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Home My WebLink About202-022 Image prbject Well History File C(Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 'd. Q.~ - 0 ~ ~ Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 RESCAN ¡Calor Items: 0 Greyscale Items: 0 Poor Quality Originals: DIGITAL DATA piskettes, No. I 0 Other, No/Type: 0 Other: NOTES: BY: Helen ~ Project Proofing BY: Helen ~ ~~vla~ ~ Scanning Preparation BY: Helen ~ :~ x30=QD Page Count from Scanned File: C' 4- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ Y!=S NO I Date: I ~5 ó.s- /5/ YES NO Production Scanning Stage 1 BY: Helen ~ Stage 1 BY: ~escan Needed I OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds: 0 Other:: , 1 I Date: I ~.f: tJ, ç- /5/ I mp f Datel ~s DS- Is/ VVlO +¿3 = TO~ALPAGES tf23 (Count does not inc1.d.ecover sheet) 111 A '~ Date: J ;:}.. S- ()Ç' /5/ f V I ~ - I wrP Helen Maria If NO in stage 1, page(s) discrepancies were found: Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: Date: /5/ I I I Date: /5/ Quality Checked 1111111111111111111 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~VED DEC. ~ ~ 2009 WELL COMPLETION OR RECOMPLETION REPORT N 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completio Zero 1 b. a ° ®Developme~tll:liloratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., o band.' 11/24/2009 12. Permit to Drill Number: 202-022 308-417 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 11/2/2002 13. API Number: 50-029-20800-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 11/5/2002 14. Well Name and Number. PBU 01-19A 165 FNL, 462 FWL, SEC. 08, T10N, R15E, UM Top of Productive Horizon: 2817' FSL, 2263' FEL, SEC. 06, T10N, R15E, UM g. KB (tt above MSL): 70+ GL (tt above MSL): 39.71' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3352' FSL, 3265' FEL, SEC. 06, T10N, R15E, UM 9. Plug Back Depth (MD+TVD): .9880' 8721' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 697777 y_ 5940734 Zone- ASP4 10. Total Depth (MD+TVD): 11584' 9010' 16. Property Designation: ADL 028329 TPI: x- 694964 y- 5943644 Zone- ASP4 Total Depth: x- 693947 Y- 5944153 Zone- ASP4 11. SSSV Depth (MD+TVD): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information r 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, ROP, RES, CNL, CCL 22. Re-DrilULateral Top Window MD/TVD: 9834' 8682' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT: CASING ` WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED 1.5# H-40 Surf 80' rf 30" 195 # P I se 1- 72# rf rf 2 17-1 x F P fr 9-5/8" 47# L-80 Surface 9610' S rface 8490' 1 -1/4" 500 sx CI s 00 sx Perm fros 'C' 7" 26# L- 0 1 5' 9164' 1885' 8 099' Tie sx Class 'G' 7" 2 22 ' -1 x I 'G' a-,rr~, ~-~~s° a.e,a~s.zni L-80 311' 11584' 822 ' 9 010' 3-3/4" 1 0 sx Clas 'G' 24. Open to production or injection? ^ Yes ®No 25. TUBING RECORD If Yes, Ilst~~aeh'Intervat-operr° ' (MD+TVD of To & Bottom; Perforation Size and Number): SIZE DEPTH .SET MD PACKER SET MD / TVD p 4-1/2", 12.6#, 13Cr 9133' 9037 / 7988' MD TVD MD TVD 5-1/2" 17# x 4-1/2" 12.6# L-80 9165' - 9340' 9231' / 8158' 26. ACID,FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED r, t,'~',~~1_.~ ,;~~~ ~~ ~ ~~~~ 9880' 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) Acquired? ^ 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 07/2009 CONTINUED ON REVERSE J2 19.Oq Subm~ OriginalOnty 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 results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 3 9977 8803' None Zone 2C 10097' 8899' Zone 26 10170' 8946' Zone 2A 10320' 9019' 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. -21 ~ Signed: Terrie Hubble Title: Drilling Technologist. Date: PBU 01-19A 202-022 308-417 Prepared ey IVameMumber. Terrie 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-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. MuRiple 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. ttem 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 07/2009 Submit Original Only • 01-19A, Well History (Pre Rig Sidetrack) Date Summary 10/27/2009 WELL S/I ON ARRIVAL. DRIFTED W/ 2.70" x 20' DMY WHIPSTOCK TO 9890' SLM / 9897' MD W/ NO PROBLEMS. WELL LEFT 10/30/2009 T/I/0=2300/450/200, Temp=Sl. PPPOT-T (PASS), pre CTD. Stung into test port (50 psi), bled void to 0 psi. Function LDS, 1 LDS stuck to gland nut, the whole assembly will move together (flagged), all the rest moved freely (1.25 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 11/1/2009 WELL SHUT IN ON ARRIVAL. INITAL T/I/O = 2380 / 440 / 500 LRS LOAD AND KILL WELL UPON ARRIVAL. RU AND RIH WITH WHIPSTOCK AND ORIENTATION TOOL. REACH SETTING DEPTH AND EXPERIENCE TELEMETRY PROBLEMS. POOH TO REPLACE ORIENTATION TOOL. 11/1/2009 T/I/0=2340/440/200 Temp=Sl Assist E-Line (CTD Prep) Spear into TBG w/3 bbls of meth followed by 290 bbls of 100° Sea H2o, cap w/40 bbls of diesel for F-Protect. EL on well upon departure, IA, OA = OTG operator notified Final Whp's=0/600/700 11/2/2009 WELL SHUT IN ON ARRIVAL. INITAL T/I/O = 2380/440/500 LRS LOAD AND KILL WELL UPON ARRIVAL. RU AND RIH WITH WHIPSTOCK AND ORIENTATION TOOL. REACH SETTING DEPTH AND EXPERIENCE TELEMETRY PROBLEMS. POOH TO REPLACE ORIENTATION TOOL. TOP OF WINDOW SET AT 9880' ORIENTED 53 DEG LOHS. 2 RA TAGS LOCATED 5.2' BELOW TOW, AT 9885.2'. PACKER ELEMENT LOCATED 7.3' BELOW TOW, AT 9887.3'. SWAB-CL, MASTER-OP, WING- CL, SSV-OP, OTG FINAL T/I/O = 0/140/340 JOB COMPLETE. 