00 - 00:00 1.00 CASE P TIEB1 11/10/2008 00:00 - 01:00 1.00 CASE P TIEB1 01:00 - 02:30 1.50 BOPSU P TIEB1 02:30 - 03:00 0.50 BOPSU P TIE61 03:00 - 03:30 0.50 BOPSU~ P TIEB1 03:30 - 06:00 2.50 BOPSU P TIEB1 06:00 - 11:00 5.001 BOPSUpP ~ TIE61 wrtn pump pressure. tscu~ az~ r, i vu sauv. RU cementing equipment. Circulated 9.8 ppg brine to warm well. Held PJSM with all cementing personnel. Finished RU to cement 7" scab liner. Tested cementing lines to 5000 psi. Mixed and pumped 175 bbls CI G cement.+additives at 15.8 ppg. Pumped cement slurry at 5.4 bpm with pressure varying from 1350 psi to 580 psi. Released DP wiper dart, saw indication of dart away. Cementing unit displaced cement with 9.8 ppg brine. Varied displacement rate from 5 bpm to 1/2 bpm. Bumped plug with 1800 osi at 227 bbls, about 4 bbls beyond calculated displacement. CIP at 13:20 hrs 11/9/2008. SO to seat seal stem in tieback receptacle. Pressured up to 3000 psi to set liner hanger. SO and pressured up to 4000 psi to set liner top packer. Bled pressure, had about 2 bbls fluid return. Rotated running tool off liner top with 12 RH turns. Pressured up to 1000 psi and PU 7'; saw pressure bleed and circulated 10 bbls 9.8 ppg brine the long way. PU 25', closed annular, and RU to reverse circulate with rig. Reverse circulated at 5 bpm and 1100 psi. Had about 40 bbls contaminated cement in fluid returns. RD cementing equipment. POH with liner running tool, standing back 3-1/2" DP. Begin ND BOPE. Crew change. Inspect derrick, check PVT alarms. Service rig. Finish N/D BOPE. Set back stack. Barriers are as follows: TTI ~ 9915', RBP @ 9333', Lnr Top Pkr C~1 9231' Lnr Top Pkr C~ TIE61 TIEB1 C~ 9161'. alve. N/D & remove existing Tubing Spool. Pull casing Pack off. Prep & Install new Pack off & Tubing spool. Pressure test casing Pack off to 5000 psi for 30 min. tested Good. Held weekly safety meeting with all hands on evening tour. Nipple up BOPE and install test plug. Rigged up the BOPE test equipment and serviced the mud cross. Function tested BOPE prior to BOPE pressure test. Test BOPE, 250/3500 psi for 5 charted minutes per AOGCC regulations and BP policy. Test witness waived by L. Grimaldi, AOGCC at 15:30 hrs 11/8/2008. Held crew change and performed pre-tour checks of PVT system and derrick. Continued testing BOPE to 250 psi low / 3500 psi high per BP policy and AOGCC regulations. Tested VBR with 3-1/2" and 4-1/2" test joints. Tested annular with Nnmea: iznizuus a:a;i:a'sann • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: WORKOVER Start: 11/2/2008 End: 11/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/10/2008 06:00 - 11:00 5.00 BOPSU P TIE61 3-1/2" test joint. Pulled test plug and installed wear ring. 11:00 - 12:00 1.00 FISH P TIEB1 Held weekly safety meeting with day rig crew. Discussed recent ADW incidents, Safety Alerts, and individuals' concerns. 12:00 - 15:30 3.50 FISH P TIEB1 PU drill-out BHA #5: 6-1/8" bit, boot baskets, oil jar, 9 x DC, 15:30 - 17:00 1.50 ~ FISH ~ P ~ ~ TIE61 17:00 - 18:00 1.00 DRILL P TIE61 18:00 - 18:30 0.50 DRILL P TIEB1 18:30 - 20:30 2.00 DRILL P TIEB1 20:30 - 00:00 3.50 DRILL P TIEBi 11/11/2008 00:00 - 01:30 1.50 DRILL P TIEB1 01:30 - 05:00 3.50 DRILL P TIE61 05:00 - 06:00 1.00 DRILL P TIEB1 06:00 - 08:00 2.00 DRILL P TIE61 08:00 - 12:00 4.00 DRILL P TIEB1 12:00 - 13:00 1.00 DRILL P TIEB1 13:00 - 14:00 1.00 FISH P TIEB1 14:00 - 17:00 3.00 FISH P TIEB1 17:00 - 18:00 1.00 FISH P TIEB1 18:00 - 18:30 0.50 FISH P TIEB1 18:30 - 21:30 3.00 FISH P TIEB1 21:30 - 22:00 0.50 FISH P TIEB1 22:00 - 23:00 I 1.001 FISH I P I ITIEBI 23:00 - 00:00 1.00 FISH P TIE61 11/12/2008 00:00 - 03:30 3.50 FISH P TIEB1 03:30 - 05:30 2.00 FISH P TIEB1 05:30 - 09:00 3.50 FISH P TIEB1 POS. RIH on 3-1/2" DP. Tagged cement in 7" liner at 9022', (landing collar at 9120') with 5k Ib. tood back 1 stand and PU 2 singles. RU head pin and circulating line. Tested 7" scab liner to 3500 psi for 30 charted minutes. Drill out cement and float equipment from 9022' to 9044'. Drilling parameters: PU/SO/Rot 148K/120K/130K; 150 amps, 3K Ib-ft Torque, 65 rpm; 4 BPM, 820psi. Tagged cement at 9022' and commenced drilling w/ 2-4K WOB. Held crew change. Check PVT alarms. Inspect derrick. Service rig. Continue to drill out cement from 9044' to 9123 ; 60-75 rpms, 5-10K WOB, 4 BPM, 900 psi. Good cement returns across shakers. Drill the landing collar and plugs 9121-9122' Drill out cement and Float collar 9123 - 9161 ; 60-75 rpms, 5-10K WOB, 4 BPM, 900 psi. Drill out cement stringers from 9161' to 9285'. Ream and clean on all connections. Reverse circulate 40 bbl Hi-Vis sweep; 4 BPM, 1050 psi. Held crew change and performed pre-tour checks of PVT system and derrick. Continued reverse circulating and displacing well to 8.5 ppg seawater. LD 9 singles. POH with drill-out BHA #5, standing back 3-1/2" DP. Clear and clean rig floor. PUMU BHA #7: 5-3/4" RCJB, 2 x 4-3/4" Boot baskets, 7" scraper, it sub, 4-3/4" oil jar, 9 x 4-3/4" drill collars & 3-1/2" POS. RIH w/BHA #7 on 3-1/2" DP from derrick. 65 stands RIH ~ 16:00-hrs. Pick up Kelly. Drop ball & open Reverse circulating Junk Basket. go down & tag fill ~ 9285'. dry drill 2'. Kick in pump 4 BPM ~ 1550 psi. everse down to 9297'. P/u & repeated washing down to 9297'. P/U & set back kelly. Drop Ball/Rod. Shear out Pump Out Sub. Crew change. Service rig. Inspect derrick. Check PVT alarms. POOH & stand back 97 stands of 3 1/2" DP. Stand back DCS. Break out & UD RCJB. Recovered 6 pcs of silver dollar sized aluminum + 1 threaded shard. Emptied boot Baskets & recovered 1 1/2 gal of metal shavings, Shmoo, scale & a few 1/2 dollar sized pcs of metal. SI Blind Rams. R/U test eauip & test liner to 3500 psi. for 30_ min. Tested good. charted same. R/D test equip. M/U Halliburton retreiving tool &RIH on 3 stands of 4 3/4" DCs. RIH with Halliburton retrieving tool and 3 stands of 4-3/4" drill collars and 3-1/2" drill pipe to 9297'. PJSM and cut and slip 84' of drilling line. j Reverse sand off of RBP from 9285' to top of fishing neck ~ Printed: 12/1/2008 9:43:43 AM BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: E -33 Common W ell Name: E -33 Spud Date: 12/11/1993 Event Nam e: WORKO VER Start : 11/2/2008 End: 11/15/2008 Contractor Name: N ORDIC CALIST A Rig Release: Rig Name: N ORDIC 1 Rig Number: N1 Date From - To I Hours Task Code ~I NPT ' Phase Description of Operations 11/12/2008 05:30 - 09:00 3.50 FISH P TIEB1 9333'. Reverse circulated until clean returns. Enaaaed RBP with retrieval tool and r RBP. Worked RBP free. Pulled +40K over string to free up RBP. Reverse circulated bottoms up. No gas in returns. 09:00 - 14:00 5.00 FISH P TIE61 POH w/7" Halco RBP and la down same. 14:00 - 16:00 2.00 FISH N RREP TIEB1 Repair broken drive chain in drawworks. PJSM -Makeup BHA and Running In Hole With Drillpipe. 16:00 - 17:00 1.00 FISH P TIEB1 Make up BHA #7 s follows: 2-3/8" Itco spear, spear ext., XO, XO, 21 s. -7 C DP, XO, 4-3/4" LBS, 4-3/4" oil jar, 9 x 4-3/4" drill collars and 3-1/2" Pump Out Sub. 17:00 - 18:00 1.00 FISH P TIEB1 RIH with BHA #7 on 3-1/2" drill pipe from derrick. 18:00 - 18:30 0.50 FISH P TIE61 Held Crew change. Check PVT alarms. Service rig. Inspect derrick. 18:30 - 21:30 3.00 FISH P TIEB1 Continue to RIH with BHA #7 on 3-1/2" drill pipe from derrick. Tagged fill at 9821' worked i e down to 9826'. 21:30 - 22:30 1.00 FISH P TIEB1 Rig up o circu a e and wash down to 9850'. Pumped 3 BPM, 1320 psi, pressure increased 2200 psi and plugged. Picked up to 9815'. P/U weight 163K. S/O weight 120K. 22:30 - 23:30 1.00 FISH P TIEBi Close the annular preventer and rigged up to reverse circulate. Reversed out sand and scale. Continue to reverse down from 9830' to 9850'. Pumped 3 BPM and pressure ran from 1440 - 1900 psi. Had large amount of sand, scale and metal over 23:30 - 00:00 0.50 FISH P TIEB1 Made a connection and washed down the long way from 9850' to 9885' and tagged the top of the funk catcher. Circulate long way 3 BPM, 1540 psi. 11/13/2008 00:00 - 12:30 12.50 FISH P TIEB1 Latched onto fish and PU to 200K. Catcher stuck. Jarred 3 times, 40K Ibs over. Fish came free on the third hit. PU 10'. Fish moving with 10-20K drag. 12:30 - 01:00 12.50 FISH P TIEB1 Pulled 2 single joints of drill pipe and the fish hung upon the third single. Pulled tight and worked pipe up and down, fish moving. Continue to work fish anri n~dla~l fish nat of tabina stub ~- t 83 '. 01:00 - 03:30 2.50 FISH P TIE61 Rigged up to circulate and pumped a 40 BBL Hi-Vis sweep. Pump 40 BBL sweep followed by 200 BBLs seawater, 4 BPM 1540 psi - incresed to 5 BPM 2450 psi. After 200 BBLs drop ball/rod and open pumpout sub, continue to circulate out sweep. Shear out pump out sub C~ 02:30 w/ 2000 psi. Continue to circulate 6 Bpm, 1700 psi. Pumped 550 bbls, received back a moderate amount of sand, scale, and smoo. 03:30 - 11:30 8.00 FISH P TIEB1 PJSM held with crew, POH and LD 3-1/2" drill pipe. 11:30 - 12:30 1.00 FISH P TIEB1 Break out and lay down BHA #6. Recovered iunk catcher intact. 12:30 - 16:00 3.50 BUNCO RUNCMP Clean and clear rig floor. Rig down 3-1/2" DP handling tools. Rig up 4-1/2" completion handling tools. 16:00 - 16:30 0.50 BUNCO RUNCMP PJSM -Reviewed chrome tubing running and handling procedure with all crew. 16:30 - 18:00 1.50 BUNCO RUNCMP RIH with 4-1/2" com letion jewelry as follows: 7" x 4-1/2" Unique Overshot Guide w/2 sets shear pins, HES "XN" nipple assy., 1 jt. 4-1/2" 12.6#, 13Cr80 tubing, HES "X" Nipple, 7" x 4-1/2" Baker S-3 9Cr packer, HES "X" nipple assy. Baker-Lok'd all connections below packer and made up all connections to 4440 ft-Ibs. optimum makeup torque per Nabors Printetl: 12/1/2008 9:43:43 AM ~ ~ BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: WORKOVER Start: 11/2/2008 End: 11/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date i From - To Hours Task Code NPT Phase Description of Operations 11/13/2008 16:30 - 18:00 1.50 BUNCO RUNCMP torque turn specialist. Driller, Baker packers tech., WSL and toolpusher verified proper placement of RHC-M plug body in XN nipple below packer. 18:00 - 00:00 6.00 BUNCO RUNCMP RIH w/completion BHA on 4-1/2" 12.6#, 13Cr80 tubing making up connections to optimum makeup torque of 4440 ft-Ibs. and using single joint compensator per running order 1 x 1 from pipe shed. Used Jet Lube Seal Guard Thread Compound on all connections. Ran in hole w/ 82 jts. Entered 7" liner 17' in on Jt #91, ...no problem. 11/14/2008 00:00 - 09:00 9.00 BUNCO RUNCMP RIH w/completion BHA on 4-1/2" 12.6#, 13Cr80 tubing making up connections to optimum makeup torque of 4440 ft-Ibs. and using single joint compensator per running order 1 x 1 from pipe shed. Used Jet Lube Seal Guard Thread Compound on all connections. Ran in hole with 173 jts at 05:00. Completed RIH with 229 jts. tbg. at 09:00-hrs. 09:00 - 11:30 2.50 BUNCO RUNCMP Picked up and ran in hole with jt. #230. Tagged top of 4-1/2" tubing stub at 9856'. unable to get Unique overshot guide over stu .Turned string 3/4 turn and attempted to slide over stub with no success. Broke circulation long way at 3.0-bpm ~ 210-psi and eased overshot guide over stub. Applied 25-30K downweight to get over stub and observed both sets of shear pins shearing. Bottomed out on overshot guide no-go and observed pressure increase to -480-psi ensuring full 14' of swallow in overshot guide. Picked up 3', marked jt. at rotary table and layed down jt. #230 and jt. #229. Fluid flow from tubing indicating that IA is heavier than tubing which indicates that there were solids on backside of tubing stub. Allowed fluid to stop flowing. Calculated spaceout and RIH with 4' 4-1/2" 12.6#, 13Cr80 tubing pup, jt. #229, tubing hanger and 3-1/2" DP landing jt. with TIW valve/headpin and circulating line connected. Circulated at 3.0-bpm at 120-psi while landing tubing hanger. Applied 25-30K downweight past slackoff weight to get overhhot guide over stub. FMC wellhead tech ran in lockdown screws. 