11/9/2009 T/I/O = VAC/320/110. Temp = SI. Bleed WHPs to 0 psi (pre CTD). No AL line. IA & OA FL near surface. Bled IAP to 0+ psi in 8.5 hours, OAP to 0+ psi in 5.5 hours. Monitored pressures for 30 min. IAP increased 5 psi, OAP increased 10 psi. Final WHPs =VAC/5/10. WV, SV =closed. SSV, MV =open. IA, OA = OTG. 11/10/2009 T/I/0= VAC/5/20. Temp= SI. Bleed WHPs to 0 psi (pre CTD). IA, OA FL near surface. Bled IAP from 5 psi to 0 psi in 10 min. Bled OAP from 20 psi to 0 psi in 5 min. Monitored for 30 min. IAP, OAP increased to 5 psi. Final WHPs= VAC/0/0. SV, WV= Closed. SSV, MV= Open. IA, OA= OTG. NOVP. 11/10/2009 T/I/0=vac/0/0 Set 5 1/8" FMC ISA TTP thru tree. 1-2' ext used tagged C~1 88". Torqued tree flanges to API specs. Pressure tested tree to 5k. Passed. Pulled 5 1/8" FMC ISA TTP thru tree. 1-2' ext used tagged @ 88". No problems. 11/10/2009 T/1/O =vac/10/30. Temp = SI. Bleed WHPs to 0 psi (CTD). Bled IAP & OAP to 0 psi in 10 min (all gas). Continued open bleed for 45 min. Monitored for 2 hrs. IAP increased to 5 psi and OAP increased to 15 psi. Final WHPs =vac/5/15. SV=C. WV, SSV, MV=O. IA, OA=OTG. NOVP. 11/12/2009 T/I/0=0/0/0 MIT-TBG to 1000 psi (CTD Prep) Pumped 19.3 bbls crude down TBG to bring to test pressure. On 3rd test, TBG lost 20 psi in 1st 15 min & 20 psi in 2nd 15 min. Pass per PE. DSO & PE notified upon departure. FWP=O/0/0 Tags hung. SV & WV =Open. SSV, MV, IA & OA =Open 11/14/2009 T/I/0=25/20/25. Temp=Sl. Monitor WHPs. (Pre-CTD). TP increased 25 psi in 2 days. IAP increased 20 psi in 2 days. OAP increased 25 psi in 2 days. WV, SV =CLOSED. SSV & MV =OPEN. IA & OA = OTG. NOVP. 11/15/2009 T/I/O=SSV/10/10. Temp=Sl. WHPs (pre CTD). No flow line or well house. IAP decreased 10 psi, OAP decreased 15 psi overnight. MV & SV locked and taged out. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 11/16/2009 T/I/O =SSV/20/18. Temp = SI. Bleed WHPs to 0 psi (pre CTD). No AL line, F/L. Well house & swab scaffold railing removed. IA, OA FL near surface. Did not bleed TP as per Night Lead. Bled IAP, OAP to 0 psi in 4.5 hours (all gas). Monitored pressures for 60 min. IAP, OAP increased to 10 psi. Bled IAP, OAP to 0 psi in 10 min. Monitored pressures during rig down. IAP, OAP increased to 0+ psi. Final WHPs = SSV/0+/0+. Unable to access SV. MV, SSV =closed. IA, OA = OTG. Page 1 of 1 BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 01-19 Common Well Name: 01-19 Spud Date: 8/25/1982 Event Name: REENTER+COMPLETE Start: 11/18/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: N1 ~ From - To Hours Task Code NPT Phase Description of Operations Date 11/23/2009 00:00 - 11:30 11.50 MOB P PRE CONTINUE MOVING RIG FROM E PAD TO DS-01 VIA K PAD RD, WEST DOCK RD TO DS-01. POSITION RIG IN FRONT OF WELL 01-19. NO PROBLEMS DURING RIG MOVE. 11:30 - 11:45 0.25 MOB P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR BACKING THE RIG OVER THE WELL. 11:45 - 12:00 0.25 MOB P PRE BACK THE RIG OVER THE WELL AND SET DOWN. ACCEPT NORDIC 1 ON DS 01-19B AT 1200 HRS, 11/23/2009 12:00 - 14:30 2.50 RIGU P PRE SPOT TRAILER, CUTTINGS BOX AND TIGER TANK. GENERAL RIG UP. M/U HARDLINE INSIDE THE COIL REEL. 14:30 - 14:45 0.25 BOPSU P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR N/U BOPE 14:45 - 18:00 3.25 BOPSU P PRE N/U BOPE. OPEN SSV WITH GREASE CREW AND LOCK OPEN WITH FUSIBLE CAP. RIG UP CUTTINGS TANK. GREASE VALVES. 18:00 - 00:00 6.00 BOPSU P PRE START BOP TEST. TEST IS WITNESSED BY AOGCC OFFICIAL CHUCK SCHEVE. VALVE #11 ON CHOKE MANIFOLD FAILS, NEEDS REBUILD. 11/24/2009 00:00 - 01:40 1.67 BOPSU N RREP PRE REBUILD CHOKE VALVE #11 AND RE-TEST, GOOD. 01:40 - 02:00 0.33 RIGU P PRE CLEAR RIG FLOOR, PREP TO PULL CT ACROSS. 02:00 - 02:15 0.25 RIGU P PRE SAFETY MEETING. DISCUSS HAZARDS AND MITIGATIONS FOR PULLING CT ACROSS PIPE SHED ROOF INTO INJECTOR. 02:15 - 03:15 1.00 RIGU P PRE ATTACH INTERNAL CT GRAPPLE AND PULL TEST. REMOVE SHIPPING BANDS FROM REEL. PULL CT ACROSS PIPE SHED ROOF AND INTO INJECTOR. 03:15 - 05:20 2.08 RIGU P PRE COIL IS THROUGH INJECTOR. REMOVE INTERNAL GRAPPLE. RE-BOOT CABLE AND CHANGE OUT STRIPPER BRASS AND PACKING ELEMENT. 05:20 - 08:00 2.67 RIGU P PRE M/U CT RISER, FILL CT FORWARDS WITH 5 BBLS MEOH THEN 2# BIOZAN. REVERSE CIRC WITH 20 BBL RIG WATER AND BIOZAN TO PUMP IN SLACK. PUMP MAX RATE 3 TIMES. CUT OFF 5' COIL. 08:00 - 09:00 1.00 STWHIP P WEXIT M/U CTC, PRESS TEST. PRESS TEST INNER REEL VALVE. CHART TEST. 09:00 - 10:30 1.50 STWHIP P WEXIT MU UOC, TEST E-LINE CONTINUITY. 10:30 - 10:45 0.25 STWHIP P WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATIONS FOR MAKING UP WINDOW MILLING BHA. 10:45 - 11:15 0.50 STWHIP P WEXIT MU 2.74" WINDOW MILLING BHA W/ COIITRACK ASSY 11:15 - 14:00 2.75 STWHIP P WEXIT RIH WITH WINDOW MILLING ASSEMBLY WHILE PUMPING 2# BIOZAN AT MIN. RATE 14:00 - 15:00 1.00 STWHIP P WEXIT TIE IN LOGGING PASS. CORRECT -7' in 15:00 - 00:00 9.00 STWHIP P WEXIT ESTABLISH FREE SPIN OF 2150 PSI ~ 1.6 BPM. BEGIN g TIME MILLING WINDOW Qp~ (71-~9~ 9880.2', 2250 PSI, 0.5K 9880.4', 3400 PSI, 0.8K (FIRST MTRWRK) 9880.9', 3000 PSI, 1.OK 9881.5', 3000 PSI, 1.9K Printed: 12/10/2009 11:16:04 AM TREE = FMC WELLHEAD = FMC HCTllAT©R ~ AXELSt}N _KB. ELEV ~= W 70' BF. ELEV~= KOP _,.w ~ _ 3401)' Max Angle = 95"~ t0~s18' C3aturn MD = 10462' DatumTVD= 880d'SS • FT 2d" CONDUCTOR, - $Q 91.5fF, H-40, ID =19.124" 13-318" CSG, 72#, L-80 BUTT, ~ = 12.:347" 1-i 2590' ~11'IICCll1111 ~Q = ~." ~ ~~~0~ 19-5/$" HES ES CEMENTER. 