11:30 - 16:30 5.00 BUNCO RUNCMP Attempted to reverse circulate corrosion inhibited seawater treated with 25 gallons per 100-Bbls. of Nalco EC1124A corrosion inhibitor. At 2.0-bpm rate, circulating pressure increased to limit of 600-psi maximum allowable pressure as recommended by Baker Packer technician. Bled off pressure and attempted to circulate inhibited seawater in the long way with similar results. Backed out lockdown screws. Dulled overshot guide f t bin h n floor and circulated inhibited seawater in the Ion wa at 3.0-b mat 200-psi. Started circulating long way at 14:00-hrs. 16:30 - 17:30 1.00 BUNCO RUNCMP Brea off circulating lines and blow down same. Lay down 3-1/2" DP landing joint and XO. Drop ball & rod. Close blind rams. Rig up test equipment and have PJSM to review packer setting procedure and hazards associated with task. 17:30 - 19:30 2.00 BUNCO RUNCMP Pressure up on tubing to 3500-psi to set packer and pressure test tubing for 30 min. Bled off Tubin ressure to 1500 si & ressure u on annulus to 3500 si, held for 30 min. bled off tubing pressure to 1100 psi & DCK-SV sheared out. Con't to bleed o annulus & tubing pressure to 0 psi. pump down Printed: 12/1/2008 9:43:43 AM BP EXPLORATION Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date "From - To ~ Hours Task Code NPT 11/14/2008 17:30 - 19:30 2.00 BUNCO 19:30 - 20:30 I 1.001 RU 20:30 - 21:00 0.50 BOPSUp P 21:00 - 00:00 I 3.001 BOPSUR P 11/15/2008 100:00 - 02:00 I 2.001 BOPSURP 02:00 - 04:30 2.50 WHSUR P 04:30 - 05:00 0.50 WHSUR P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 09:30 I 3.501 WHSUR I P 09:30 - 10:30 I 1.001 WHSUR I P 10:30 - 11:00 I 0.501 WHSUR P Page9of9~ Spud Date: 12/11 /1993 Start: 11 /2/2008 End: 11 /15/2008 Rig Release: Rig Number: N1 Phase. Description of Operations RUNCMP tubing & thru DCK-SV, 3 BPM C~? 1170 psi. Reverse pump down annulus & thru DCK-SV, 3 BPM ~ 1100 psi. Charted entire setting & testing operation. All testing good. RUNCMP Dry rod TWC i ger profile, Pressure test TWC from above w/ 3500 psi for 10 min. Pressure test TWC from belo RUNCMP Prepare to N/D BOPE. Barriers are as follows: PX plug in tubing C~ 9915', Pkr C~ 9757'. TWC in hanger profile & gate valve on tubing spool. RUNCMP Held a 3 hr safety stand down with all hands. Reviewed latest incidents at 4-ES and 3-ES. Discussed pinch points on rig. Each Hand described and identified pinch points on his routine tasks and steps taken to mitigate the risks. Reviewed and edited the Man-Rider Procedure with input from all hands. RUNCMP N/D BOPE. Barriers are as follows: PX plug in tubing ~ 9915', Pkr ~ 9757'. TWC in hanger profile & gate valve on tubing spool. RUNCMP N/U adapter flange and tree. E-pad operator witnessed and inspected tree orientation. RUNCMP R/U to test hanger packoff and tree. Pressure test tree and hanger packoff to 5000psi RUNCMP Rig up lubricator and test to 500 psi. Pull and lay down TWC valve and rig down the lubricator. RUNCMP MIRU LRS and lines to U-Tube. PJSM -Reviewed freeze protect well with tree installed procedure. P/T lines to 3500-psi. Pumped 150-Bbls. diesel ~ 3.3-bpm ~ 1300-psi down IA taking returns to rig pits. Allowed diesel to U-Tube IA x T until balanced IA x T. RUNCMP FMC wellhead tech dry rod set BPV ensuring proper travel for /o engagement in tubing hanger profile. LRS P!T from below to 1000-psi for 10-charted minutes. RUNCMP RDMO LRS and put away tools. RELEASED RIG AT 11:00-HRS. Printed: 12/1/2008 9:43:43 AM • • ~ ~ ~ ~ ~ ~ ~~ ~ ~. COI~TSERQA ATip CO ~ Ip~ David Reem Engineering Team Leader BP Exploration Alaska Inc. SARAH PAL/N, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE,AIASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 C~ Anchorage, AK 99519-661~i~~~~~ ~ rT ~ ~' 2~~8 5 ~ ~ ~ 1 ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-33A Sundry Number: 308-348 Dear Mr. Reem: 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 letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair s ~-- ~-~ h~ ~' DATED this ~ day of~~~er, 2008 Encl. STATE OF ALASKA ~ - `~ ~' ~ ~ ~ ~ ~ ' ~~ ~- ~ A~ OIL AND GAS CONSERVATION COM~SION ~,~-~, ~ ,r~; ~(j('b? " APPLICATION FOR SUNDRY APPROVAL `" `~ 20 AAC 25280 ,. 9~~~T ~° ~~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time extension ®Alter Casing ' ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 205-089 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22422-07-00 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 E-33A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028304' 64.12' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11920' - 8958'- 11860' - 8958' - 9986 & 11708' None Casin Len th i M TVD B Structural n r 7' 1 ' S rfa 3574' 13-3/8" 3 4 7 In rm fi e 9390' 9-5/ " 4' 6 70 7 Pr i finer 1304' 7" 9231' - 1002 ' 4 ' - 895' 724 Liner 1975' 3-1/2", 3-3/16" x 2-7/8" 9945' - 119 0' 60' - 958' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing Mn (ft): Below Plugs: 10400' - 11860' 9025' - 8958' 4-1/2", 12.6# L-80 998(3' Packers and SSSV Type: 7" x 41/2"'SAB' packer Packers and SSSV MD (ft): 9935' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®~evelopment ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 1, 2008 ®Oil - ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date 9 ZS Q& Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: . Conditions of approval: Notify Commission so that a representative may witness ~) ~ ~~ S ~ S~``~~ ' ,SOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Plug Integrity / ' , f 6 _®~ Other: ~ ' Z~ ~5 ~ ~''~.J~ ~.5~ Subsequent Form Required: ~~ APPROVED BY / / l~ ~ A roved B COMMISSIONER THE COMMISSION Date / 6 / Form 10-403 Revi~ed06/2006 ' } 3 Submit In Duplicate . , °0 ~ ~°_J~,~~~ ~~ ~~~~ ~ ~ 1006 • E-33A Rig Workover (Restore OA/IA integrity) C Scope of Work: Pull 4.5" L-80 completion. Run & cement 7" scab liner to shut off Cretaceous leak. Run 4.5" 13 Cr-80 completion. Engineer: Hank Baca MASP: 3200 psi Well Type: Producer Estimated Start Date: November 1st, 2008 F 1 MIT tubin to 1000 si for 10 minutes to veri XX lu 9986' is holdin . W 2 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e. PPPOT-T & IC. S 3 Dump 10' sluggits on top of plug @ 9986'. Drift 4.5" tubing to 9900' for jet cutter. Set 4.5" junk catcher on to of 3.5" de to ment sleeve 9945' E 4 Jet cut tubing at 9887' if plug holds. Reference tubing tally dated 1/2/94, cut desired to be '/z down first full ~oint above acker F 5 Circulate well with seawater and diesel thru the cut. CMIT T to 1000 psi for 10 minutes to verify TTP intact. 9.625" leak, no need for MIT IA W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test ROPE to 250 psi low/ 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tubing string to the cut. 3. Run 7" RBP and set 9,850. Dump ~50' of sand on RBP. 4. PU 9.625" retrievable packer & RIH to 4000' and test RBP to 1000 psi to verify barrier. Find leak w/ packer to determine scab liner top. 5. Run 7", 26#, L-80 liner tied back from existing 7" liner top @ 9231' to 3850'. Cement same. 6. Test 7" scab liner to 3500 psi for 30 charted minutes. 7. Drill out 7" shoe, and clean out above 7" RBP. 8. Pull 7" RBP. 9. Run 4-'/" 13Cr-80 stacked packer completion 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 12. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. 13. 3.5" XX plug to be pulled after rig is gone. • • by Ge~firy E-33A Rig Wtigrkover (Restore OA/IA integrity) Scope of Work: Pull 5" L-80 completion. Run & cement 7" scab liner to shut off Cretaceous leak. Run 4.5" 13 Cr-80 completi Engineer: Hank Baca MASP: 3200 psi Well Type: Producer Estimated Start Date: Novem r 1st, 2008 F 1 MIT tubin to 1000 si r 10 minutes to verif XX lu C~ 9986' is holdin . W 2 Check the tubing hanger ck down screws for free movement. Completely back out and check each lock down screw for eaka e. PPPOT-T & IC. S 3 Dump 10' sluggits on top of lug ~ 9986'. Drift 4.5" tubing to 9900' for jet cutter. Set 4.5" junk catcher on to of 3.5" de to nt sleeve C~ 9945' E 4 Jet cut tubing at 9887' if plug Ids. Reference tubing tally dated 1/2/94, cut desired to be'/z down first full 'oint above acker F 5 Circulate well with seawater and di el thru the cut. CMIT T to 1000 psi for 10 minutes to verify TTP intact. 9.625" leak, no need for IT IA W 6 Set a BPV in the tubin hap er. O 7 Remove the wellhouse & flow line. Lev the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 00 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the t. 2. Pull and LD tubing string to the cut. 3. Run 7" RBP and set 10,000'. PT RBP to 1000 psi to pr a plug is set. Dump ~50' of sand on RBP. 4. Run 7", 26#, L-80 liner tied back from existing 7" liner top 9231' to 3850'. Cement same. 5. Drill out 7" shoe, and clean out above 7" RBP. Pull 7" RBP. 6. Run 4-'/z" 13Cr-80 stacked packer completion 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 9. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. MO. ~~ C1 ~ ,s.--~....-- ~ ~ ..~ TREE = CW WELLHEAD = FMC ACTUATOR =.. OTIS KB. E1E\/. = 64.2' B~EV = 29.4' KOP = 10023' Max Angle = 98° @ 11815' Datum MD = 9953' Datum N D = 8800' SS ~ E -3 3 Q S NOTES: WELL ANGLE > 70° @ 10078 13-3/8" CSG, 72#, L-80, ID = 12.347" i--i 3609' Minimum ID = 2.441" @ 10941' 2-7/8" STL LNR TOP OF 7" LNR ~ 9231' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9424' ESTIMATED TOC (~ 9945' ~ ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" (~ 9978' 3-1/2" XX PLUG (01/05/08) MECHANICAL WS (06-20-05) N 10023' RA PIP TAG 10033' (7" LNR 26#, L-80, .0383 bpf, ID = 6.726" ~-i 10535' F 4-1/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.953" 11551' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 10/04/95 ANGLE AT TOP PERF: 78° @ 10400' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10400 - 10740 C 08/24/05 2" 6 10880 - 11230 C 08/24/05 2" 6 11300 - 11320 C 08/24/05 2" 6 11360 - 11630 C 08/24/05 2" 6 11780 - 11860 C 08/24/05 (4-1/2" OTIS SSSV LANDING NIP, ID = 3.813" ~ CAMCO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4242 6905 4241 6849 0 40 MMG MMG DMY DMY RK RK 0 0 01 /06/08 01 /06/08 ~ 4-1 /2" OTIS X NIP, ID = 3.813" i 9933' u4-1/2" SEAL ASSY 9935' 7" X 4-1/2 SAB PKR, ID = 3.875" 9945' BOT DEPLOY SLEEV E, ID = 3.00" 9954' 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND PIPE) 9967' 4-1/2" OTIS XN NIP (MILLED OUT), ID = 3.80" (BEHIND PIPE) 9979' 4-1/2" PARKER WLEG (BEHIND PIPE) 9985' ~MD TT LOGGED 10/04/95 9986' 3-1/2" HOWCO X NIP, ID = 2.813" 10018' 3-1/2" X 3-1/16" XO, ID = 2.867 MILLOUT WINDOW (~33A) 10023' - 11131' 10941' 3-3/16" X 2-7/8" XO, ID = 2.441" 11708' 2-7/8" CIBP ~~ (07/04/07) 3-3/16" LNR 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" PBTD - j 11860' ~~ 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11920' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04194 SJA ORIGINAL COMPLETION 07/04/07 LLVSV SET CIBP 08/25/05 NORDIC 1 CTD 01/15/08 DAV/PJC GLV GO (01/06/08) 10/20/04 DAV/TLP GLV GO 01/15/08 DTR/PJC SETXXP(01/05/08) 06/05/05 TLH/TLH 7" LNR DEPTH CORRECTION 05/05/08 JSR/PJC XXP CORRECTION (04/17/08) 06/20/05 RWUPJC BKR WHIPSTOCK 03/05/07 MWS/PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: E-33A PERMfT No: 2050890 API No: 50-029-22422-01 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP Exploration (Alaska) TREE = CNV WELLHEAD = FMC ACTUATOR=,,, OTIS KB. ELEV,= 64.2' BF. ELEV = 29.4' KOP = 10023' Max Angle = 98°@ 11815' Datum MD = 9953' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 4.5" x 7" Baker S-3 chrome packer, 7" scab liner 26#, L-80 -3850`-9231' TOP OF 7" LNR ~ 9231' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9424' 4.5" 12.6# 13Cr-80 tubing ESTIMAT® TOC I~ 9945' E -3 3 A SAFETY NOTES: WELL ANGLE > 70° @ 10078' PROPOSED -2100` 4.5" X nip, 3.813" ID CAMCO GAS LIFT MANDRELS 11 I I ( I I ( I I 4.5" X nip, 3.813" ID ~4.5" X nip, 3.813" ID 4.5" XN nip, 3.725" ID Unique Overshot 9933' 4-1/2" SEAL ASSY 9935' 7" X 4-1/2 SAB PKR, ID = 3.875" 9945' BOT DEPLOY SLEEVE ID = 3.00" 9954' 4-1/2" OTIS X NIP, ID = 3.813" (BEJiIND PIPE 9967' 4-1 /2" OTIS XN NIP (MILLED OUT), ID = 3.80" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" ~ 9978' 9979' ~4-1/2" PARKER WLEG (BEHIND PIPE 9985' ELMD TT LOGGED 10/04/95 9986' 3-1/2" HOWCO X NIP, ID = 2.813" 10018' 3-1/2" X 3-1/16" XO, ID = 2.867 ~ MILLOUT WINDOW (E-33A) 10023' - 11131' ~ (MECHANICAL WS (06-20-05) I RA PIP TAG 10941' H 3-3/16" X 2-7/8" XO, ID = 2.441" 2-7/8" CIBP (07/04/07) 7" LNR 26#, L-80, .0383 bpf, ID = 6.726" ~ 10535' ~- •1/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.953" 11551' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 10/04/95 ANGLE AT TOP PERF: 78° @ 10400' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10400 - 10740 C 08/24/05 2" 6 10880 - 11230 C 08/24/05 2" 6 11300 - 11320 C 08/24/05 2" 6 11360 - 11630 C 08/24!05 2" 6 11780 - 11860 C 08/24/05 3-3116" LNR, 6.2#, L-80 TCII, ( 10941' .0076 bpf, ID = 2.80" PBTD -~ 11860' I~ 2-7/8" LNR 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11920' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/94 SJA ORIGINALCOMPLEfION 07/04/07 LLVSV SETCIBP 08/25/05 NORDIC 1 CTD 01/15/08 DAV/PJC GLV GO (01/06/08) 10/20/04 DAV/TLP GLV GO 01/15/08 DTR/PJC SETXXP(01/05/08) 06/05/05 TLH/7'LH 7" LNR DEPTH CORRECTION 05/05/08 JSR/PJC XXP CORRECTION (04/17/08) 06/20/05 RWUPJC BKR WHIPSTOCK 03/05/07 MWS/PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: E= 33A PERMff No: 2050890 API No: 50-029-22422-01 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP Exploration (Alaska) Page 1 of 2 • • Maunder, Thomas E (DOA From: Maunder, Thomas E (DOA) Sent: Tuesday, September 30, 2008 11:57 AM To: 'Baca, Hank' Subject: RE: E-33A (205-089) Workover Thanks Hank. From: Baca, Hank [mailto:hank.baca@bp.wm] Sent: Tuesday, September 30, 2008 10:39 AM To: Maunder, Thomas E (DOA) Subject: RE: E-33A (205-089J Workover Here you go Tom Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Tuesday, September 30, 2008 8:45 AM To: Baca, Hank Cc: Reem, David C Subject: RE: E-33A (205-089) Workover Hank, 1 would appreciate a revised procedure. Email is fine. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Tuesday, September 30, 2008 8:39 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: E-33A (205-089) Workover Tom, just sloppiness on my part, Sorry about that. 1) I'm planning to RIH with a packer to test the RBP and make sure we know where the leak is. 2) Planning to test the scab just prior to drilling out 3) The XX is in 3.5" so, so it will be pulled after we leave. Do you want me to get you a revised copy? Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 9/30/2008 Page 2 of 2 s • From: Maunder, Thomas E (DOA) [mailto:tam.maunder@alaska.gov] Sent: Monday, September 29, 2008 2:51 PM To: Baca, Hank Cc: Reem, David C Subject: E-33A (205-089) Workover Hank and Dave, I am reviewing the sundry for the planned Workover and have a couple of questions. 1. There is Cretaceous casing leak. In the pre-rig section, step 5, it is stated that an IA pressure test will not be conducted due to the leak. In step 3 of the rig procedure, a 1000 psi pressure test is planned after setting the 7" RBP. Is it expected that this test will pass with the casing leak present? The two steps seem in conflict. 2. After setting the 7" scab liner, when will the pressure tests will be conducted? 3. I presume that the XX plug will be pulled after the rig release. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 9/30/2008 ~: .:. ~ ~~i' ~~ ~~~? DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050890 Well Name/No. PRUDHOE BAY UNIT E-33A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22422-01-00 MD 11920 TVD 8958 Completion Date 8/25/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~~ DATA INFORMATION Types Electric or Other Logs Run: MWD / SGRD / SROP, MGR /CCL !CNL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED D Asc Directional Survey 3F.~D C Lis 13463 Neutron ICED D Lis 13436./` Gamma Ray t 13436 6amnra-Raq ~ 2~~~ ~~ c~~ i a ~ti ICED C Pdf 13888 Gamma Ray `^-1=D C Pdf 13888 Rate of Penetration ~~-ED C Lis 13888 Induction/Resistivity ~og Neutron 1-4 1-4 5 Blu Interval OH / Stan. Stop CH Received Comments 10020 11920 Open 9/26/2005 IIFR 9700 11835 Case 1/17/2006 Memory CNL GR CCL CNL 9415 11887 1/31/2006 GR/ROP 9415 11887 1/31/2006 GR/ROP 8839 8894 5/10/2006 NPG 11-Aug-2005 10046 11920 5/10/2006 ROP NGP 14-Aug-2006 9415 11917 5/10/2006 GR, ROP 9700 11835 Case 1/17/2006 Memory CNL GR CCL CNL Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? -mil-pl-- Analysis `~-f-N" Received? Comments: Log Log Run Scale Media No Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ / N Formation Tops ~ (data taken from Logs Portion of Master Well Data Maint -i DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050890 Well Name/No. PRUDHOE BAY UNIT E-33A MD 11920 ND 8958 Completion Date 8/25/2005 Compliance Reviewed By; __._____ __. _-.____-__-_~__- Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22422-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Date: ~~ 13 5f $'~ WELL LOG TRANSNIITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs E-33A, ao5-o s~ April 27, 2006 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 E-33A: LAS Data & Digital Log Images: 50-029-22422-01 ,aos-o ~ 1 CD Rom r • WELL LOG TRANSMITTAL To: State of Alaska January 23, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 ~b5 -b8q RE: MWD Formation Evaluation Logs: E-33A, AK-MW-3880796 1 LDWG formatted Disc with verification listing. API#: 50-029-22422-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ~ p(p Signed: ~ ovos/os Schlumberger Alaska Data & Consulting Services 2525 Gambelt Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh 3t ~ .... ne ..~:,. NO. 3654 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. 11-06A 10928610 MCNL (Prints & Film sent 01/18105) 12!24/04 1 L3-05 11058540 RST 11/10/05 1 1 G-11A 11084277 RST 07/12/05 1 1 L3-11 11072883 RST 08(09!05 1 1 L2-32 11136742 RST 11/08!05 1 1 E-33A O20Jr"t~ 11075912 MCNL 08/23/05 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Reeeived by~ • STATE OF ALASKA ALASKA O L AND GAS CONSERVATION COMM ..LION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RE~E~"~ SEP 2 6 ~~~ ~~.,~~~ nil R Gas Cons. dam';! 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One P Other 1b. Well Class: A11C~1rf'2gtz ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/25/2005 12. Permit to Drill Number 205-089 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/17/2005 13. API Number 50-029-22422-01-00 4a. Location of Well (Governmental Section): Surface: 1598' FNL 883' FEL SEC T1 06 7. Date T,D. Reached 8/22/2005 14. Well Name and Number: E-33A , , . , 1 N, R14E, UM Top of Productive Horizon: 2883' FNL, 3337' FEL, SEC. 06, T11 N, R14E, UM 8, KB Elevation (ft): 64 12' 15. Field /Pool(s): Prudhoe Bay Field !Prudhoe Bay Pool Total Depth: 3196' FNL, 4868' FEL, SEG. 06, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11860 + 8958 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664099 y- 5975457 Zone- ASP4 10. Total Depth (MD+TVD) 11920 + 8958 Ft 16. Property Designation: ADL 028304 _ __ _ TPI: x- 661678 y- 5974120 Zone- ASP4 Total Depth: x- 660156 Y- 5973774 Zone- ASP4 11. Depth where SSSV set (Nipple) 2090' MD 17. Land Use Permit: 18. Directional Surve Y ®Yes ^ No 19. Water depth, if offshore N!A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD ! SGRD / SROP, MGR / CCL / CNL 2. ASING, LINER AND EMENTING ECORD CASING ETTING EPTH MD ' ETTING EPTH TVD HOLE AMOUNT ' $IZE- WT. PER FT. GRADE OP TTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 32' 110' 32' 110' 30" 280 cu ft Arcticset A rox. 13-3/8" 68# L-80 35' 3609' 35' 3608' 16" 612 cu ft PF 'E', 432 cu ft Class 'G' 9-518" 47# L-80 34' 9424' 34' 8533' 12-1l4" 1639 cu ft Class'G' 7" 26# L-80 9231' 10023' 8404' 8895' 8-112" 332 cu ft Class 'G' s-v2° x 3-3/16• X z-7ra° a.a,a r s.za ~ s.,c~ L-80 9945' 11920' 8860' 8958' 3-3/4" x a-va• 124 cu ft Class 'G' 23. Perforations open to Produc B tt I t l S tion (MD + TV D of Top and " " 24. T UBING RECORD o om n erva , ize and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9980' 9933' MD TVD MD TVD 10400' - 10740' 9025' - 9020' 10880' - 11230' 9024' - 9001' 'Zrj,, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11300' - 11320' 8997' - 8996' 11360' - 11630' 8993' - 8980' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11780' -11860' 8967' - 8958' 2500' Freeze Protect with 25 Bbls McOH 26. PRODUCTION TEST Date First Production: September 5, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 9/13/2005 Hours Tested 4 PRODUCTION FOR TEST PERIOD • OIL-BBL 307 GAS-MCF 4,220 WATER-BBL 4 CHOKE SIZE 96° GAS-OIL RATIO ~ 13,759 Flow Tubing Press. 1,08 Casing Pressure 1,340 CALCULATED 24-HOUR RATE OIL-BBL 1,840 GAS-McF 25,318 WATER-BBL 25 OIL GRAVITY-API (coRR) 26.7 27. GORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Subrrwt core chips; if none, state "none". rl~ _ .. Non .I ~ ~- ~F~._ St"F' °~ ~ 200 'awW ~9 ~ ~' V ~ , ~~ ~: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ ~ ~ ,: r 28. GEOLOGIG MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 B 10188' 8951' None TDF /Zone 1A 10300' 8998' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. // Signed Terrie Hubble ~ Title Technical Assistant Date ~•o~,,io'~~~j E-33A 205-089 Prepared By Name/Number.• Terrie Hubble, 564-4628 Well Number Permit NO. / A rOVal NO. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct welt completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a welt producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information, If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only r~ ~~ BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: E-33 Common W ell Name: E-33 Spud Date: 12/11/1993 Event Nam e: REENTE R+COM PLET E Start : 8!11/2005 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: N1 ~ ~ ! Date I From - To , Hours Task ~, Code NPT ~ Phase I Description of Operations 8/15/2005 00:00 - 06:00 6.00 MOB P PRE Arrive on location 06:00 - 06:30 0.50 MOB P PRE RIG ACCEPTED, back over weN 06:30 - 07:00 0.50 MOB P PRE Spot rig on well 07:00 - 08:30 1.50 MOB P PRE Scope derrick 08:30 - 10:00 1.50 RIGU P PRE NU BOPE 10:00 - 14:30 4.50 RIGU P PRE Service Injector head 14:30 - 21:00 6.50 BOPSU P PRE Test BOPE. Tightenswab valve flange, Grease and re test 2, 6,&11. Didn't isolate which one was leaking. HCR was greased and retested. Test witnessed by Chuck Scheve of AOGCC. 3" manual valve rebuilt and retested per Chuck's instruction. Retest witnessing was waived by Chuck Scheve. 21:00 - 00:00 3.00 BOPSU P PRE Replace 3" manual valve and retest. 8/16/2005 00:00 - 03:30 3.50 BOPSU P PRE Replace 3" inside chokeline valve and retest. 03:30 - 06:00 2.50 RIGU P PRE Pump dart. Vol = 58.2 bbl. Cut 8'. Behead. Test inside reel valve. 06:00 - 07:00 1.00 STMILL P WEX{T PU milling assy. 07:00 - 09:15 2.25 STMILL P WEXIT RIH wl CT and milling assy. Tag up at 10012'. Calculated pinch point of 10029'. 09:15 - 17:30 8.25 STMILL P WEXIT Mill tbg exit window. PU wt- 42K. Mill at 1'/hr, 1200/2200 WOB, 2.55 bpm, 1300/2000 press, 200/300 psi motor work. 17:30 - 20:00 2.50 STMILL P WEXIT Drill 10' of formation..3'/min, 200 psi motor work, 600/800 WOB, 1500/1650 press. Work through and clean window. Prelim. tie-in: TOWS: 10025' TOW: 10029' BOW : 10036'. RIHlPOOH thru WS 4 times: clean all 4 runs. Swap mud over to Flo-pro system. 20:00 - 22:15 2.25 STMILL P WEXIT POOH for BHA change 22:15 - 23:00 0.75 DRILL P PRODi LD milling assembly: LD PH6 for inspection. Problem with little jerks: not biting. Go to power tongs. String mill: 3.79 in. Window mill: 3.76 in. 23:00 - 00:00 1.00 DRILL P PROD1 MU jet BHA and jet stack to clear metal shavings. 8/17J2005 00:00 - 01:00 1.00 DRILL P PROD1 Cut Baker CTC off, NU SLB CTC 01:00 - 02:00 1.00 DRILL P PROD1 PU build BHA #1: HCC bi-center bit 3 degree Xtreme mtr Sperry MWD and orienter. Scribe BHAJMWD: 204!300. 02:00 - 02:30 0.50 DRILL P PROD1 Test orienter: good. 02:30 - 03:00 0.50 DRILL P PROD1 Change pack-off elements on injector. 03:00 - 05:00 2.00 DRILL P PROD1 RIH with build BHA #1 05:00 - 09;00 4.00 DRILL P PROD1 Drill ahead from 10046' to 10105' at 104R. 2.4 bpm, 3100 psi (2900 FS), 1300 WOB, 20'/hr 09:00 - 10:00 1.00 DRILL P PROD1 PU 9458'. Log down. RA tag found at 10033'. No correction. 10:00 - 14:30 4.50 DRILL P PROD1 RIH to bottom. Drill ahead from 10105' to 10236'. 0=2.5, 34003700 press, 2700/3000 WOB, 25!70 'lhr. Orient as needed- TF at 100R 14:30 - 15:00 0.50 DRILL P PROD1 Wiper trip to window. 15:00 - 16:00 1.00 DRILL P PROD1 Orient TF to 70L. Drill ahead from 10236' to 10264'. 0=2.41, 320013500 press, 5700/700 WOB, 43/56'/hr Printed: 8/26/2005 11:39:09 AM BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: E-33 Common W ell Name: E-33 Spud Date: 12/11/1993 Event Nam e: REENTE R+COM PLET E Start : 8/11/2005 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date j From - To ! Hours I Task ~ Code ~ ~ NPT ! Phase I Description of Operations 8/17/2005 16:00 - 16:30 0.50 DRILL P PROD1 PU to window, orient TF to 60L 16:30 - 18:00 1.50 DRILL P PRODi Drill ahead from 10264' to 10345'. Q=2.4, 3400/3600 press, 6200/5600 WOB, 61155 `/hr 18:00 - 18:15 0.25 DRILL P PRODi PU to window and orient TF to 100E 18:15 - 23:30 5.25 DRILL P PROD1 Drill ahead from 10345' to 10451'. 2.5 gpm, 3300/3700 on/off btm press 4000- 5500 Ib WOB Drill/orient time breakdown: 75%/25%. 23:30 - 00:00 0.50 DRILL P PRODi POOH for BHA change. End of build. 10451' MD, 8965.5' TVD, 93 deg. inclination. Length of build: 420' MD. Paint flag: 9800' EOP 8/18/2005 00:00 - 02:15 2.25 DRILL P PROD1 POOH for BHA change. 02:15 - 03:15 1.00 DRILL P PROD1 LD build BHA #1. PU lateral BHA #1. ~ Grade for BHA #1 bit: 4/5/RO/N/X/1 /BT/BHA 03:15 - 03:45 0.50 DRILL N RREP PROD1 Repair solenoid on accumulator. 03:45 -04:15 0.50 DRILL PRODi Test orienter:OK 04:15 - 06:00 1.75 DRILL P PRODi RIH with {ateral BHA #1. 1.2 degree Baker Xtreme mtr 4 1/8" HCC bicenter bit. 06:00 - 06:30 0.50 DRILL P PROD1 Tie into log. +3' correction. 06:30 - 07:00 0.50 DRILL P PROD1 RIH and orient TF to 140R. 07:00 - 08:00 1.00 DRILL P PROD1 Drill ahead from 10450' to 10469'. 