1 7"' sGAB LNR, 26#, L-$0 BTGM, L-sQ, ~-~ 9~2i' .03$3 bpf., lD = 6.276" 4112°' TBG, 12.6#, 13CR VAl1A TOP, 9133' .0152 bpf, ID = 3.958" - 5-112" TUBING 1 . STUB--I 9165' 5-112" TBG, 17#, L-80 BTC, 9242' .4232 bpf, ID = 4.892" TOP OF 7" LNR, BOT HGR 9305' 01-196 511~F~TY~ES. **;4-1l2" CHROME TBG~ 1 ~$~~ 9-518" X 7" BKR ZXP PKR w 1 G2 PROF~E & FLEX-LOCK LNR HGR, ID = 6.310" 2083' 4112 HES X NIP,1D = 3.813" GAS LIFT MANDRELS 5T MD TVr.3 DEV TYPE VLV ' LATCfi# PORT DATE 5 3532 3512 19 KBG-2 DOME' BK i' 6 i 2108109 4 5401 51 d5 39 KBG-2 SO BK 2d i 2I08f09 3 6810 6191 40 KBG-2 DMY BK 0 03/06104 2 8011 7128 36 KBG-2 DMY BK 0 43!06104 1 8958 7920 30 KBG-2 DMY ' BK d 03106104 9026' 4-112" HES X NIP, ID = 3.813" 9031' 7'" X 4112" BKR S-3 PKR, Iii = 3.875•' 9"102" 41 /2" HES X NIP, ID = 3.813'" 4112" MULE SHOE, ID = 3.958" 9-518" X 5-112" UNIQUE OVERSHOT GAS LIFT MANDRELS D DEV TYPE VLV LATCH P( 9231' ~ 9-x!8" X x-112" BRN PKR, ID = ? 924' S-112" X 4-112" KO, K3 = 3.958° 9311'... 3-314" BKR DEPLOY SLV, ID - 300" 9316' 3-112" XO PIN, ID = 2.8$0" 93121' ~ 3-1l2" HOWCO XN N~', ID = 2.7x0•, 41f2" TBG, 12.6#, L-80 BTC, .0152 bpf, ID= 3.958" 1 9340' 9-x18" CSG. 47#, L-80 BUTT, ID = 8.681" 9610` 3-112" LNR, $.$1 #, L-80 STL, .0487 bpf, ID = 2:992° 9111' 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 9$34' ) i MILLOUT WINDOW (01-19A) 9834' - 9839' hu i iV REF LOG:. A NGLE AT TOP PERF; 9d' ~ 14650' Note: Refier #o Produc#ion DB for his#orioal parr da#a SIZE SPF INTERVAL OprifSgz C~4TE 1.56" 6 14650 - 1 4930 O 12103!09 1.x6" 6 11010 - 11550 O 12/03/09 +Top Liner Top PacKer w; 3" GS 2-315" Tta~ •~fi Line w 1 ~° CsS y~$~' ~3-~ 1~~"Ti:1POFWHTOCK ~ 9880' 1 DA, TE 3-3/16" LNR, 6.2#, L-80, TCII, .0076 bpf, ID = 2.80" PBTD 11620' ' ~`' ". ~, ` ' r 2-3/8`" LNR, 4.7, L-8Q STL, ID° 1.995" 11660" , ~- \ i ~ y, ,~ l~ rkl,i `1~,• L t, ~ ', ,' 1'~~ ;~~_ :; MILLOUT WINDOW (01-19B) 9880' - 9886' ~``:, •~~ .~ DATE REV BY COMIV~NTS DATE REV BY COMMEM1(TS 08)11182 ROWAN 35 COMPLETION 12/12/49 DAV/SV GLV GO (12108149) Q'31191#12 N3ES CTCI SUSPE3+lf~ (A1-19A) 11/08/112 NORI~C 1 CTD Slf]EY'RACK (41-19A) 0310711)4 N4ES RWO 12105!09 NORDIC 1 CTt1 SIDETRACK (01-19B) 12!12109 SV DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: 01-198 PERMIT No: 2081770 API No: 50-029-20840-02 SEC 6, T10N, R15E, 2233..27' FEL & 2387.66" FNL BP Ekploration (Alaslta) ALASSA OIL A1~TI~ GAS CO1~T5ERQATIOI~T CO1~IIrIISSIOr1T John McMullen Engineering Team Leader BP Exploration Alaska Inc. • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 ~>`~b'~~~%;, ~~ t~ ~ ~ ~~~ Anchorage, AK 99519-6612 ~"~ ~~~"- D Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-19A Sundry Number: 308-417 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 4:3Q 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, '- Cathy P. Foerster Commissioner DATED this ~~day of November, 2008 Encl. pp~~- - - ,: V ~~~~ V STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SION - APPLICATION FOR SUNDRY APPROVAL `~`'' 20 AAC 25.280 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time ExtensioA ^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 202-022 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20800-01-00 - 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 01-19A - Spacing Exception Required? ^ Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~ la ADL 028329 ' 70' ~ 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): 11584 ~ 9010 - 11551 - 9016 f None None asin L n i tru r I r 14 4 urfa 2 9 ' 1 -3/8" 2670 In rm i 1 9-5/8" 1 4 7 476 in in r 52 ' 7" 3 5' - 834' 2 3' - 82' 816 7 Lin r 273' 3-~n° x 3-3/16" X za~e~~ 9311' - 115 4' 22 ' - 9 10' i 7" 1 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10870' - 11470' 9033' - 9029' a-~n° ~z.6a x s-~rz° »aXa-~n° ~zs~ 13Cr / L-80 9340' Packers and SSSV Type: 9-5/8" x 7" Baker ZXP Packer, 7" x 4-1/2" S-3 Packer, and Packers and SSSV MD (ft): 1885', 9037', 9231' a 9-5/S" x 5-1/2" BRN Packer 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ®BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 20, 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 Charles Reynolds, 564-5x80 Printed Name John G~A Ilen Title En ineerin Team Leader Prepared By Name/Number. Signature ~,-~--~- Phone 564-4711 Date (( (y~ Sondra Stewman, 564-4750 Commission Use Onf Sundry Number. ,, Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 35~~ PS l ~ ~ ~~~ ~~~, Subsequent Form Required: ~,.~~~ APPROVED BY // ~ ~ ~ ~ ~ A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised96/2006 ~j ~` i Submit In Duplicate tit To: Tom Maunder • • Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Charles Reynolds CTD Engineer Date: November 11, 2008 Re: 01-19A Sundry Approval Sundry approval is requested to abandon perforations on well 01-19A. Well 01-19A is a Z2A CTD sidetrack drilled in November 2002. The initial perforations were shot off depth at 2400' and the well did not flow. The off-depth perforations created tubing and casing leaks. The leaks were repaired with a rig workover in March 2004 that installed afully-cemented 7" scab liner from 1885' - 9188'. Following the workover, the well was produced; however, the oil rate quickly fell and the well began cycling in 6 months. 75' of Z2A heel adperfs were shot in Feb 2005 with a minimal impact on the well's performance. An additional 25' of Z2A perforations were shot in the horizontal in September 2005 with no impact. A CIBP was set at 10310' along with 14' of end-of-life adperfs in lower Z26. The CIBP/adperfs had minimal impact. Following a long SI, the CIBP was milled in August 2007 and the well produced for ~6 months prior to reaching marginal GOR again. The well was shut-in in April 2008 at marginal GOR. The well passed aMIT-IA to 3000 psi and aMIT-OA to 2000 psi in May 2008 verifying the integrity of the wellbore. A caliper log was run since the well has relatively new chrome tubing run in 2004 and a caliper log in December 2005 indicated the tubing was in excellent condition. The 2005 caliper log did indicate a leak in the old 5-1/2" tubing stub at 9177' but this is below the current production packer and does not affect the integrity of this well. REASON FOR SIDETRACK: Well 01-19 is currently producing above marginal with minimal remaining value. The planned sidetrack will access Zone 2A reserves that would otherwise remain undeveloped. Pre-CT Rig Work: ~ • 1. MIT-IA - to 3000psi 2. MIT-OA - to 2000 psi 3. Drift well for whipstock to 3-3/16" x 2-7/8" crossover at 9.897'. 4. Set Baker 3-3/16" whipstock on a 033 packer at 9,880'. 5. PT tree (MV,SV,WV), function LDS r 6. Bleed IA, gas lift and production flowlines down to zero and blind flange. , ~~~ ~ ~ ~~~~i~ \ 7. Remove S-Riser, Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on December 21, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill 2.75" window at 9,880' thru 3-3/16" liner. 4. Drill build/turn section with 2.70" x 3.0" bicenter bit, and land well. 5. Drill lateral section to 11,655' MD. 6. Run and cement a 2-3/8" L-80 liner string. 7. Make a cleanout run with mill and motor. 8. Make a logging run with a SWS GR-CNL logging tool. 9. Perforate well. 10. Circulate well to KWF brine. FP well to 2000' with methanol.. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Charles Reynolds CTD Engineer CC: Well File Sondra Stewmanlf errie Hubble TREE = FMC LLHEAD = FMC ACTUATOR = ............_._...._ ........... A7~ELSON ........ .. ... . _ KB. EIgV .. .. ... .. 70' BF. ELEY _ ..__._..... ............... KOP s _ ... 3~~ .. X = .l1 11509' Detun MD = 10058' Daum TVD = 8800' SS 20" COM1IDUCTOR, 91.5*, H-40, ~ =19.i 24" '~ ~~ SAF MOTES: ""'4-12" CFA TBCi. 1~~ 9-518"}( 7" ~tR ZxP PKR w! C2 PRCFN.E ~, 8 FLEXd.OCK lIWt HGR ID = 6.310" ~(~' 412" HES X NIP, ID = 3.813" 13.318" CS4, 72*, L•80 BUTT, 10 =12.347" ~-( 259[1' Minimum ID = 2.377" ~ 9897' TOP OF 2-7J8" LINER 9-516" HES ES CEh~NTER -~T9" 7" SCAB IPYt, 26ar, L-~ BTC-M, L-80, .0383 bof. D = 6.276" 4112" TBf3,12.6ar, '13CR YAM TOP, .0152 bpf,. O = 3.958" 5.12" TUBMJ4 STUB 5-112" TBC3,17ar, L-80 BTC, .0232 b f, ~ = 4,892' TOP Of 7" LNR, 807 H4R 412" T®4, 12.6sY. L•80 BTC. A152 bpf. ID = 3.958" ( 9.518" GS6, 4T~1, L•80 BUTT, D = 8.681" ~-i 98'Mr' ~ 3.12" LNR, 8.81*, L-~ STL, .0087 Dpf, ID = 2.992" `--"977-1_'_ WHIPSTOCK •-~ T" LNR, 29N, L-80 ®TC, .0371 bpf, D = 6.184' 1~ PERFORATION SIN~NAARY R~ L04. ANt3LE AT TOP PERF: 66' ~ 10286' Note: Refa to Produt~ioft DB to tlistoricar f date 512E SPF NTEth/AL DATE r 4 2360 -2520 s 03A6A4 r 6 1 o2e6 -10300 0 02119106 r 6 10465 -1 X10 0 o223A5 r 6 itlSSO -10660 0 0223105 1.56" 6 10725 -10775 O 042DA4 r 4 .10670 -10675 0 11107A2 1.56" 6 10675 -10925 0 0420104 r 4 10925 - i 0930 0 11 A7102 r 6 11090 -11140 0 09ld'I AS 1.56" 6 11350 -11425 0 0420x0+1 3-3H 8' LNR, 6.2N, L•80, I TCI m78 hn1 ®: 21?b" ST MD TVD ~ DEY ~~~ TYPE ~~ VLY LATCH PORT DATE 5 3532 3512 19 KBO-2 DMY BK 0 12/28AD5 4 5401 5105 39 KBf3-2 DMY BFf 0 12/28AD5 6810 6191 40 KBt3-2 DMY BK 0 03I~A4 2 6011 7128 36 K8t3-2 DMY BF( 0 03iD6~04 1 8956 7920 3D KB0.2 DMY BK 0 03>~A4 412"HESXN~,D=3.813" ~~ 7" X 412" BKR S-3 PKR, ID = 3.875" • 9102' 412" HES X NIP, ID = 3.813" 9121' 7"X5.12" X0, ID = 4.892" 9133' 412" MIRE SHOE, D = 3. "' 8" 9164' 9.518" X5.12" UNDUE OV ERSHOT i ( 9188 ( 8120 I ~ { K~3-2( DMY ( RA ( 0 ~ 10121AD1( 9231' $-518" X5-12" BRN PKR, ~ : ? 9242' S• fit" X 412" X0, D = 3.~ ~ - 9311~ 3-314" BKR DEPLOY SLV, ~ = 3.00" 9'318' 3.12" XD PtlV, D = 2.880" 9321' ~ 12" NOW CO XN N8-, D = 2.750" 9327' 412" NES XN N~, MLLED TO 3.80" 9340' ®ROWN SH6AROUT SUB, D = 3.958" 9771' 3.112" x 3-3r1er xo. q = s.e8o" ~ MILLOUT WNDOuN (M-1!A) 9834' -9839' ' ~~"I 718"x0, 7• ~ 2.377" MILLED a PuSH1En to eTA4(08123A7) h 2.719" LNR, 0.161, 480!, .00~ bpf, ID = i rt~~ = r Mc: WELLHEAD = FMC A,,CT~.IATOR.= ....................... A3CELSON ... KB. ELEV = .................................. BF ELEV . ..... ....-70' ................................ . = ''KOP = 3000' Max Angle = ]1 (~ 11509' ~ ~~~~~~~~ Datum MD = ...... ......... . ..... . 