0=2.45, 3500 press, 8600 WOB, 29'/hr 08:00 - 09:15 1.25 DRILL P PROD1 PU to window, orient to 170R 09:15 - 10:15 1.00 DRILL P PROD1 Drill ahead from 10469' to 10531'. Q=2.45, 4000 press, 36K PU/ 27 SO, 45'!hr 10:15 - 11:00 0.75 DRILL P PROD1 Orient TF to 41 R 11:00 - 12:30 1.50 DRILL P PROD1 Drill ahead from 10531' to 10600'. 0= 2.5, 3200 press, 36K PUJ 24K SO, 80'/hr 12:30 - 13:30 1.00 DRILL P PROD1 Conduct wiper trip to window, MAD pass logging from 10495' to 10557'. PU to window. RIH to bot. 13:30 - 16:15 2.75 DRILL P PROD1 Orient TF to 90R. Drill ahead from 10600' to 10681'. 0=2.3/2.5, 3200/3500 press, 36PU/20S0, 50/82 '/hr 16:15 - 16:45 0.50 DRILL P PROD1 Orient TF to 83L 16:45 - 18:00 1.25 DRILL P PROD1 Drill ahead from 10681' to . Q=2.55/ 2.7, 3200/3400 press, 40KPU/ 28S0, 70/62 'lhr 18:00 - 19:00 1.00 DRILL P PROD1 POOH to 9982' for short trip. 19:00 - 21:00 2.00 DRILL N RREP PROD1 Add CT inspect hardware to injector. (SLB science project). 21:00 - 00:00 3.00 DRILL P PROD1 Drill lateral per DD and geo. O: 2.5/2.5 gpm. 3200/3350 psi off/on btm pressure PU wt: 46K Ib, SO wt: Drillingl0rient time: 50°1°/50%. 8/19/2005 00:00 - 00:30 0.50 DRILL P PRODi Orienter not working. Not getting clicks. MWD not working. Signal intermitnent. Unable to obtain signal at TD. 00:30 - 03:00 2.50 DRILL N DFAL PROD1 POOH for orienter/MWD problems. 03:00 - 05:30 2.50 DRILL N DFAL PROD1 LD BHA #1. Printed: 872612005 11:39:09 AM • BP EXPLORATION Operations Summary Report Page 3 of 8 Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12/11/1993 Event Name: REENTER+COMPLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date ~'~ From - To 'Hours ~~, Task ~~ Code ! NPT ~~, Phase i Description of Operations 8/19/2005 03:00 - 05:30 2.50 DRILL N DFAL PROD1 Bit: 1/2/BT/S/X10/PN/BHA: 2 nozzles plugged with mtr rubber and shale. PU lateral BHA #2: all new components except CTC. 05:30 - 08:30 3.00 DRILL N DFAL PROD1 RIH. SHT to check orienter. RIH to TD. 08:30 - 14:15 5.75 DRILL P PROD1 Drill ahead from 10830' to 10945. 0=2.6, 3400{4000 press, 40KPU/18KS0, 23!30 yhr. Orient as needed. 14:15 - 14:45 0.50 DRILL P PROD1 Orient TF to 151 L 14:45 - 15:30 0.75 DRILL P PROD1 Drill ahead from 10945 to 10980'. 0=2.45/2.55, 3500/3600 press, 40KPU/16KS0, 28155 '1hr. 15:30 - 16:30 1.00 DRILL P PROD1 Conduct wiper trip to window 16:30 - 17:00 0.50 DRILL P PROD1 Drill ahead from 10980' to 10996'. 0=2.55, 3500 press, 40KPU1 17KS0, 52'!hr 17:00 - 19:30 2.50 DRILL N DFAL PROD1 Developed pinhole in coil. POH to change coil 19:30 - 21:00 1.50 DRILL N DFAL PROD1 LD lateral BHA #2 Bit: 1/1/BU/S/X/0/WT/DTF: Junk slots on gauge reamer completely balled. Cutter condition improved over HCC. 21:00 - 21:45 0.75 DRILL N DFAL PROD1 Displace coil with water chased by methanol. Slowdown coil with N2. 21:45 - 00:00 ~ 2.25 ~ DRILL ~ N ~ DFAL ~ PROD1 ~ Unstab coil, secure coil on reel, breakdown hardline. 8/20!2005 00:00 - 06:00 6.00 DRILL N DFAL PRODi Wait on coil tubing reel to be prepared at SLB shop. 06:00 - 07:30 1.50 DRILL N DFAL PROD1 RU to swap reels. 07:30 - 12:00 4.50 DRILL N DFAL PROD1 Swap reels 12:00 - 14:00 2.00 DRILL N DFAL PROD1 Connect and RU new reel 14:00 - 14:30 0.50 DRILL N DFAL PROD1 RU new CTC on coil 14:30 - 14:45 0.25 DRILL N DFAL PROD1 Pull test CTC to 35K. Held. 14:45 - 15:15 0.50 DRILL N DFAL PROD1 Pump dart to catch coil volume- 52.1 bbls. 15:15 - 15:30 0.25 DRILL N DFAL PRODi Test coil and CTC to 3500. Held. 15:30 - 16:15 0.75 DRILL N DFAL PROD1 PU Lateral BHA #5 16:15 - 16:45 0.50 DRILL N DFAL PRODi Inspect Injector- block packing installed wrong. 16:45 - 17:45 1.00 DRILL N DFAL PROD1 Wait for service hand to bring out new packings 17:45 - 22:30 4.75 DRILL N DFAL PRODi Inspect injector -block packing installed wrong, replace as needed 22:30 - 23:00 0.50 DRILL N DFAL PROD1 MU injector. Test orienter:good. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 RIH to TD. 8/21/2005 00:00 - 00:30 0.50 DRILL N DFAL PROD1 RIH to TD. 00:30 - 01:30 1.00 DRILL N DFAL PROD1 Log up from 10075'. Tie-in and correct +16.5'. 01:30 - 01:45 0.25 DRILL N DEAL PROD1 RIH to 10810'. PU: 40K Ib. SO: 2iK Ib. Oi:45 - 02:00 0.25 DRILL N DFAL PROD1 Orient TF to 120 L 02:00 - 04:30 2.50 DRILL N DFAL PROD1 Ream shale section, working toward TD. PU: 40K Ib. SO: 21 K Ib. 5-15 ft/min. Printed: 8/26/2005 11:39:09 AM • BP EXPLORATION Operations Summary Report Page 4 of 8 Legal Well Name: E-33 Common W ell Name: E-33 Spud Date: 12/11/1993 Event Nam e: REENTE R+COM PLETE Start: 8/11/2005 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~, Hours ' Task i I Code I NPT Phase Description of Operations - - 8/21/2005 02:00 - 04:30 2.50 DRILL N DFAL PRODi Q in/out: 2.512.5 gpm +1-O.i5. Overpull: 0-10K Ib. Max stack: -6K Ib. Pressure on/off btm: 3300 psi/2900 psi. 04:30 - 04:45 0.25 DRILL N DFAL PROD1 MWD not working. Cycling pumps to get it back online. 04:45 - 05:00 0.25 DRILL N DFAL PROD1 Work down to TD. PU: 40K Ib. SO: 21 K Ib. Q in/out: 2.512.5 gpm +/- 0.15. Overpull: 15K Ib. Stack out: -1500 Ib. 05:00 - 06:30 1.50 DRILL P PROD1 Drill ahead. SO: 22K Ib. PU: 41 K Ib. O infout: 2.5/2.5 gpm +/- .15. ROP: 40 ftlhr. 06:30 - 08:00 1.50 DRILL P i PROD1 Drill ahead from 10995' to i 1130'. Q=2.4512.55, 3400/3600 press, 41 KPU/20KS0, 60!120 '/hr. 08:00 - 09:45 1.75 DRILL P PROD1 Conduct wiper to window. 8K overpull (max pull 62K). Shale problems. 09:45 - 10:30 0.75 DRILL P PROD1 Work through and backream shale several times from 10740' to 10880', pump 5 bbl sweep (flo-vis). Overpull problems (62K max) and stalling problems (4500 max} 10:30 - 14:00 3.50 DRILL P PROD1 Orient to 90R. Drill ahead from 1 i 130' to 11260'. 0=2.6/2.45, 3500/3700 press, 40KPU/17KS0, 60/100'/hr. 14:00 - 15:45 1.75 DRILL P PROD1 Conduct wiper trip to window. No problems through shale (10740' to 10880'). Log up and tie in. +6' correction. 15:45 - 16:00 0.25 DRILL P PROD1 Orient to 90R 16:00 - 19:30 3.50 DRILL P PROD1 Directionally drill f/ 11260' to 11400'. 0=2.52.6, 3400!3800 press, 40KPU/17KS0, 35'/hr. Swapped mud on the fly. 19:30 - 20:30 1.00 DRILL P PROD1 Wiper trip to 10650'. PU wt: 4iK Ib. SO wt: 22K Ib. Overpull up to +f 7K Ib. Orient on way down to 30L. Orient to 105E at 11400'. 20:30 - 21:00 0.50 DRILL P PROD1 Directionally drill f/ 11400'-11441'. PU wt: 42K SO wt: 23K Ib. Q: 2.7/2.7 gpm +/- 0.15 Add 5 gal. of flo-vis per circulation to help w/ new mud shear-thinning. Overpull: +10K Ib. ROP: 82 ft/hr. 21:00 - 21:30 0.50 DRILL P PROD1 Orient around to 90L. 21:30 - 00:00 2.50 DRILL P PROD1 Directionally drill f/ 1 1,441' - 11570' PU wt: 42K Ib. SO wt: 22K Ib. O: 2.55!2.60 gpm +/- 0.10. Pressure on/off btm: 3000 psi/3450 psi. ROP: 51.6 ft/hr. ~ TF: 45L-90L. Printed: 8/26/2005 11:39:09 AM BP EXPLORATION Operations Summary Report Page 5 of 8 Legal Well Name: E-33 Common Well Name: E-33 Spud Date: 12!1111993 Event Name: REENTER+COM PLET E Start: 8/11/2005 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 1 Rig Number: N1 Date ~~` From - To ~~, Hours! Task j Code ; NPT ~~ Phase I Description of Operations ~ 8(2212005 00:00 - 00:20 -1 - 0.33 DRILL --- ~ P _--- - --- ----- ------- -- - -- _ PRODi Drill fl 11570'-11586'. ROP: 53.5 ftihr. 00:20 - 01:20 1.00 DRILL P PROD1 Wiper trip to 9930`. No hole problems. 01:20 - 01:50 0.50 DRILL P PRODi Log up fl 10080'. Tie-in to RA tag: +2'. 01:50 - 02:35 0.75 DRILL P PRODi RIH to TD. Minor hitch at 10820'. 02:35 - 03:20 0.75 DRILL P PRODi Orient to 75L TF. Reactive torque. 03:20 - 06:30 3.17 DRILL P PROD1 Drilt f/ 11586' - 11730'. PU: 42K ib. SO: 21 K Ib. Pressure on/off btm: 3000/3400 psi. ROP: 58' ft/hr. Drilllorient time: 80% / 20% 06:30 - 08:30 2.00 DRILL P PROD1 Conduct wiper trip to window. No hole problems. Function test ~ rams while in casing- working. RIH. 08:30 - 10:30 DRILL 2.00 P PROD1 Drill ahead from i 1730' to 11875'. 0=2.55/2.6, 3400/3600 press, 40KPU18KS0, 75!120 '/hr 10:30 - 13:00 2.50 DRILL P PROD1 Conduct wiper while waiting for orders from town. Orders recieved at 11:30 for another 40' polygon drilling extension. Continue wiper, log up and tie in. +4' correction. 13:00 - 13:30 0.50 DRILL P PRODi Finish drilling ahead to 11920' TD. 13:30 - 18:00 4.50 DRILL P PRODi Conduct wiper trip, clean out shale section from 10740' to 10880'. No problems. Circulate hole clean. POOH laying in 75 bbl finer pill. 18:00 - 21:00 3.00 DRILL P PRODi LD BHA. Prepare rig for running liner. 21:00 - 21;45 0.75 CASE P RUNPRD Safety meeting for running liner. Found out no XO for 3.5"x2 3/S" on rig in case of well control. Called BOT and had one brought out prior to running 3.5" 21:45 - 22:45 1.00 CASE P RUNPRD RIH w! liner per liner tally. Very slow, brakes not letting blocks descend quickly. 22:45 - 23:00 0.25 CASE N RREP RUNPRD Work on brakes. No success, brake blocks too big/not seated. 23:00 - 23:40 0.67 CASE P RUNPRD Fill 2 718" pipe with water. 23:40 - 00:00 0.33 CASE P RUNPRD MU LSL &RIH. 8!2312005 00:00 - 01:00 1.00 CASE P RUNPRD RIH w/ Liner. Slow due to drawworks brakes. 01;00 - 01:30 0.50 CASE P RUNPRD RU injector. 01:30 - 05:00 3.50 CASE P RUNPRD RIH: White flag at 8000' EOP. Worked through shales f/ 10815'-10845', f/ 10909-10920' (+21 K Ib overpull), f/ 11500' - 11639' (varied overpull to +20K Ib, stacking negative wt). PU to 11500', work back through to TD. Uncorrected depth reading 11911.8. 05:00 - 05:30 0.50 CASE P RUNPRD Pump 518" ball. Pressure up to 2800 psi. Verify release (20K Ib drop in hook load). 05:30 - 07:30 2.00 CASE P RUNPRD Swap well to 2% KCI 07:30 - 07:45 0.25 CEMT P RUNPRD RU cmt'ers. Printed: 8/26/2005 71:39:09 AM • BP EXPLORATION Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To I Hours '~ Task ;Code 8/23J2005 07:45 - 09:15 1.50 CEMT P 09:15 - 09:30 0.25 CEMT P 09:30 - 10:30 1.00 CEMT P Start: 8/11 /2005 Rig Release: Rig Number: N1 Page 6 of 8 Spud Date: 12/11/1993 End: NPT Phase Description of Operations - --- ----'' ------------------ RUNPRD Conduct safety meeting wlcrews RUNPRD Run fluid in lines, PT lines to 4000. RUNPRD Pump cement job: Pump 21 bbls at 2.712.6 at 1700 psi Zero MM, clear lines Pump 30 bbl bio Displace with 34.4 bbls KCI Bump LWP with 52.5 bbls (total) at 3400 psi shear Bump plug at 64.4 bbls Pressure up to 2500-held. No flow. Unsting 10:30 - 12:30 2.00 CEMT P RUNPRD POOH 12:30 - 13:15 0.75 EVAL N WAIT LOWERI Wait on SLB loggers. Work on drawworks. 13:15 - 14:45 1.50 EVAL P LOWERI RU SLB loggers. Work on drawworks. 14:45 - 15:00 0.25 EVAL P LOWERI Safety meeting w/ SLB loggers. 15:00 - 15:30 0.50 EVAL P LOWERI PU logging BHA #1. 15:30 - 17:00 1.50 EVAL P LOWERI TIH w! CSH. 17;00 - 17:30 0.50 EVAL P LOWERI MU injector. 17:30 - 18:15 0.75 EVAL N WAIT LOWERI Wait on XO from BOT. 5 pitch x 2 318 reg. 18:15 - 19:30 1.25 EVAL P LOWERI Finish stabbing injector. Setup loggers at surface. RIH w/ coil. 19:30 - 20:30 1.00 EVAL P LOWERI Continue RIH logging BHA#6 on CT to 9500'. 20:30 - 00:00 3.50 CEMT N WAIT RUNPRD W. O. Cement in UCA to reach 500psi compressive strength. 8!2412005 00:00 - 00:15 0.25 EVAL P LOWERI RIH logging BHA#6 on to 9700'. 00:15 - 01:45 1.50 EVAL P LOWERI Log down @ 30fpm from 9700'. Reciprocate 2x across LSL sub @ 1.5bpm. Start pumping down 150kcps Flo-Pro pert pill. Continue logging down to PBTD tagged 3x @ 11876'. 01:45 - 02:25 0.67 EVAL P LOWERI Log up C~3 60fpm from PBTD to 9700' while laying-in 150kcps pert pill in liner. 02:25 - 03:45 1.33 EVAL P LOWERI POOH logging/cleanout BHA#6. 03:45 - 04:15 0.50 EVAL P LOWERI PJSM & RU for UD & R/B CSH. 04:15 - 05:00 0.75 EVAL P LOWERI R!B 31 stands & UD 2 jts of 1-114" CSH. 05:00 - 05;15 0.25 EVAL P LOWERI PJSM for UD SWS MCNUCCUGR logging tool. 05:15 - 05:45 0.50 EVAL P LOW ER1 UD SWS MCNUCCUGR logging tool, motor & mill. Check log data quality - OK. 05:45 - 06:00 0.25 CLEAN P LOWERI M!U swizz{e stick. Stab injector & jet BOP stack. 06:00 - 09:30 3.50 CASE P PROD1 Liner lap test #1: 2000 psi starting pressure 1700 psi after 30 mins. Wait on co. man to finish morning call. Liner lap test #2: 2100 psi shut-in pressure. 