10058' Datum TVD = 8800' SS 91.5#, H-40, ID =19.124" ~~ ~~ ~~ ~po~ed CTD :.sidetrack 113.318" CSG, 72aM, L•80 BUTT, 10 = 12.347" I Minimum ID ~ 1.90" ~ 9710' TAP ~F 2~I8"LINER 9-5!$" HES ES CEMENTER --r 7" SCAB LNR, 26#, L-80 BTC-M, L-80, .0383 bpf , ID = 6.276" 4-112" TBG,12.6#,13CR VAM TOP, .0152 bpf ID = 3.958" 5.112" TUBING STUB SAF NOTES: ""4-112° CHRON~ TBG. 1885' 9-518" X 7" BKR ZXP PKR wJ C2 PROFILE ~ FLEX-LOCK LNR HGR, IO = 6.310" 2083' 4112" H ES X N IP, ID = 3.813" S 3532 3512 19 KBG-2 DMY BK 0 12/28105 a 5401 s1 OS 39 KBG-2 DMY BK 0 12128ADs 6810 6191 40 KBG-2 DMY BK 0 03/06A04 2 8011 7128 36 KBG-2 DMY BK 0 03/06N4 1 8958 7920 30 KBG-2 DMY Ed( 0 03N6N4 - 9026' 4112" H ES X N IP, ID = 3.813" - 9037' 7" X 4 12" BKR S-3 PKR, ID = 3.875" - 9102' 41x2" HES X NIP, ID = 3.813" 9133' 41x2" MULE SHOE, ID = 3.958" 9164' 9-518" X5-102" UNIQUE OVERSHOT GAS LIFT MANDRELS 9188 18120 I~ IKBG-21 DMY I RA 10 5-112" TBG,17#, L-80 BTC, 0232 bpf, ID = 4,892" TOP OF 7" LNR, BOT H4R L•80 BUTT, ID = .0087 bpf, ID = 91 231' 1 ~9.5P8" X 5.112" BRN PKR, ID = ? •~ 9242' 5-112" X 41 f2" X0, ID = 3.958" 9311' 3-314" BKR DEPLOY SLV, ID = 3.00" 9316' 3.112" XO PIN, ID = 2.880" 9321' 3112" H OW C 0 XN N IP, ID = 2.750" 9340' I-I 4112" TBG, 12.0*, L• 80 BTC, .0152 bpf , ID = 3.958" {~:q I 9700' 1~2-38" Top of Liner 9700' TOC LNR, 29rq, L•80 BTC, .0371 bpf, ID = 0.184" REF LO01 ANGLE AT TOP PERF: 68' ~ 10286' SEE PAGE 2 FOR PERFORATION DATA 3.3116" LNR, t3.2#, L•80, TCq, .0070 bpf, N) = 2.80" 3.3116" X 2.71'8" X0, ID = 2.377" DATE REV BY COMMENTS DATE REV BY COMMENTS 09M1/82 ROWAN 33 COMPLETION 121281U5 DAV/TLH GLV CIO 03M1f02 N3ES CTD SUSPENDED 01-19A 02M9106 RRDIPAG ADPERFS/CIBP 11/08102 NORDIC 1 CTD SIDETRACK (01-19A) 08126>n7 JGMISV MILLED CIBP (08C231U7) 03/07104 NOES R4V~0 09/15107 PJC W8S CORRECTIONS 03/04N5 BMcN/TLH ADPERFS 02l23AJ5 09021 !OS BMcN/fLH ADPERFS and 033 backer PRLIDFIOE BAY LIFNT WELL: 01-1 ~ PERMIT No: API No: 50-029-20800-02 T10N, R15E, 2233.27' FEL 8 2387.66' FNL BP Exploratkm (Alaska) 5 10 ~2UDHOE BAY, PRI~HOE ~ production Data 01-19A ~ Oil Rate (CD) (bbl/d ) ~~ Gas Rate (CD) (Mcf/d ) ~ Gas /Oil Ratio (cf/bbl ) -- --- Water Cut (% ) - -- Days on Prod .. r~ ~~ ~~~ 2 10- 103 • ~ 10 0 10- 2002 03 05 DATE n 06 07 08 03/02/2007 Schlumbepger SCANNED APR 1 0 2007 NO. 4170 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnklm 333 West 7th Ave, Suib3 100 Anchorage, AK 99501 d()d-()~d '1f: /91:> ~J Field: Prudhoe Bay WI! BL CD J b# L D . ti D t CI e 0 og escnp1 on ae o or 04-46 11477735 RST 12102106 1 1 01-19A 11513650 RST 11125106 1 1 W-06A 11657101 RST 01124107 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503_28, W k ATTN: Beth Q. ì Received by: (1_- . . i"---- Date Delivered: t11\ r¡ n ? ?Ofr,' H"'~ \ t~,:, ' ~. _, 1 f!( /-{ . . .. _ STATE OF ALASKA e AlAYA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: 70 KB Total Depth 11. Present Well Condition Summary: ADL-028329 Effective Depth Casing Conductor Surface Production Liner Liner Liner Liner Liner Liner Liner Perforation depth: measured 11584 true vertical 9010.01 measured 11551 true vertical 9015.79 Length Size 83 20" 91.5# H-40 2557 13-3/8" 72# L-80 9578 9-5/8" 47# L-80 7277 7" 26# L-80 529 7" 29# L-80 80 5-1/2" 17# L-80 98 4-1/2" 12.6# L-80 460 3-1/2" 9.3# L-80 126 3-3/16" 6.2# L-80 1687 2-7/8" 6.16# L-80 Measured depth: 10286 - 10300 True Vertical depth: 9005.69 - 9010.97 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P" Stratigraphic [J feet feet feet feet MD 34 - 117 33 - 2590 32 - 9610 1885 - 9162 9305 - 9834 9162 - 9242 9242 - 9340 9311 - 9771 9771 - 9897 9897 - 11584 10485 - 11425 Closed 9050.25 - 9030.81 4-1/2" 12.6# Stimulate D Other D WaiverD Time ExtensionD > ãr' Re-enter Suspended Well D CI> 5. Permit to Drill Number b 202-0220 =.: 6. API Number: :Þ m :;;1 ø 50-029-20800-01-00g. tI> 9. Well Name and Number: ;;; (C! fO o D o Exploratory Service s: ::c o :::0 01-19A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) TVD 34 - 117 33 - 2589.94 32 - 8489.55 1884.98 - 8097.31 8223.1 - 8682.35 8097.31 - 8167.7 8167.7 - 8253.85 8228.38 - 8628.34 8628.34 - 8734.72 8734.72 - 9010.01 13Cr80 7" Baker ZXP Packer 4-1/2" Baker S-3 Perm Packer 5-1/2" Brown Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. 10310 None en en S' ::::¡ Burst 1490 4930 6870 7240 8160 7740 8430 10160 Collapse 470 2670 4760 5410 7020 6280 7500 10530 13450 13890 \:';! (?, 29-9133 1885 9037 9231 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN 44248 17 600 484 15. Well Class after proposed work: Exploratory Development P'i Service 16. Well Status after proposed work: Oil P' Gas [J WAG WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 862 x Contact Sharmaine Vestal P"oted Nam, Sham:a'oov"", ~ k..·.. Signatu~J Title Data Mgmt Engr Phone 564-4424 Form 10-404 Revised 04/2004 0 RIG I N A L MAR 2 3 Z006 a:¡~submit Original Only Date 3/21/2006 · e e 01-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARy"...., 2/17/2006 T/I/O=161 0/900/21 O. Temp=SI. Tbg & FLs (Pre CIBP) EL. TBG FL @ 4966', IA FL @ 966'. 2/19/2006 SET BAKER 2.22" CIBP AT 10310'. PERFORATED FROM 10286' TO 10300' USING 2.0" HSD 2006 PJ OMEGA GUN. NO PROBLEMS RIH OR POOH. FINAL TI 110 = 1500/930/200. TURNED WELL OVER TO DSO. WELL LEFT SHUT IN. BBLS 1 :1 ,+ FLUIDS PUMPED 1 I ::::L . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ) ') R:JI E" '" C E'''' ~'VE ' ..-: ~<; '= I ",., OCT 2, 6 2005 WELL LOG TRANSMITTAL ŒII 8i Gom~.Commission To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Anf;li){ji!r~;n;G February 23, 2004 RE: MWD Fonnation Evaluation Logs: 01-19A, AK-MW-22177 Ol-19A: Digital Log Images 50-029- 20800-01 tt- I 31)1 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:;{ g G' ~~, Signed: µ&Lv . ....i<-........ - -_."....,...... ... -....J. ...."......,..._....'~,.,.. ~ANNED OCT 3 1 2005 ,. ^ 0 ^' - ()~,~F.'(~ RECEIVED OCT 1 9 2005 STATE OF ALASKA . Al. Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATION D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: 70 KB ADL-028329 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Liner Liner Liner Production Liner Liner Liner Liner Perforation depth: measured 11584 true vertical 9010.01 measured 11551 true vertical 9015.79 Packers and SSSV (type and measured depth) Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M Stratigraphic 0 feet feet feet feet MD 34 - 117 33 - 2590 1885 - 9162 9162 - 9242 9242 - 9340 32 - 9610 9311 - 9771 9305 - 9834 9771 - 9897 9897 - 11584 10550 - 10660 9045.72 - 9037.95 4-1/2" 12.6# Stimulate D Other I;J h . WaiverD Time Extension r:rC ~age Re-enter Suspended Well D 5. Permit to Dril~umber: 2<Ø22O o 6. API Number: 50-029-20800-01-00 Exploratory Service 9. Well Name and Number: 01-19A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) TVD 34 - 117 33 - 2589.94 1884.98 - 8097.31 8097.31 - 8167.7 8167.7 - 8253.85 32 - 8489.55 8228.38 - 8628.34 8223.1 - 8682.35 8628.34 - 8734.72 8734.72 - 9010.01 10725 - 10775 9036.79 - 9036.11 13Cr80 7" Baker ZXP Packer 4-1/2" Baker S-3 Perm Packer 5-1/2" Brown Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Length Size 83 20" 91.5# H-40 2557 13-3/8" 72# L-80 7277 7" 26# L-80 80 5-1/2" 17# L-80 98 4-1/2" 12.6# L-80 9578 9-5/8" 47# L-80 460 3-1/2" 9.3# L-80 529 7" 29# L-80 126 3-3/16" 6.2# L-80 1687 2-7/8" 6.16# L-80 Measured depth: 10485 - 10510 11350 - 11425 True Vertical depth: 9050.25 - 9048.56 9030.37 - 9030.81 Tubing: (size, grade, and measured depth) Oil-Bbl 267 373 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Priot" N,me Sh,m""e Ve,lal _ ¿ Signatu~~ Form 10-404 Revised 04/2004 None None Burst 1490 4930 7240 7740 8430 6870 10160 8160 Collapse 470 2670 5410 6280 7500 4760 10530 7020 13450 10870 - 1 0930 13890 11090 - 11140 9033.2 - 9032.62 9026.61 - 9024.27 29 - 9144 1885 9048 9231 w- Tubing pressure 1310 1758 Service WDSPL 0 Title Data Mgmt Engr Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 14593 34 800 21170 17 500 15. Well Class after proposed work: Exploratory OJ Development M 16. Well Status after proposed work: Oil M Gas 0 WAG Phone 564=2I2rL4 Date 10/14/2005 RBDMS 8Fl 0 C1 2 (J)qgQ3it Original Only e e 01-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY IACTIVITY9~l'E I .c.. SUMMARyt;;~~" ·~~j'H;;~.'¡¡h;'¡1 9/20/2005 CTU#9: Memory log/Perforating. ***Well SI Upon Arrival*** MU/RIH w/ PDS 2.2" GR/CCL carrier and 2.25" JSN. Logged interval from 11375' to 10250'. Painted flag at 11080' CTMD. Depth correction (-24') tied into SWS MCNL - 11/7/2002 *** Continued WSR on 9-21-2005 *** 9/21/2005 CTU #9. Perforating. *** Continuation of WSR 9-20-2005 ***. RIH with Gun #1 (25' - SWS 2.00" HSD-PJ2006 HMX @ 6 spf). Correct depth to top shot at flag. Perforate interval 11115' to 11140'. POOH. All shots fired. RIH with Gun #2 (25' - SWS 2.00" HSD-PJ2006 HMX @ 6 spf). Correct depth to top shot at flag. Perforate interval 11 090' to 11115'. POOH. All shots fired. FP well with meth. Blow down coil with N2. RDMO. FLUIDS PUMPED BBLS 168 50/50 Meth 1000 Gallons N2 140 1 % KCL w/1.5% Lubetex . ) STATE OF ALASKA ) Ø~CE' 'IV·E'D ALASKA OIL AND GAS CONSERVATION COMMISSION "I: '..., REPORT OF SUNDRY WELL OPERATIONS>~ 1 ~ 2ðð§ 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program 0 2. Operator Name: 3. Address: Repair Well 0 PluQ PerforationsD Pull Tubing D Perforate New Pool D Operation Shutdown D Perforate [K] 4. Current Well Class: Development Œ] BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 70.00 8. Property Designation: ADL-028329 11. Present Well Condition Summary: Total Depth Stimulate CAlaska Oil & Gas ({S\R§rÊ¥mmi..ion WaiverD TirrA1mMti9~D Re-enter Suspended WellO 5. Permit to Drill Number: 202-0220 6. API Number 50-029-20800-01-00 Exploratory 0 Stratigraphic 0 9. Well Name and Number: 01-19A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Service 0 measured 11584 feet SCANNEC~ ~\PR 2 5 Z005 true vertical 9010.0 feet Plugs (measured) None measured 11551 feet Junk (measured) None true vertical 9015.8 feet CONDUCTOR LINER LINER LINER LINER LINER LINER LINER PRODUCTION SURFACE Perforation depth: Measured depth: 10485 - 10510, 10550 -10600,10725 -10750, 10750 - 10775, 10870 - 10875, 10875 -10900, 10900 -10925 10925 -10930,11330 -11350,11350 -11375,11375 -11400,11400 -11425,11425 -11470 True vertical depth: 9050.25 - 9048.56,9045.72 - 9041.69,9036.79 - 9036.43,9036.43 - 9036.11,9033.2 - 9032.98,9032.98 - 9031.98 9031.98 - 9032.39, 9032.39 - 9032.62, 9028.49 - 9030.37, 9030.37 - 9031.28, 9031.28 - 9031.07, 9031.07 - 9030.81 9030.81 - 9028.72 Tubing ( size, grade, and measured depth): Effective Depth Casing Length 83 529 7277 80 460 1687 126 98 9578 2557 Packers & SSSV (type & measured depth): 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations _ Size 20" 91.5# H-40 7" 29# L-80 7" 26# L-80 5-1/2" 17# L-80 3-1/2" 9.3#L-80 2-7/8" 6.16# L-80 3-3/16" 6.2# L-80 4-1/2" 12.6# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 4-112" 12.6# 13Cr80 5-112" Brown Packer 4-1/2" Baker S-3 Perm Packer 7" Baker ZXP Packer Oil-Bbl 441 512 MD 34 9305 1885 9162 9311 9897 9771 9242 32 33 117 - 9834 - 9162 - 9242 - 9771 - 11584 - 9897 - 9340 - 9610 - 2590 TVD 34.0 8223.1 1885.0 8097.3 8228.4 8734.7 8628.3 8167.7 32.0 33.0 - 117.0 - 8682.4 - 8097.3 - 8167.7 - 8628.3 - 9010.0 - 8734.7 - 8253.9 - 8489.6 - 2589.9 @ @ @ @ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 23.1 7 1200 28.4 9 1200 Contact Printed Name Signature 29 9144 9231 9048 1885 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: Oil Œ] GasD ! Garry Catron Garry Catron ."L3ß' Ca~~ Form 10-404 Revised 4/2004 Burst 1490 8160 7240 7740 10160 13450 8430 6870 4930 Development ŒI Collapse 470 7020 5410 6280 10530 13890 7500 4760 2670 Tubing Pressure 1604 1110 Service 0 WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA O R \ G , ~.-.I. it.l~ L Production Technical Assistant ï . \ \ ~'~ e 564-4657 Date ~ "" iJ R~Dft15 Lf ~ 4/15/05 ') -) 01-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/22/05 Perforate 105751.10600. 6 SPF 02/23/05 Perforate 104851.1051016 SPF, 105501-1057516 SPF BBLS 137 60/40 Methanal 110 1 % KCL 247 TOTAL FLUIDS PUMPED Page 1 TREE = FMC W.ELLHEAD"'= FMC ...'^""'"''''''''''..................~,....,...,..,.,.''''......,',.............,-'....,.,".........,''"''''''''"^'~'''''''~' ACTUA TaR = AXELSON ",.,.""""""",.,..""""",. KB. ELEV = 70' ~,^"",...,......."",~,.. BF. ELEV = KOP = 3000' _I'I',.,.,..,.,.,.,.........,.,...,..,.'''''''''''IWW,.,.....~M...'_''''''''''''',.,.IY''''IYHI'<'M"IW'IY''''''''''''''''IW' .~~~,..~.,~9..I.:...~......1g.~..^,®...~...~5~.~.: Datum MD = 10053' Datum TVD = 8800' SS ) 01-19A 1 7" CSG, 26#, BTC-M, L-80, ID = 6.276" l-i 9120' I 14-1/2" TBG, 12.6#, 13-CR. .0152 bpf, ID = 3.958" I-{ 9133' I ~~ ~ I I ~ '~ 1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" l-i 9242' I \ l- I TOP OF 7" LNR, BOT HGR I-{ 1--71 ~ 9305' 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" Ii 9340' I 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I-{ 9610' ~ ~ 1 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" I-{ 9771' I 113-3/8" CSG, 72#, L-80, ID = 12.347" I-{ 2590' I~ Minimum ID = 2.377" @ 98971 TOP OF 2-7/8" LINER ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 94 @ 10485' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 23g0 .. 2520 S 03/06/04 I L SAr -) NOTES: ***4-1/2" CHROME TBG. 1885' I-{ 9-5/8" X 7" BKR ZXP PKR W/ C2 PROFILE I 2083' I I 4-1/2" HES X NIP, ID = 3.813" I ~ S5T 4 3 2 1 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 19 KBG-2 DOME BK 39 KBG-2 SO BEK 40 KBG-2 DMY BK 36 KBG-2 DMY BK 30 KBG-2 DMY BK PORT DATE 16 03/13/04 20 03/13/04 03/06/04 03/06/04 03/06/04 MD 3532 5401 6810 8011 8958 TVD 3512 5105 6191 7128 7920 9026' I I 4-1/2" HES X NIP, ID = 3.813" I 9037' I-{ 7" X 4 1/2" BKR S-3 PKR, 10 = 3.875" I 9102' II 4-1/2"HESXNIP,ID=3.813" I 9121' I-{ 7" X 5-1/2" XO, ID = 4.892" I 9133' 1--1 4-1/2" MULE SHOE, ID = 3.958" I 9162' 1-1 9-5/8" X 5-1/2" UNIQUE OVERSHOT 1 9188' 1-1 5-1/2" GLM 1 9231' 1-1 9-5/8" X 5-1/2" BROWN PKR 1 9242' I-L 5-1/2" X 4-1/2" XO I 9311' I-{ 3-3/4" BKR DEPLOYMENT SLV, ID = 3.0" 9321' I-{ 3-1/2" HES XN NIP, ID = 2.750" I MILLOUT WINDOW 9834' - 9839' 9771' I-{ 3-1/2" X 3-3/16" XO, ID = 2.880" I 9830' I-{ TOP OF WHIPSTOCK I I-{ 3-3/16" X 2-7/8" XO, ID = 2.440" I 2" 6 1 0485 - 1051 0 0 02/23/05 2" 6 1 0550 - 1 0660 0 02/23/05 1.56" 6 10725 - 10775 0 04/20/04 2" 4 10870 - 10875 0 11/07/02 1.56" 6 10875 - 10925 0 04/20/04 2" 4 10925 - 10930 0 11/07/02 1 11551' I-{ PBTD I 1.56" 6 11350 - 11425 0 04/20/04 17" LNR, 29#, L-80, .0371 bpf, ID=6.184" I-{ 10500' I I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" I-{ 9897' I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I-{ 11584' REV BY DATE 04/04/04 04/20/04 05/08/04 03/04/05 REV BY COMMENTS I BJMcNfTLP CORRECTIONS TO DRLG DRAFT DA V /KA K A DPERFS KS/KA K PERF CORRECTIONS BJMcNfTLH ADPERFS (02/23/05) PRUDHOE BAY UNIT WELL: 01-19A PERMIT No: 2020220 API No: 50-029-20800-01 SEC 6, T10N, R15E, 2233.27' FEL & 2387.66' FNL DATE 09/11/82 09/11/82 03/11/02 11/08/02 03/07/04 03/13/04 COMMENTS ORIGINAL COM PLETION LAST WORKOV ER CTD SUSPENDED (01-19A) CTD SIDETRACK (01-19A) RWO GLV C/O DC RlKK JBM/KK JBMlKK BP Exploration (Alaska) '6 bJ..-L Á.-Ú~~ '1. DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2020220 Well Name/No. PRUDHOE BAY UNIT 01-19A Operator BP EXPLORATION (ALASKA) INC MD 11584/' ~ ----+--- --- -~--~.~~-~----- TVD 9010 /" Completion Date 11/8/2002 / Completion Status 1-01L --. - ---"------- --~_.-~---~_u_-- REQUIRED INFORMATION Mud Log No Samples No .~-------~~~-------- ~--_._--~._----------~~ DATA INFORMATION Types Electric or Other Logs Run: MWD. GR, ROP, RES, CNL, CCL Well Log Information: Log/ Data Digital Type M~d/Frmt , -ED-z:.