1725 psi after 30 mins. Set-back injector, load pert guns into pipe shed. 09:30 - 12:00 2.50 PERFO N WAIT LOWERI Wait on town team to evaluate logs. From log data, PBTD Printed: 812612005 11:39:09 AM • BP EXPLORATION Page 7 of S Operations Summary Report Legal Well Name: E-33 Common Well Name: E-33 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date '~, From - To I Hours ~~ Task ~, Code ~, 8/24/2005 09:30 - 12:00 2.50 12:00 - 15:00 3.001 PERFOB~N WAIT LOWERI PERFO 15:00 - 15:15 0.25 PERFOB~ P LOWERI 15:15 - 18:30 3.25 PERFO P LOWERI 18:30- 19:30 1.00 PERFO P LOWERI 19:30 - 21:45 2.25 PERFO P LOWERI 21:45 - 22:00 I 0.251 PERFOBI P I I LOW ER1 22:00 - 22:10 i 0.171 PERFOBI P I I LOW ER1 22:10 - 22:30 I 0.331 PERFOBI P I I LOW ER1 22:30 - 23:10 I 0.671 PERFOBI P I I LOWERI 23:10 - 23:25 0.25 PERFO P LOWERI 23:25 - 00:00 0.58 PERFO P LOWERI 00:00 - 00:30 0.50 PERFO P LOWERI 00:30 - 01:00 I 0.50{ PERFOBI P f I LOWERI 01:00 - 01:30 0.50 PERFO P LOWERI 01:30 - 01:45 0.25 PERFO P LOWERI 01:45 - 02:00 0.25 PERFO P LOWERI 02:00 - 08:00 6.00 PERFO P LOWERI 08:00 - 08:15 0.25 PERFO N WAIT LOW ER1 08:15 - 08:30 0.25 PERFO N WAIT LOWERI 08:30 - 09:30 I 1.001 WHSUR P ~ POST 09:30 - 10:45 1.25 WHSUR P POST 10:45 - 12:00 1.25 WHSUR P POST Spud Date: 12!11/1993 Start: 8!1112005 End: Rig Release: Rig Number: N1 NPT ~~ Phase Description of Operations 11860' & TOL = 9944'. Wait on SLB to build new 10' pert pup per ANC orders. R/U safety jt & prep to M/U perf guns. Safety meeting with SLB perf crew. M/U 70jts of 2" HSD 6spf 2006PJ guns & blanks with CBF firing head. M/U 10 doubles of 1-1/4" CSH tbg. M!U injector. RIH with perforating BHA#7 circ perf pill @ min rate. Wt check above Inr. RIH into Inr @ 50fpm. Observe SLB electronic counter freeze-up. Add BHA length (2116.2') to mechanical depth counter (8058') & reset CTD to 10174.2'. Continue RIH & tag PBTD @ 11890' (14' deeper than was previously tagged with the logginglcleanout BHA#6). Review CTD PBTD with ANC & get OK to perf as per the CNL PBTD. Pull to P/U wt & correct CTD to 11860' (PBTD as per MCNL log). PUH to ball drop postion @ 11840'. R/U sonogram detector to choke manifold for shot detection. Pump 15bb1 perf pill ahead. Load 1/2" steel ball. Blow baH into CT with 15bbls perf pill behind. Position guns for btm shot @ 11860'. Chase ball @ 2.05bpm/1840psi. Slow to 1.3bpm/880psi @ 40bbls. Ball on seat after 42.5bbls away. Ramp up to 3200psi & observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 10400' - 10740', 10880' - 11230', 11300' - 11320', 11360' - 11630' & 11780' - 11860'. POOH with perf gun BHA @ 50fpm pumping down the CT @ 1.5bpm1800psi. POOH to 9650'. Trip data indicate Obbls loss/gain while POOH to TOL. SID pump &flowcheck well for i 5 mins -well stable. POOH with perf gun BHA @ 85fpm pumping down the CT @ 1.5bpm/550psi. Continue POOH with perf gun BHA @ 85fpm pumping down the CT @ 1.5bpm/500psi. Trip data indicate Obbls lossfgain while POOH from TOL to surface, OOH. SLB electronic counter reading 2112' - 4' off the BHA length of 2116'. S!D pump &flowcheck well for 30 mins -well stable. Meanwhile held PJSM for R!B 1-114" CSH. SIB injector. UD MHAs & R/B 10 stds of 1-114" CSH tbg. R/U to UD perf guns. PJSM for LD perf guns. UD 70 jts of perf guns & blanks. RU Baker Oil Tools for liner top packer. RD Baker Oil Tools per town reorders. Per discussion with Asset engineer, no LTP is necessary at this time. BOT sent back into town. RU injector. Stab injector on well. RIH with nozzle to freeze protect. Pump McOH. Pump 25 bbl. Begin POOH to 500'. Stop wait for McOH across shakers. Printed: 8/26/2005 11:39:09 AM Printed: 8126!2005 11:39:09 AM Halliburton Sperry-Sun North Slope Alaska BPXA E-33A Job No. AKMW3880796, Surveyed: 22 August, 2005 Survey Report 19 September, 2005 Your Ref.• API 500292242201 Surface Coordinates: 5975457.26 N, 664098.99E (70° 20' 21.3807" N, 148° 40' 06.0414" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 64.15ft above Mean Sea Level 5~~1"~1"~'1a~-~UI"1 i9RiLLINCa S~Ftv~c~s Survey Refsvy4655 A Hailiburton Company • r Halliburton Sperry-Sun Survey Report for E-33A Your Ref.• API 500292242201 Job No. AKMW3880796, Surveyed: 22 August, 2005 North Slope Alaska Measured Depth (ft) 10020.13 10023.00 10046.29 10078.03 10112.82 10142.61 10172.74 10202.12 10232.66 10262.61 10292.65 10323.72 10355.68 10384.80 10418.51 10448.64 10480.91 10510.88 10540.75 10571.55 10602.06 10633.39 10663.69 10694.54 10726.59 True Sub-Sea Vertical Local Coordinates Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 66.910 239.770 8829.77 8893.92 1337.77 S 2218.84 W 67.170 239.870 8830.89 8895.04 1339.10 S 2221.13 W 69.960 240.000 8839.40 8903.55 1349.96 S 2239.89 W 73.650 256.000 8849.36 8913.51 1361.17 S 2267.75 W 73.560 273.200 8859.25 8923.40 1364.30 S 2300.83 W 69.430 287.970 8868.75 8932.90 1359.17 S 2328.51 W 64.950 294.330 8880.44 8944.59 1349.18 S 2354.40 W 64.250 306.810 8893.08 8957.23 1335.73 S 2377.19 W 64.420 315.600 8906.33 8970.48 1317.62 S 2397.87 W 65.040 304.350 8919.15 8983.30 1300.26 S 2418.59 W 68.990 293.450 8930.91 8995.06 1286.96 S 2442.76 W 74.180 284.130 8940.74 9004.89 1277.51 S 2470.64 W 73.210 273.760 8949.73 9013.88 1272.74 S 2500.89 W 75.320 262.330 8957.65 9021.80 1273.71 S 2528.84 W 82.350 247.740 8964.21 9028.36 1282.27 S 2560.67 W 94.830 242.300 8964.95 9029.10 1294.97 S 2587.91 W 95.270 249.680 8962.11 9026.26 1308.04 S 2617.25 W 91.140 251.260 8960.43 9024.58 1318.04 S 2645.44 W 86.660 256.360 8961.01 9025.16 1326.36 S 2674.11 W 92.200 259.700 8961.31 9025.46 1332.74 S 2704.22 W 93.510 266.730 8959.79 9023.94 1336.34 S 2734.46 W 93.690 271.300 8957.82 9021.97 1336.88 S 2765.71 W 91.580 280.620 8956.43 9020.58 1333.74 S 2795.78 W 89.210 277.800 8956.21 9020.36 1328.80 S 2826.23 W 90.000 270.770 8956.44 9020.59 1326.41 S 2858.17 W 10758.67 91.580 10789.92 86.220 10819.08 86.840 10850.44 88.940 10880.46 91.670 10910.42 96.060 10940.68 96.770 10970.54 94.390 11002.08 92.280 11034.52 92.990 Global Coordinates Northings Eastings (ft) (ft) 5974071.25 N 661909 .96 E 5974069.87 N 661907 .70 E 5974058.60 N 661889 .18 E 5974046.79 N 661861 .58 E 5974042.93 N 661828 .57 E 5974047.46 N 661800 .79 E 5974056.87 N 661774 .68 E 5974069.83 N 661751 .60 E 5974087.48 N 661730 .53 E 5974104.38 N 661709 .44 E 5974117.15 N 661684 .98 E 5974125.98 N 661656 .91 E 5974130.09 N 661626 .56 E 5974128.51 N 661598 .63 E 5974119.25 N 661567. 00 E 5974105.97 N 661540 .04 E 5974092.26 N 661510. 99 E 5974081.64 N 661483 .03 E 5974072.69 N 661454 .55 E 5974065.65 N 661424. 59 E 5974061.39 N 661394 .43 E 5974060.17 N 661363 .20 E 5974062.65 N 661333 .07 E 5974066.92 N 661302 .52 E 5974068.62 N 661270 .53 E Dogleg Vertical Rate Section Comment (°/100ft) 2556.82 Tie On Point 9.607 2559.44 Window Point 11.991 2580.89 49.254 2610.92 47.416 2642.80 48.993 2666.60 24.481 2686.93 38.431 2703.11 25.944 2715.59 34.021 2728.39 35.882 2745.90 32.987 2768.28 31.286 2794.61 38.462 2820.93 47.276 2853.66 45.168 2883.66 22.821 2915.76 14.751 2945.65 22.720 2975.35 21.001 3005.69 23.410 3035.10 14.569 3064.33 31.504 3091.08 11.940 3117.52 22.072 3146.30 265 .500 8955. 99 9020 .14 1327. 45 S 2890.22 W 5974066.87 N 661238 .52E 17. 148 3176.44 263 .040 8956. 59 9020 .74 1330. 57 S 2921.29 W 5974063.07 N 661207 .52E 18. 870 3206.46 256 .890 8958. 36 9022 .51 1335. 64 S 2949.94 W 5974057.38 N 661178. 99E 21. 159 3234.94 251 .440 8959. 51 9023 .66 1344. 19 S 2980.07 W 5974048.17 N 661149 .05E 18. 612 3266.10 250 .560 8959. 36 9023 .51 1353 .96 S 3008.46 W 5974037.78 N 661120 .89E 9. 555 3296.08 251 .960 8957. 34 9021 .49 1363. 56 S 3036.75 W 5974027.56 N 661092 .81E 15. 376 3325.92 245 .640 8953. 95 9018 .10 1374. 43 S 3064.78 W 5974016.08 N 661065 .03E 20. 887 3355.97 245 .110 8951. 05 9015 .20 1386. 81 S 3091.79 W 5974003.11 N 661038. 29E 8. 164 3385.65 241 .940 8949. 21 9013 .36 1400. 85 S 3119.97 W 5973988.47 N 661010 .43E 12. 059 3417.03 239 .660 8947. 72 9011 .87 1416. 66 S 3148.25 W 5973972.04 N 660982 .49E 7. 354 3449.16 BPXA • 19 September, 2005 - 9:50 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for E-33A Your Ref: API 500292242201 Job No. AKMW3880796, Surveyed: 22 August 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11070.83 92.720 243.000 8945.91 9010.06 1434.05 S 3180.07 W 5973953.95 N 660951.07E 9.217 3485.16 11100.77 93.160 247.570 8944.38 9008.53 1446.55 S 3207.22 W 5973940.86 N 660924.19E 15.314 3515.01 11136.10 94.660 252.670 8941.97 9006.12 1458.53 S 3240.36 W 5973928.16 N 660891.33E 15.014 3550.23 11166.02 93.430 254.600 8939.85 9004.00 1466.94 S 3268.99 W 5973919.13 N 660862.89E 7.635 3579.94 11196.94 92.460 258.990 8938.27 9002.42 1473.99 S 3299.05 W 5973911.42 N 660832.99E 14.522 3610.46 11226.20 93.250 260.930 8936.81 9000.96 1479.09 S 3327.82 W 5973905.70 N 660804.34E 7.151 3639.07 11258.69 93.430 266.730 8934.91 8999.06 1482.57 S 3360.05 W 5973901.51 N 660772.19E 17.830 3670.30 11288.95 92.720 269.890 8933.29 8997.44 1483.46 S 3390.25 W 5973899.95 N 660742.01E 10.688 3698.67 11319.01 93.690 276.920 8931.61 8995.76 1481.68 S 3420.19 W 5973901.08 N 660712.04E 23.572 3725.81 11351.54 92.990 276.570 8929.71 8993.86 1477.87 S 3452.44 W 5973904.19 N 660679.72E 2.405 3754.35 11385.51 93.870 282.730 8927.68 8991.83 1472.19 S 3485.86 W 5973909.13 N 660646.19E 18.285 3783.27 11422.39 93.870 281.490 8925.19 8989.34 1464.47 S 3521.83 W 5973916.06 N 660610.05E 3.355 3813.81 11453.72 91.670 278.330 8923.67 8987.82 1459.08 S 3552.65 W 5973920.77 N 660579.12E 12.280 3840.43 11486.32 91.320 276.050 8922.82 8986.97 1455.01 S 3584.98 W 5973924.14 N 660546.71E 7.073 3868.94 11517.88 91.930 272.530 8921.93 8986.08 1452.65 S 3616.44 W 5973925.81 N 660515.21E 11.315 3897.28 11548.96 92.200 269.010 8920.81 8984.96 1452.23 S 3647.49 W 5973925.55 N 660484.16E 11.352 3925.96 11581.75 93.950 265.320 8919.05 8983.20 1453.85 S 3680.19 W 5973923.22 N 660451.50E 12.440 3956.92 11616.91 94.130 261.630 8916.57 8980.72 1457.83 S 3715.03 W 5973918.47 N 660416.76E 10.481 3990.75 11652.93 95.010 254.250 8913.70 8977.85 1465.33 S 3750.11 W 5973910.21 N 660381.84E 20.569 4026.11 11688.05 93.510 249.500 8911.09 8975.24 1476.22 S 3783.39 W 5973898.59 N 660348.82E 14.147 4061.05 11718.80 95.010 247.740 8908.80 8972.95 1487.40 S 3811.94 W 5973886.79 N 660320.51E 7.508 4091.72 11747.67 95.890 241.590 8906.06 8970.21 1499.69 S 3837.90 W 5973873.94 N 660294.83E 21.424 4120.39 11779.24 95.620 239.310 8902.89 8967.04 1515.18 S 3865.23 W 5973857.85 N 660267.85E 7.236 4151.51 11815.38 97.650 231.050 8898.71 8962.86 1535.65 S 3894.67 W 5973836.74 N 660238.86E 23.386 4186.45 11849.27 94.830 234.910 8895.02 8959.17 1555.93 S 3921.57 W 5973815.88 N 660212.42E 14.050 4218.94 11880.86 91.140 233.860 8893.38 8957.53 1574.30 S 3947.21 W 5973796.95 N 660187.18E 12.143 4249.57 11898.05 89.030 233.860 8893.35 8957.50 1584.43 S 3961.09 W 5973786.51 N 660173.53E 12.275 4266.22 11920.00 89.030 233.860 8893.73 8957.88 1597.38 S 3978.81 W 5973773.19 N 660156.09E 0.000 4287.48 Projected Survey BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 248.220° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11920.OOft., The Bottom Hole Displacement is 4287.49ft., in the Direction of 248.126° (True). • 19 September, 2005 - 9:50 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for E-33A Your Ref: API 500292242201 Job No. AKMW3880796, Surveyed: 22 August, 2005 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 10020.13 8893.92 1337.77 S 2218.84 W Tie On Point 10023.00 8895.04 1339.10 S 2221.13 W Window Point 11920.00 8957.88 1597.38 S 3978.81 W Projected Survey BPXA • Survey tool program for E-33A From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 11920.00 8957.88 Survey Tool Description MWD Magnetic (E-33) e~ 19 September, 2005 - 9:50 Page 4 of 4 DrillQuest 3.03.06.008 - TREE _ ~ 5000# CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 64.2' BF. ELEV = 29.4' KOP = 6231' Max Angle = 94 @ 10683' Datum MD = 9953' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 3609' Minimum ID = 3.725" @ 9966' 4-1/2" OTIS XN NIPPLE E -3 3A S NOTES: HORIZ WELL, 70° @ 10054' Proposed CTD Sidetrack L J 14-1/2" OTIS SSSV LANDING NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 2 1 4242 6905 4241 6849 0 40 CAM CAM DMY DMY RK RK - - 10/20/04 10/20!04 4-1/2" OTIS X NIP, ID = 3.813" 9933' ~a-1/2" SEAL ASSY 9933' 9 5/8" X 4-1/2 SAB PKR, ID = 3.875" Top of Cement 9945' TOP OF 3-3/16" LN 9945' TOP OF 7" LNR 9231' 9954' 4-1l2" OTIS X NIP, ID = 3.813" 9966' 4-1/2" OTIS XN NIP, ID = 3.725" 9-5/8" CSG, 47#, L-80, ID = 8.681" 9424' milled to 3.8" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" 9979' 9979' 4-1/2" PARKER WLEG 9985' ELMD TT LOGGED 10/04/95 3.5" X Nip 2.813" ID 9983' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 10/04/95 ANGLE AT TOP PERF: 80 @ 10320' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10320 - 10340 isolated proposed 3-3/8" 6 10340 - 10360 isolated proposed 7" LNR, 26#, L-80, .0383 bpf, ID = 6.726" I~ 10535' SLTD LNR, 12.6#, .0152 bpf, ID = 3.953" J~Mechanical Whipstock 10475' 3-3/16 x 2-7/8 3-3/16" X 2-718" cmt'ed ~ nc perfedl 10409' 4-1/2" TM/ HORIZONTAL 10421' 4-1/2" PORTED LNR, 39.E ( 11865' I DATE REV BY COMMENTS DATE REV BY COMMENTS 01104194 SJA ORIG HORIZ COMPLETION 03/17/03 DAV/TLH SET IBP 01/04/02 RN/TP CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION CORRECTION 05/26/02 DAV/tlh GLV UPDATE/CORRECTION 02/04/04 CMO/TLP REF LOG CORRECTION 06/03/02 DAV/KK PULL IBP; FISH 10/10/04 GRGTLH IBP PULLED 7/25/04 01/31/03 SRB/TP SET IBP 10/20!04 DAV/TLP GLV GO 02/C3/03 JCM/TP PULL IBP PRUDHOE BAY UNff WELL: E-33 PERMfT No: 1931780 API No: 50-029-22422-00 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP Exploration (Alaska) • C7 20-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well E-33A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,020.13' MD Window /Kickoff Survey: 10,023.00' MD (if applicable) Projected Survey: 11,920.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ao~"-owl r • ~~ ~ ~~, ,.~~, >~, ~~ ~ ~ FRANK H. MURKOWSKi, GOVERNOR ~~ ~~ ~~. Di~[7u7I~A OuI ~ ~ !~ 333 W. 7~" AVENUE, SUITE 100 CO1~T5ERVATI011T CO1~II1'II5SIOIQ ~ ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 27&7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay E-33A BP Exploration (Alaska) Inc. Permit No: 205-089 Surface Location: 1598' FNL, 883' FEL, SEC. 06, T11N, R14E, UM Bottomhole Location: 3173' FNL, 4828' FEL, SEC. 06, Tl 1N, R14E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to rtness any required test. Contact the Commission's petroleum field inspector at 9 7)59-3~~pager). K. DATED this~~ day of June, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t~1 U+~- ~ / 3 j L~'~5 . STATE OF ALASKA ca ~x-~-..., ALASKA~L AND GAS CONSERVATION CO~ISSION ` ~~~~~~ PERMIT TO DRILL ~' ' `` 20 AAC 25.005 % f e 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Stratigraphic Test ^ Service ^Development Gas ~ Multiple Zone ~kag~`Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: E-33A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11865 TVD 8890ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1598' FNL 883' FEL SEC 06 T11 N R14E UM 7. Property Designation: ADL 028304 Pool , , . , , , Top of Productive Horizon: 2704' FNL, 2720' FEL, SEC. 06, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 14, 2005 ''~ Total Depth: 3173' FNL, 4828' FEL, SEC. 06, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664099 y-5975457 Zone-ASP4 10. KB Elevation (Height above GL): 64.15' feet 15. Distance to Nearest Well within Pool 500' 16. Deviated Wells: Kickoff Depth: 10025 feet Maximum Hole Angle: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3205 Surface: 2325 'F 18. Casing. Program: Size Spec cations Setting .Depth To Bottom Quantrty o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 33/4" x 4-1/8" 3-3116° x 2-7/8" 6.2# / 6.16# L-80 STL 1905' 9960' 8803' 11865' 8890' 5 cu ft Class 'G' ~ 19. PRESENT WELL CONDITION SUMM ARY (To be comple#ed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11551 Total Depth ND (ft): 8973 Plugs (measured): None Effective Depth MD (ft): 11551 Effective Depth TVD (ft): 8973 Junk (measured): None Casing Length Size Cement Volume MD TVD rl n t r 78' 20" 80 cu ft Arcticset A rox. 110' 110' 3574' 13-3/8" 612 cu ft PF 'E', 432 cu ft Class 'G' 3609' 3608' 9390' 9-5/8" 1639 cu ft Class 'G' 9424' 8533' Pr 'n 1304' 7" 332 cu ft Class 'G' 9231' - 10535' 8404' - 8990' Liner 1142' 4-1/2" Uncemented Slotted Liner 10409' - 11551' 8983' - 8973' Perforation Depth MD (ft): 10320' - 10360' Perforation Depth TVD (ft): 8971' - 8978' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer / v Prepared By Name/Number: Si nature '~' Ll~~~ Phone 564-4387 Date 6 2 OS Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ~',,., r~ API Number: 50- 029-22422-01-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ii Hydroge Sulfide Measures Other: T,r%S t ~~' ~ ~ S ~t7 ~ (.-~ . A roved B ^ Yes ~"No Mud Log Required ^ Yes ~ No ~°Yes ^ No Directional Survey Required Yes ^ No APPROVED BY /' I r/ THE COMMISSION Date v ~~ V Form 10-401 Revised 0~2pG4 ` * ` '~"~" ~Submit/In Duplicate BP Prudhoe Bay E-33A CTD Sidetrack CTD Sidetrack Summary 1) P&A well 2) Mill window off whipstock 3) Drill sidetrack in Zone 1. 4) Cement liner. Run MCNL. Perforate. Mud Program: • Well kill: 8.5 ppg rind • Milling/drilling: 8.6 pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • 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: ~ • 3 3/16" x 2 7/8" f 'cemented liner - 9960'MD to 11865'MD • A minimum of 7 b s 15.8 ppg cement will be used for liner cementing. Casing/Liner ormation 13 3/8", N-80, 72#, Burst 5380 psi; collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 7", N-80, 26#, Burst 7240 ;collapse 5410 psi 4'/i" slotted, 12.6# Well Control: • BOP diagram is-attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. ~ • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 10,300 ft. • Distance to nearest well within pool - 500 ft. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards ~ ~ • The maximum recorded H2S level on E pad ' 10 pm . • Lost circulation risk is low. • A short liner lap is planned. Reservoir Pressure • Res. press. is estimated to be 3205 psi at 8800'ss (7.0 ppg EMW). j Max. surface pressure with gas (0.10 psi/ft) to surface is 2325 psi. TREE = 5000# CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 64.2' BF. ELEV -._._ ___.___._........29.4' KOP = 6231' Max Angle = 94 @ 10683' Datum MD = 9953' Datum TV D = 8800' SS ~ E-33 I 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 3.725" @ 9966' 4-1 /2" OTIS XN NIPPLE ~TY NOTES: HORIZ. WELL, 70° @ 10054' 2090' I-i 4-1/2" OTIS SSSV LANDING NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4242 6905 4241 6849 0 40 CAM CAM DMY DMY RK RK - - 10/20/04 10/20/04 9915' I-i 4-1 /2" OTIS X NIP, ID = 3.813" 9933' IJ4-1/2" SEAL ASSY 9933' I-{ 9 5/8" X 4-1/2 SAB PKR, ID = 3.875" 9954' I-~4-1/2" OTIS X NIP, ID = 3.813" TOP OF 7" LNR ~ 9231' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9424' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" 9979' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.726" ~- j 10535' PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 10/04/95 ANGLE AT TOP PERF: 80 @ 10320' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10320 - 10340 O 06/30/97 3-3/8" 6 10340 - 10360 O 06/05/97 9966' 4-1/2" OTIS XN NIP, ID = 3.725" 9979' ~4-1/2" PARKERWLEG I 9985' ELMD TT LOGGED 10/04/95 ~ 10409' ~4-1/2" TNV HORIZONTAL PKR I I 10421' 4-1/2" PORTED LNR, 39.69' I I I I ~. ~. ~. ~ ` ~ ~ ~ ` ~ ` ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4-1/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.953" 11551' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/94 SJA ORIG HORIZ COMPLETION 03!17/03 DAV/TLH SET IBP 01/04/02 RN/TP CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION CORRECTION 05/26/02 DAV/tlh GLV UPDATE/CORRECTION 02/04/04 CMO/TLP REF LOG CORRECTION 06/03/02 DAVlKK PULL IBP, FISH 10/10/04 GRGTLH IBP PULLED 7/25/04 01/31/03 SRB/TP SET IBP 10/20/04 DAV/TLP GLV GO 02/03/03 JCMITP PULL IBP PRUDHOE BAY UNff WELL: E-33 PERMIT No: 1931780 API No: 50-029-22422-00 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP Exploration (Alaska) TREE _, 5000# CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 64.2' BF. ELEV = 29.4' KOP = 6231' Max Angle = 94 @ 10683' Datum MD = 9953' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 3609' Minimum ID = 3.725" @ 9966' 4-1 /2" C''~S ~R ~iPpl_E ' 14-1/2" OTIS SSSV LANDING NIP, ID = 3.813" I rA S I IFT MA NDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4242 6905 4241 6849 0 40 CAM CAM DMY DMY RK RK - - 10/20/04 10/20/04 9915' I-i 4-1 /2" OTIS X NIP, ID = 3.813" I Too of Cement I 9-518" CSG, 47#, L-80, ID = 8.681" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" 3.5" X Nip 2.813" ID E-33A, Proposed CTD Sidetrack (7 VJ I 9975' I PERFORATION SUMMARY REF LOG: PDS JEWELRY LOG ON 10/04/95 ANGLE AT TOP PERF: 80 @ 10320' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10320 - 10340 isolated proposed 3-3/8" 6 10340 - 10360 isolated proposed I I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.726" 10535' I I I I I I I I 4-1/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.953" 11551' 9933' ~a-1/2~ SEAL ASSY 9933' 1 9 5/8" X 4-112 SAB PKR, ID = 3.875" gg54' I- j4-1/2" OTIS X NIP, ID = 3.813" 9966' 4-1/2" OTIS XN NIP, ID = 3.725" 9979' 99~ 4-1/2" PARKER WLEG ELMD TT LOGGED 10/04/95 10025' ~ Mechanical Whipstock I 10900' 3-3/16 x 2-7/8 X-over 10050' ~ IBP ~ 3-3/16" X 2-7/8" cmt'ed and perfed 11865' 10409' 4-1/2" TNV HORIZONTAL PKR 10421' 4-1/2" PORTED LNR, 39.69' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/94 SJA ORIG HORIZ COMPLETION 03/17/03 DAV/1LH SET IBP 01/04/02 RN/TP CORRECTIONS 07/12/03 CMO/TLP KB ELEVATION CORRECTION 05/26/02 DAV/tlh GLV UPDATE/CORRECTION 02/04/04 CMO/TLP REF LOG CORRECTION 06/03/02 DAV/KK PULL IBP, FISH 10/10/04 GRGTLH IBP PULLED 7/25/04 01/31/03 SRB/TP SET IBP 10/20/04 DAV/TLP GLV GO 02/03/03 JCM/TP PULL IBP PRUDHOE BAY UNfr WELL: E-33 PERMff No: 1931780 API No: 50-029-22422-00 SEC 6, T11 N, R14E, 1598' FNL & 883' FEL BP 6cploration (Alaska) • • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~i~ ___~_ iNTEt,Z ._..._. _. ~~ Company: BP Amoco Date: 5/5/2005 Time:. 12:06:25 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Weli: E-33, True North Site: PB E Pad Vertical (1'VD) Reference: 54 ; 3312!1.1!1993 00:00 642 Well: E-33 Section (VS) Reference; Well (t).OON,O.OOE,24822Azi) Wellpathf Plan#4, E-33A ` Survey Calculation Method: Minimum Curvature Dbo Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB E Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973160.88 ft Latitude: 70 19 59.134 N From: Map Easting: 662538.97 ft Longitude: 148 40 53.054 W Position Uncertainty: 0.00 ft North Reterence: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: E-33 Slot Name: 33 E-33 Well Position: +N/-S 2262.65 ft Northing: 5975457.71 ft Latitude: 70 20 21.385 N +E/-W 1609.13 ft Easting : 664098.58 ft Longitude: 148 40 6.053 W Position Uncertainty: 0.00 ft Weilpath: Ptan#4, E-33A Drilled From: E-33 Tie-on Depth: 9961.68 ft Current Datum: 54:33 12/11/1993 00:00 Height 64.20 ft Above System Datum: Mean Sea Level Magnetic Data: 5/4/2005 Declination: 24.80 deg Field Strength: 57641 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N/-5 +E/-W Direction ft ft ft deg 34.20 0.00 0.00 248.22 Plan: Plan #4 Date Composed: 5/4/2005 Copy Lamar's plan4 Version: 6 Principal: Yes Tied-to: From: Definitive Path Targets Map Map ~--- Latitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting' Deg Min Sec Deg,Min ,...Sec 'Dip.. Dir. ft ft ft ft ft E-33A Target2 64.20 -1433.73 -3354.99 5973951.00 660776.00 70 20 7.277 N 148 41 44.030 W E-33A Target3 64.20 -1571.77 -3949.20 5973800.00 660185.00 70 20 5.917 N 148 42 1.381 W E-33A Polygon 64.20 -1124.46 -2448.94 5974280.00 661675.00 70 20 10.322 N 148 41 17.573 W -Polygon 1 64.20 -1124.46 -2448.94 5974280.00 661675.00 70 20 10.322 N 148 41 17.573 W -Polygon 2 64.20 -1201.93 -2565.67 5974200.00 661560.00 70 20 9.560 N 148 41 20.982 W -Polygon 3 64.20 -1227.99 -2746.30 5974170.00 661380.00 70 20 9.303 N 148 41 26.256 W -Polygon 4 64.20 -1253.02 -3201.99 5974135.00 660925.00 70 20 9.055 N 148 41 39.564 W -Polygon 5 64.20 -1498.23 -3972.59 5973873.00 660160.00 70 20 6.640 N 148 42 2.065 W -Polygon 6 64.20 -1627.09 -3935.40 5973745.00 660200.00 70 20 5.373 N 148 42 0.977 W -Polygon 7 64.20 -1617.05 -3480.04 5973765.00 660655.00 70 20 5.474 N 148 41 47.679 W -Polygon 8 64.20 -1382.67 -2534.62 5974020.00 661595.00 70 20 7.783 N 148 41 20.073 W -Polygon 9 64.20 -1305.96 -2382.89 5974100.00 661745.00 70 20 8.537 N 148 41 15.643 W E-33A Faultl6 64.20 -1091.08 -2603.26 5974310.00 661520.00 70 20 10.650 N 148 41 22.080 W -Polygon 1 64.20 -1091.08 -2603.26 5974310.00 661520.00 70 20 10.650 N 148 41 22.080 W -Polygon 2 64.20 -861.81 -2338.16 5974545.00 661780.00 70 20 12.906 N 148 41 14.340 W E-33A Fault3 64.20 -1735.90 -3077.52 5973655.00 661060.00 70 20 4.307 N 148 41 35.923 W -Polygon 1 64.20 -1735.90 -3077.52 5973655.00 661060.00 70 20 4.307 N 148 41 35.923 W -Polygon 2 64.20 -1797.27 -2558.70 5973605.00 661580.00 70 20 3.705 N 148 41 20.772 W E-33A Fault46 64.20 -1401.03 -3980.47 5973970.00 660150.00 70 20 7.596 N 148 42 2.297 W -Polygon 1 64.20 -1401.03 -3980.47 5973970.00 660150.00 70 20 7.596 N 148 42 2.297 W -Polygon 2 64.20 -1260.58 -3542.26 5974120.00 660585.00 70 20 8.979 N 148 41 49.501 W E-33A Faults 64.20 -2223.92 -4088.51 5973145.00 660060.00 70 19 59.502 N 148 42 5.439 W U ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~i~[~ _` Company: BP Amoco Date: 5/5/2005. Time: 12:06:25 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: rWell: E-33, True North Site: PB E Pad Vertical (TVD) Reference:.. 54:3312/1.1/1993 00:00 642 We1L• E-33 Section (VS) Reference: Well (O.OON,O.OOE24822Azi) Wellpath: Plan#4, E-33A Survey Calculation Metbod: M inimum Curvature . Db: Oracle Targets Map Map ~-- Latitude --> <- Longitude -> Name Description ' TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min: Sec , Dip. Dir. ft ft ft ft ft -Polygon 1 64.20 -2223.92 -4088.51 5973145.00 660060.00 70 19 59.502 N 148 42 5.439 W -Polygon 2 64.20 -1881.13 -3525.84 5973500.00 660615.00 70 20 2.876 N 148 41 49.013 W E-33A Fau1t4A 64.20 -1567.54 -4599.31 5973790.00 659535.00 70 20 5.955 N 148 42 20.366 W -Polygon 1 64.20 -1567.54 -4599.31 5973790.00 659535.00 70 20 5.955 N 148 42 20.366 W -Polygon 2 64.20 -1401.03 -3980.47 5973970.00 660150.00 70 20 7.596 N 148 42 2.297 W E-33A Fault2 64.20 -1238.27 -2276.38 5974170.00 661850.00 70 20 9.203 N 148 41 12.533 W -Polygon 1 64.20 -1238.27 -2276.38 5974170.00 661850.00 70 20 9.203 N 148 41 12.533 W -Polygon 2 64.20 -1275.93 -1927.10 5974140.00 662200.00 70 20 8.834 N 148 41 2.332 W E-33A Fau1t1A 64.20 -1127.79 -2754.11 5974270.00 661370.00 70 20 10.288 N 148 41 26.486 W -Polygon 1 64.20 -1127.79 -2754.11 5974270.00 661370.00 70 20 10.288 N 148 41 26.486 W -Polygon 2 64.20 -1091.08 -2603.26 5974310.00 661520.00 70 20 10.650 N 148 41 22.080 W E-33A Target1 9020.20 -1238.81 -2480.46 5974165.00 661646.00 70 20 9.198 N 148 41 18.493 W Annotation MD TVD ft ft- 9961.68 8868.44 TIP 10025.00 8895.84 KOP 10045.00 8903.29 End of 9°/100' DLS 10075.00 8913.36 4 10255.00 8981.97 5 10455.03 9020.46 End of 35°/100' DLS 10580.03 9015.72 7 10940.03 9003.60 8 11240.03 8996.01 9 11515.03 8982.28 10 11865.03 0.00 TD Plan Section Information MD Incl Azim TVD, +Nl-S +E!-W DLS Buitd Turn' TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg , 9961.68 61.82 239.66 8868.44 -1311.42 -2173.28 0.00 0.00 0.00 0.00 9993.55 64.11 240.14 8882.93 -1325.66 -2197.83 7.31 7.19 1.51 10.69 10020.18 66.91 239.77 8893.97 -1337.79 -2218.81 10.59 10.51 -1.39 353.07 10025.00 67.35 239.95 8895.84 -1340.02 -2222.65 9.76 9.13 3.73 20.69 10045.00 68.91 240.91 8903.29 -1349.18 -2238.79 9.00 7.81 4.82 30.00 10075.00 71.95 251.58 8913.36 -1360.52 -2264.63 35.00 10.14 35.56 75.00 10255.00 68.03 319.04 8981.97 -1320.40 -2416.11 35.00 -2.18 37.47 106.00 10455.03 92.20 251.64 9020.46 -1276.19 -2594.55 35.00 12.08 -33.69 281.00 10580.03 92.13 236.63 9015.72 -1330.52 -2706.63 12.00 -0.06 -12.01 270.00 10940.03 91.55 279.85 9003.60 -1402.09 -3050.58 12.00 -0.16 12.01 90.00 11240.03 91.25 243.84 8996.01 -1443.93 -3342.59 12.00 -0.10 -12.00 270.00 11515.03 94.32 276.74 8982.28 -1489.70 -3609.57 12.00 1.11 11.96 84.00 11865.03 94.54 234.61 8953.97 -1574.05 -3940.01 12.00 0.06 -12.04 272.00 ~ • ~,~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ #~:r~~__._~.__.._._ Company: BP Amoco Date: 5/5/2005 Time: 12:06:25 Page: 3 Field: Prudhoe Bay Co-ordinate(NE)Befereace: - Well: E-33, True North Site: PB E Pad Vertical (TVD) References 54:33.12/1 1/1993 00:00 64.2 Well: E-33 Section (VS) Reference: Well (O.OON, (}.OOE,248.22Azi) Wellpath: Plan#4 E-33A Survey Calculation Method: Minimum Curvature Db: Orate Survey MD Incl Azim SSTVD N!S E/W MapN MapE ' DLS V5 TFO Tool ft deg deg ft ft ft ft ft deg/t00ft ft deg 9961.68 61.82 239.66 8804.24 -1311.42 -2173.28 5974099.13 661954.67 0.00 2504.71 0.00 MWD 9975.00 62.78 239.86 8810.43 -1317.36 -2183.47 5974092.97 661944.62 7.31 2516.38 10.69 MWD 9993.55 64.11 240.14 8818.73 -1325.66 -2197.83 5974084.36 661930.43 7.31 2532.80 10.59 MWD 10000.00 64.79 240.05 8821.51 -1328.56 -2202.88 5974081.35 661925.45 10.59 2538.56 353.07 MWD 10020.18 66.91 239.77 8829.77 -1337.79 -2218.81 5974071.78 661909.73 10.59 2556.78 353.10 MWD 10025.00 67.35 239.95 8831.64 -1340.02 -2222.65 5974069.46 661905.94 9.76 2561.17 20.69 MWD 10045.00 68.91 240.91 8839.09 -1349.18 -2238.79 5974059.95 661890.00 9.00 2579.56 30.00 MWD 10050.00 69.37 242.72 8840.87 -1351.38 -2242.91 5974057.66 661885.93 35.00 2584.20 75.00 MWD 10075.00 71.95 251.58 8849.16 -1360.52 -2264.63 5974048.05 661864.42 35.00 2607.76 74.36 MWD 10100.00 69.75 260.55 8857.37 -1366.21 -2287.52 5974041.86 661841.66 35.00 2631.13 106.00 MWD 10125.00 68.02 269.75 8666.40 -1368.19 -2310.72 5974039.37 661818.51 35.00 2653.41 103.05 MWD 10150.00 66.81 279.13 8876.01 -1366.41 -2333.70 5974040.64 661795.50 35.00 2674.09 99.73 MWD 10175.00 66.17 288.65 8886.01 -1360.92 -2355.93 5974045.65 661773.16 35.00 2692.69 96.12 MWD 10200.00 66.11 298.22 8896.14 -1351.84 -2376.87 5974054.27 661752.02 35.00 2708.77 92.32 MWD 10225.00 66.64 307.76 8906.18 -1339.39 -2396.05 5974066.30 661732.58 35.00 2721.96 88.44 MWD 10250.00 67.74 317.17 8915.89 -1323.85 -2413.02 5974081.46 661715.27 35.00 2731.96 84.61 MWD 10255.00 68.03 319.04 8917.77 -1320.40 -2416.11 5974084.84 661712.11 35.00 2733.55 80.95 MWD 10275.00 69.53 311.70 8925.02 -1307.15 -2429.20 5974097.80 661698.73 35.00 2740.79 281.00 MWD 10300.00 71.82 302.75 8933.31 -1292.91 -2447.97 5974111.63 661679.66 35.00 2752.93 283.66 MWD 10325.00 74.51 294.05 8940.56 -1281.55 -2469.00 5974122.52 661658.38 35.00 2768.25 286.63 MWD 10350.00 77.53 285.59 8946.61 -1273.35 -2491.80 5974130.22 661635.41 35.00 2786.38 289.15 MWD 10375.00 80.81 277.33 8951.31 -1268.48 -2515.84 5974134.56 661611.27 35.00 2806.90 291.20 MWD 10400.00 84.28 269.22 8954.56 -1267.08 -2540.57 5974135.42 661586.52 35.00 2829.34 292.76 MWD 10425.00 87.85 261.22 8956.28 -1269.16 -2565.40 5974132.80 661561.75 35.00 2853.17 293.81 MWD 10450.00 91.47 253.25 8956.42 -1274.68 -2589.76 5974126.75 661537.52 35.00 2877.84 294.36 MWD 10455.03 92.20 251.64 895626 -1276.19 -2594.55 5974125.13 661532.76 35.00 2882.85 294.41 MWD 10475.00 92.20 249.25 8955.50 -1282.87 -2613.35 5974118.04 661514.11 12.00 2902.79 270.00 M W D 10500.00 92.19 246.24 8954.54 -1292.33 -2636.47 5974108.08 661491.20 12.00 2927.77 269.91 MWD 10525.00 92.18 243.24 8953.59 -1302.99 -2659.06 5974096.93 661468.85 12.00 2952.70 269.79 MWD 10550.00 92.16 240.24 8952.64 -1314.82 -2681.06 5974084.62 661447.12 12.00 2977.52 269.68 MWD 10575.00 92.13 237.24 8951.71 -1327.78 -2702.41 5974071.20 661426.05 12.00 3002.16 269.57 MWD 10580.03 92.13 236.63 8951.52 -1330.52 -2706.63 5974068.36 661421.90 12.00 3007.09 269.45 MWD 10600.00 92.12 239.03 8950.78 -1341.15 -2723.52 5974057.37 661405.25 12.00 3026.71 90.00 MWD 10625.00 92.12 242.03 8949.85 -1353.44 -2745.27 5974044.61 661383.78 12.00 3051.47 90.09 MWD 10650.00 92.10 245.03 8948.93 -1364.57 -2767.63 5974032.99 661361.67 12.00 3076.37 90.20 MWD 10675.00 92.08 248.04 8948.02 -1374.52 -2790.54 5974022.55 661338.98 12.00 3101.33 90.31 MWD 10700.00 92.06 251.04 8947.12 -1383.25 -2813.95 5974013.30 661315.77 12.00 3126.31 90.42 MWD 10725.00 92.03 254.04 8946.23 -1390.75 -2837.78 5974005.29 661292.11 12.00 3151.22 90.53 MWD 10750.00 91.99 257.04 8945.35 -1396.98 -2861.97 5973998.52 661268.06 12.00 3176.00 90.64 MWD 10775.00 91.95 260.04 8944.49 -1401.95 -2886.45 5973993.03 661243.70 12.00 3200.58 90.74 MWD 10800.00 91.90 263.04 8943.65 -1405.62 -2911,17 5973988.81 661219.07 12.00 3224.89 90.84 M W D 10825.00 91.85 266.05 8942.83 -1407.99 -2936.04 . 5973985.90 661194.26 12.00 3248.86 90.95 MWD 10850.00 91.79 269.05 8942.03 -1409.06 -2961.00 5973984.28 661169.33 12.00 3272.44 91.04 M W D 10875.00 91.73 272.05 8941.26 -1408.83 -2985.98 5973983.97 661144.35 12.00 3295.55 91.14 MWD 10900.00 91.67 275.05 8940.52 -1407.28 -3010.92 5973984.97 661119.38 12.00 3318.14 91.23 MWD 10925.00 91.59 278.05 8939.81 -1404.43 -3035.74 5973987.28 661094.51 12.00 3340.13 91.32 MWD 10940.03 91.55 279.85 8939.40 -1402.09 -3050.58 5973989.29 661079.62 12.00 3353.05 91.41 MWD 10950.00 91.55 278.66 8939.13 -1400.49 -3060.42 5973990.68 661069.75 12.00 3361.59 270.00 MWD 10975.00 91.54 275.65 8938.46 -1397.38 -3085.21 5973993.24 661044.90 12.00 3383.46 269.97 MWD 11000.00 91.54 272.65 8937.78 -1395.57 -3110.14 5973994.51 661019.94 12.00 3405.93 269.89 MWD 11025.00 91.52 269.65 8937.12 -1395.06 -3135.12 5973994.46 660994.96 12.00 3428.94 269.81 MWD 11050.00 91.51 266.65 8936.45 -1395.87 -3160.10 5973993.11 660970.01 12.00 3452.44 269.73 M W D 11075.00 91.49 263.65 8935.80 -1397.98 -3184.99 5973990.46 660945.16 12.00 3476.34 269.65 MWD • ~,~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~i~ s:: i~:r~~ _._m__._.__. Company: BP Amoco Date: 5!5/2005 Time:. 12:06:25 Page: 4 Field:. Prudhoe Bay Co-ordinate(NE) Reference: WeiC E-33, True North Site: PB E Pad Vertical (TVD) Reference: 54:33 12/f 1/1993A0:00642 We1L• E-33 Section (VS) Reference: ' Weli (O.OON ,O.OOE;248.22Azi) Wellpath: Plan#4, E-33A Survey Calculation Method: Minimum Curvature - Db: Oracle Survey MD Incl Azim S5TVD N/S E/W MapN MapE DLS VS TFO Toole ft deg deg ft ft ft ft ft degN00ft ft 'deg 11100.00 91.46 260.65 8935.16 -1401.40 -3209.75 5973986.50 660920.49 12.00 3500.60 269.57 MWD 11125.00 91.43 257.65 8934.52 -1406.10 -3234.29 5973981.26 660896.06 12.00 3525.13 269.49 MWD 11150.00 91.40 254.65 8933.91 -1412.08 -3258.55 5973974.75 660$71.93 12.00 3549.88 269.41 MWD 11175.00 91.37 251.65 8933.30 -1419.33 -3282.47 5973966.98 660848.18 12.00 3574.78 269.34 MWD 11200.00 91.32 248.65 8932.72 -1427.82 -3305.98 5973957.99 660824.87 12.00 3599.76 269.27 MWD 11225.00 91.28 245.65 8932.15 -1437.52 -3329.00 5973947.78 660802.06 12.00 3624.74 269.20 MWD 11240.03 91.25 243.84 8931.81 -1443.93 -3342.59 5973941.07 660788.62 12.00 3639.74 269.13 MWD 11250.00 91.38 245.03 8931.59 -1448.23 -3351.59 5973936.56 660779.72 12.00 3649.69 84.00 MWD 11275.00 91.69 248.02 8930.92 -1458.19 -3374.51 5973926.12 660757.03 12.00 3674.66 84.03 MWD 11300.00 91.99 251.00 8930.11 -1466.93 -3397.91 5973916.87 660733.82 12.00 3699.64 84.11 MWD 11325.00 92.29 253.99 8929.18 -1474.45 -3421.73 5973908.84 660710.17 12.00 3724.55 84.20 MWD 11350.00 92.59 256.98 8928.11 -1480.70 -3445.91 5973902.05 660686.14 12.00 3749.33 84.31 MWD 11375.00 92.87 259.97 8926.92 -1485.69 -3470.37 5973896.53 660661.79 12.00 3773.90 84.44 MWD 11400.00 93.15 262.96 8925.61 -1489.40 -3495.06 5973892.28 660637.19 12.00 3798.19 84.58 MWD 11425.00 93.42 265.95 8924.17 -1491.81 -3519.90 5973889.33 660612.41 12.00 3822.16 84.74 MWD 11450.00 93.69 268.95 8922.62 -1492.92 -3544.82 5973887.67 660587.52 12.00 3845.71 84.91 MWD 11475.00 93.94 271.94 8920.96 -1492.73 -3569.77 5973887.32 660562.58 12.00 3868.80 85.10 MWD 11500.00 94.18 274.94 8919.19 -1491.23 -3594.66 5973888.27 660537.67 12.00 3891.36 85.30 MWD 11515.03 94.32 276.74 8918.08 -1489.70 -3609.57 5973889.47 660522.73 12.00 3904.64 85.51 MWD 11525.00 94.36 275.54 8917.32 -1488.64 -3619.45 5973890.32 660512.82 12.00 3913.43 272.00 MWD 11550.00 94.45 272.54 8915.40 -1486.88 -3644.31 5973891.53 660487.93 12.00 3935.86 271.91 MWD 11575.00 94.53 269.53 8913.45 -1486.44 -3669.23 5973891.43 660463.01 12.00 3958.83 271.68 MWD 11600.00 94.60 266.52 8911.45 -1487.29 -3694.13 5973890.03 660438.14 12.00 3982.28 271.44 MWD 11625.00 94.66 263.51 8909.44 -1489.46 -3718.95 5973887.32 660413.37 12.00 4006.13 271.20 MWD 11650.00 94.70 260.50 8907.40 -7492.92 -3743.62 5973883.32 660388.78 12.00 4030.33 270.96 MWD 11675.00 94.73 257.49 8905.34 -1497.68 -3768.08 5973878.03 660364.44 12.00 4054.80 270.71 MWD 11700.00 94.75 254.48 8903.27 -1503.71 -3792.25 5973871.47 660340.41 12.00 4079.48 270.47 MWD 11725.00 94.76 251.47 8901.20 -1511.00 -3816.07 5973863.66 660316.76 12.00 4104.31 270.22 MWD 11750.00 94.75 248.46 8899.13 -1519.54 -3839.47 5973854.62 660293.55 12.00 4129.21 269.97 MWD 11775.00 94.73 245.45 8897.06 -1529.29 -3862.39 5973844.36 660270.84 12.00 4154.11 269.72 MWD 11800.00 94.69 242.44 8895.01 -1540.23 -3884.78 5973832.94 660248.71 12.00 4178.96 269.47 MWD 11825.00 94.65 239.43 8892.96 -1552.34 -3906.55 5973820.36 660227.20 12.00 4203.67 269.22 MWD 11850.00 94.59 236.42 8890.96 -1565.57 -3927.66 5973806.67 660206.39 12.00 4228.18 268.98 MWD 11865.03 j 94.54 234.61 8889.77 -1574.05 -3940.01 5973797.92 660194.23 12.00 4242.80 268.74 MWD BP Amoco wELL~11TM aLTYL{ 11nnH~ EJ]~ rw°nr w.Ewr°~ em Tr. an rm EEN.m Eyr ^n.ak ~ Enf. o.a.~.~ a ~ ]] ]]mnw] oooo s~.]on v.E.casn o.~ a~ w.on~ LEGEND T AZImUIhS IO TNB NOrth %an'. %en itb (E-33/Planif4, E-33A) -E ~y, M Magnetic North: 24.80° created ey: ani Micnaetson Date: sisnoo5 b - %en., P Magnetic Field Contact Informa0orc. Strength: 57641nT James Ohhnger Dip Angle: 80.87° Direct: (so7) asp-ssto Date: S/4/2005 Cell: (907)250-7375 Model: bggm2004 E-mail: jamas.ohlingerQinteq.com • • PM Vertical Section at 248.22° [SOft/in~ • • • • TERRIE L RUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF 89-6!1252 2~6 DATE `'' ~w`~- $ ~~.o~ DOLLARS First National Bank Alaska Anchorage, AK 99501 MEMO ~ ~~ a ~e ~: ~ 25 200060:99 14~~~6 2 27~~~ L 55611' 0 206 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (ply records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for welt (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produceiiniect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) .assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Alt dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\j ody\transm ittal_checklist WELL PERMIT CHECKLfST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT E-33A Program Well bore seg PTD#:2050890 Company BP EXPLORATION (ALASKA) INC Initial Classlfype _ ! 1-OIL GeoArea 9~_ Unit 11650 _ On/Off Shore On Annular Disposal Administration 1 Permitfee attached_ _ _ - _ _ _ - - _ _ _ _ - _ _ . Yes . - _ i2 Lease number appropriate - Yes - 3 Uniquewell_nameandnumber______________________________ ________ Yes.-__ -.,- 4 Well located in a_d_efinedpool__ ___ _________-_-- ----__--_ - -_---- Yes__-- ____-_-_____-__-_- 5 Well located proper distance-f[omdrilling unit_boundary_ - . - - - - - - - Yes - - 6 Well locatedp[operdis#ance_f[omotherwells_________ ____________ _____ __ Yes_-__ _.-- ___.-____ - - 7 Sufficiegt acreage available in_tlrilling unit - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 If_deviated,is-wellboreplat_included__________________ ________ ________ Yes-___ _-.-____ 9 Operator only affected party ______________________ ________ ________ Yes_-_ ____--_____- - ~ - 10 Operator has.appropriate-bondi_n force_-_-_-__-_-__._--_--_,__ _.___-- Yes---- ------------------------- 11 Permitcanbeissuedwithoutco_nservationorder____________________ ________ Yes__-_ -___---__ -_-_-__---- Appr Date 12 Permit_canbeissuedwithou#administrative_approval___-_----------- -------- Yes___ -_____-______,-___---___-_____--__--__--__-__--- -------------------- RPC 6!212005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by Injection 0[der # (put1O# in_comments)_(Fpr- NA_ _ - - - - - - - _ - - - - 15 All wellswithin 1!4_mile area of review identified (For service well only} _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ - - _ _ - _ _ - - _ _ - _ 16 Pre-produced injector; duration of pre production I_ess_ than 3 months. (For_service well_ only) , . NA_ _ _ - 17 ACMP-Finding of Consistencyhas been issued_focthis project- . NA- - - Engineering 18 Conductorstring-provided_--___--_______________________ ________ NA_____ __- _-- - - 19 Su_rfacecasingp_rotectsall_kn4wn_USDWS_______ _____________ ______ NA--___ _--- - - - 20 CMT_vol-adequate_tociCculate_onconductor-&surf_csg________________ ________ NA_---_ ___---____---__-_----__----_ - - 21 CMT_voladequate-totie-in long string tosurfcsg__________ _________ _____-- NA-____ --_______-_____-___ 22 CMT_will coyer_allknown-productive horizons- - _ - Yes - _ - - - ' 23 Casing designs adequate Fo[C,_T,B&-permafrost------------------ - Yes---- -----,------------------ ---------.-----------------.--------------- 24 Adequate tankage_orreservepit___________________-___-_,_- ___-_--_ Yes---_ __CTDU.-__---____ - ~ - 25 If_a-re-drill,has-a10-4D3forabandonment been approved______________ ________ Yes-___ _--*_____.-___-__-_ - - 26 Adequatewellboreseparationproposed--_-____________________ _______ Yes__-_ _-______-_____--__--_,-- 27 Ifdiverterrequired,doesitmeetregulations_--_____--___-__-_-- _--__--- NA-___ , -Sidetrack_________ ______ ------------------------------------------- Appr Date 28 Drillin fluid-roram schematic&eui listadequate_--- 9 p ~ 4p _ Yes____ --_MaxfvlW-$.6ppg._-___-___-__---_------------------------__--_-_ WGA 6/3/2005 29 B_0_PEs,-do they meet regulation________________ Yes__ ___-__ -___-_ - - - ~ 30 BOPE_ptess rating appropriate; test to-(put prig in comments)_ _ Yes Test to 3500 psi. _MSP 2325 psi.- _ - _ . ---------------------------------- 31 Choke_manifgldcomp_lieswlAPI_RP-53 (May 84)___________ ________ ________ Yes_-__ --.-____-. - - 32 Work will occur without operation shratdown___________ ___________ ________ Yes-___ -_-_-____----_---------_---_____,-__---_--_-_-_--_-.--------___-_----__ 33 Is presence-of H2$ gas_probable - - - - - No - . fylax H2$10.pPm~ 34 Mechanicatcondition of wells within AOR verified (For service wep only) NA_ _ _ Geology 35 Permitcan be issued w/o_ hydrogen_sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - -N_o_ _ - - _ _ _ _ _ - 36 Data-presented on_ potential overpressr~re zones _ - - _ _ _ _ - - - - - - - - - - - - - - - _ - NA- - _ - _ _ - _ _ - - _ _ _ Appr Date 37 Seismic analysis ofsha_Ilowgas-zones----_-------------------- -------- NA___-. -___-_._ - RPC 6/2!2005 38 Seabed condition survey-(ifoff-sh_ore) ------------------------- -------- -N_A_--- - - - - 39 -Contact name/phone forweekly progress reports (exploratory only]_ - _ NA_ Geologic Engineering Public Commissioner: pTS Date: Commissioner: Date Co is ' r 6~~'is ~ c Date u~ , -3-os le o f • ~J u Well History File APPENDIX Information of detailed nature that is not particularly getimane 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. i Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 16 14:57:09 2006 Reel Header Service name .............LISTPE Date .....................06/O1/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/01/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library • 13~3Lo 005 -D $9' Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: E-33A API NUMBER: 500292242201 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-JAN-06 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0003880796 MW0003880796 MW0003880796 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: T. EIDEN/S. T. EIDEN/S. T. EIDEN/S. MWD RUN 4 JOB NUMBER: MW0003880796 LOGGING ENGINEER: S. LATZ OPERATOR WITNESS: T. EIDEN/S. SURFACE LOCATION SECTION: 6 TOWNSHIP: 11N RANGE: 14E FNL: 1598 FSL: FEL: 883 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 64.15 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 15T STRING 4.125 7.000 10023.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS} , 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10023' MD/ 8831'TVDSS AND THE BOTTOM WAS AT 10033/8835'TVDSS. 4. THE WHIPSTOCK WAS SET AND THE INITIAL TIE-IN WAS PERFORMED WITHOUT SDS TOOLS IN THE STRING. 5. MWD RUNS 1-4 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY PROVIDED TO SDS BY D. DORTCH {SAIC/BP) ON 12/30/05. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4 REPRESENT WELL E-33A WITH API#: 50-029-22422-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11920'MD/8894'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 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 9415.0 11887.0 ROP 10043.0 11917.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9415.0 9417.5 10030.5 10033.0 10075.5 10084.5 10089.0 10093.0 10111.0 10114.0 10133.0 10146.5 10172.5 10183.0 10204.5 10210.5 10214.0 10233.0 10243.0 10251.0 10264.0 10275.5 10285.5 10299.0 10302.5 10306.5 10310.0 10313.5 10321.5 10342.5 10353.5 10381.0 10417.5 10453.5 10466.0 10509.0 10568.0 10595.5 10674.5 10749.0 10759.0 10761.0 10777.5 10817.0 10847.5 10657.5 10868.0 10878.5 10910.5 10915.5 10936.5 10956.0 11051.0 11055.5 11117.0 11140.0 11148.5 11150.5 11177.0 11230.0 11234.0 11236.5 11245.5 11250.5 11267.0 11276.0 11288.5 11293.0 11294.5 11315.5 11332.0 11360.0 10079.0 10088.0 10091.5 10095.5 10113.0 10115.0 10135.5 10150.0 10178.0 10190.0 10207.5 10214.0 10218.0 10236.5 10246.0 10253.5 10267.5 10279.5 10290.0 10303.5 10306.0 10312.0 10314.5 10316.5 10322.0 10344.0 10356.5 10385.0 10419.0 10455.0 10467.5 10508.5 10566.5 10607.0 10676.5 10749.5 10760.0 10763.0 10782.5 10821.5 10849.5 10857.5 10867.0 10880.0 10913.0 10917.0 10936.0 10956.5 11052.5 11056.5 11118.5 11140.5 11147.0 11150.5 11178.5 11232.5 11237.0 11238.5 11248.5 11254.0 11270.0 11280.5 11291.0 11297.5 11299.5 11317.0 11335.0 11363.5 • 11418.0 11419.5 11439.5 11441.0 11461.0 11462.5 11477.0 11480.0 11514.0 11514.0 11542.5 11544.0 11550.5 11551.5 11553.0 11554.0 11588.0 11591.0 11594.5 11600.5 11637.5 11642.5 11642.0 11646.5 11707.5 11707.5 11740.0 11744.5 11756.5 11760.5 11767.0 11772.5 11778.0 11782.5 11782.5 11786.5 11814.0 11817.0 11828.0 11830.5 11917.5 11920.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 9417.5 MWD 2 10454.0 MWD 3 10832.0 MWD 4 10996.0 REMARKS: MERGED MAIN PASS. MERGE BASE 10454.0 10832.0 10996.0 11920.0 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FTf H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9415 11917.5 10666.3 5006 9415 11917.5 ROP MWD FTfH 0.03 2391.52 72.5928 3750 10043 11917.5 GR MWD API 16.82 706.73 65.7435 3841 9415 11887 First Reading For Entire File..........9415 Last Reading For Entire File...........11917.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 a • Date of Generation.......06j01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 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 INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9417.5 10423.5 ROP 10046.0 10454.0 LOG HEADER DATA DATE LOGGED: 17-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10454.0 TOP LOG INTERVAL (FT) 10046.0 BOTTOM LOG INTERVAL (FT) .10454.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.0 MAXIMUM ANGLE: 82.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 9976.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM} AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 141.7 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....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 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWDO10 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9417.5 10454 9935.75 2074 9417.5 10454 ROP MWDO10 FT/H 0.03 501.98 51.3797 817 10046 10454 GR MWDO10 API 16.82 706.73 49.8562 909 9417.5 10423.5 First Reading For Entire File..........9417.5 Last Reading For Entire File...........10454 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. • BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10424.0 10801.5 ROP 10454.5 10832.0 LOG HEADER DATA DATE LOGGED: 19-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT}: 10832.0 TOP LOG INTERVAL (FT}: 10454.0 BOTTOM LOG INTERVAL (FT) 10832.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 9976.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 6.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 145.9 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....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 • • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10424 10832 10628 817 10424 10832 ROP MWD020 FT/H 0.94 121.63 62.692 756 10454.5 10832 GR MWD020 API 50.63 151.43 74.7943 756 10424 10801.5 First Reading For Entire File..........10424 Last Reading For Entire File...........10832 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 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 10802.0 10965.5 ROP 10832.5 10996.0 LOG HEADER DATA DATE LOGGED: 19-AUG-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10996.0 TOP LOG INTERVAL (FT) 10832.0 BOTTOM LOG INTERVAL (FT) 10996.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 96.8 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT): 9976.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITX (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 154.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....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 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 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 10802 10996 10899 389 10802 ROP MWD030 FT/H 7.15 317.36 42.5755 328 10832.5 GR MWD030 API 47.69 139.51 88.8688 328 10802 First Reading For Entire File..........10802 Last Reading For Entire File...........10996 File Trailer Last Reading 10996 10996 10965.5 Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/O1j16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10966.0 11889.5 ROP 10996.5 11920.0 LOG HEADER DATA DATE LOGGED: 22-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11920.0 TOP LOG INTERVAL (FT) 10996.0 BOTTOM LOG INTERVAL (FT) 11920.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 97.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 3.750 DRILLER'S CASING DEPTH (FT}; 9976.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3) 10.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 163.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL • • MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN?: EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10966 11920 11443 1909 10966 11920 ROP MWD040 FT/H 5.34 2391.52 91.4539 1848 10996.5 11920 GR MWD040 API 27.52 236.44 66.1412 1848 10966 11889.5 First Reading For Entire File..........10966 Last Reading For Entire File...........11920 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/O1j16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/01/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF writing Library. Scientific Technical Services End Of LIS File