ør --- ~- - ~'- ro D ~' D Rpt /' tA--ð9 LEtf C Rpt Log I~D ....... C Pdf (.,ED C Pdf £ÆD C Lis 4'D C Lis Electr Dataset Number Name Directional Survey Gamma Ray 6,1661 LIS Verification q.c1'f44 See Notes Directional Survey Log Log Scale Media Run No 1 1 1 1 1 25 Blu Neutron 1JßJ"t See Notes 25 Blu LIS Verification Leak Blu ('12424 Rate of Penetration \ 12424 Induction/Resistivity 25 1-5 25 1-5 12424 Rate of Penetration 1-5 ..,1'2424 Induction/Resistivity 1-5 - -~-------~-----~-_._--~---_._~ Well Cores/Samples Information: Name Interval Start Stop Sent Received Current Status 1-01L API No. 50-029-20800-01-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 9800 11584 8966 11531 9752 9106 9800 8966 8985 9752 100 9850 OH/ CH Received Comments Open 12/6/2002 Case 2/7/2003 11539 Open 4/17/2003 9841 Open 4/8/2002 Jewelry log 11584 Open 12/6/2002 11531 Case 2/7/2003 11530 Case 2/7/2003 LDWG edit digital data 11539 Open 4/17/2003 11584 Open 2/26/2004 9430 Case 5/30/2003 CULLED 9850 11584 Open 2/26/2004 9850 11584 Open 2/26/2004 9850 11584 Open 2/26/2004 Sample Set Number Comments ROP, DGR, EWR - Horizontal Presentation - MWD ROP, DGR, EWR- Horizontal Presentation - MWD ROP, DGR, EWR - Horizontal Presentation - MWD ROP, DGR, EWR - Horizontal Presentation - MWD -- Permit to Drill 2020220 MD 11584 TVD 9010 Well Cored? ADDITIONAL INFORMATION Y~ Chips Received? Analysis Received? --- - _.- -------.-~~---- Comments: rtN-- YïN ---,--- ----------- - --~-~----~- ---~------,_._._-_._- ----- --"'--_.~-------~------~-~- Compliance Reviewed By: - DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Well Name/No. PRUDHOE BAY UNIT 01-19A Operator BP EXPLORATION (ALASKA) INC Completion Date 11/8/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? (DN Formation Tops .,~ C!JN ç:-O Date: API No. 50-029-20800-01-00 UIC N ! ---- &(J~~ ~ \~- --- ""i\¡¡ ALASKA ~IL AND ~~ST~g~S~~;:~ON COMM!SSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAY 102004 1. Operations Performed: Abandon D Alter Casing D ChanÇJe Approved ProÇJram D 2. Operator Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Alaska U¡¡ & Gas (;ons. l;Ol!ID.1iSS'O Perforate ŒI WaiverO Anchorag~therU Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0220 Suspend D RepairWellD Pull TubinÇJ D Name: BP Exploration (Alaska), Inc. 70.00 8. Property Designation: ADL-0028329 11. Present Well Condition Summary: Development Œ] StratiÇJraphic D 9. Well Name and Number: 01-19A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): ExploratoryD Service D Total Depth measured 11584 feet true vertical 9010.0 feet Plugs (measured) Junk (measured) Effective Depth measured 11551 feet true vertical 9015.8 feet 6. API Number 50-029-20800-01-00 None None Casing Length Size MD TVD Conductor 83 20" 91.5# H-40 34 117 34.0 - 117.0 Liner 7277 7" 26# L-80 1885 - 9162 1885.0 - 8097.3 Liner 80 5-1/2" 17# L-80 9162 - 9242 8097.3 - 8167.7 Liner 98 4-112" 12.6# L-80 9242 - 9340 8167.7 - 8253.9 Liner 529 7" 29# L-80 9305 - 9834 8223.1 - 8682.4 Liner 460 3-1/2" 9.3# L-80 9311 - 9771 8228.4 - 8628.3 Liner 126 3-3/16" 6.2# L-80 9771 - 9897 8628.3 - 8734.7 Liner 1687 2-7/8" 6.16# L-80 9897 - 11584 8734.7 - 9010.0 Production 9578 9-5/8" 47# L-80 32 - 9610 32.0 - 8489.6 Surface 2557 13-3/8" 72# L-80 33 - 2590 33.0 - 2589.9 Measured depth: 10725 -10750,10750 -10775, 10870 -10875,10875 -10900, 10900 -10925, 10925 -10930 11350 -11375,11375 -11400,11400 -11425,11425 -11470 True vertical depth: 9036.79 - 9036.43, 9036.43 - 9036.11, 9033.2 - 9032.98, 9032.98 - 9031.98, 9031.98 - 9032.39, 9032.39 - 9032.62 9030.37 - 9031.28,9031.28 - 9031.07,9031.07 - 9030.81,9030.81 - 9028.72 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 29 9144 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 141.1 812 720 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 5-1/2" Brown Packer 7" Baker ZXP Packer @ 9048 @ 9231 @ 1885 13 Prior to well operation: Subsequent to operation: Oil-Bbl 2600 2082 8.8 14 14. Attachments: 15. Well Class after proposed work: Exploratory D Burst 1490 7240 7740 8430 8160 10160 13450 6870 4930 1075 Development 00 Collapse 470 5410 6280 7500 7020 10530 13890 4760 2670 Tubing Pressure 398 1007 Service 0 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run - Daily Report of Well Operations - K 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature Jj(~ Cø~ Form 1 0-404 Revise~ 12/2003 564-4657 Production Technical Assistant 5/7/04 Title ORIGINA[e Date t~tl0 ) ) 01-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/14/04 CTU #5: FCO/ADD PERF. RIH WITH 2.25" 3-BLADE JUNK MILL. TAG AT 9444' CTMD. CLEAN OUT TO 9935' W/ MOTOR STALLS @ 9799'. MULTIPLE STALLS @ 9935', UNABLE TO PROCEED. POOH TO INSPECT MOTOR. RIH W/ 2" JSN. «CONTINUED ON 4/15/04 WSR» 04/15/04 CTU #5: FCO/PERFORATE. CONTINUED. RIH W/2" JSN, CONTINUE CLEAN OUT FROM 9930' TO 11,549' (PBTD), JET OUT HOLE AT 80% USING GL ASSIST AT -0.7 MMSCF. RIH W/ GR/CCL LOGGING STRING. CONTINUED ON 4/16/04. 04/16/04 CTU #5: CONTINUED FROM 4/15/04. FCO/LOG FOR PERF GUNS. RUN TIE-IN SLB MEMORY GR/CCL LOG. LOGGED FROM 11450', HUNG UP AT 10400', WORKED FREE. DECISION MADE TO RUN VENTURI JUNK BASKET, UNABLE TO RIH BEYOND 10,277'. RECOVERED 2 CUPS GRAVEL AND METAL PIECES 5/8" X 1/4". MADE 2ND VENTURI RUN. CONTINUED ON 4/17/04. 04/17/04 CTU #5: CONTINUED FROM 4/16/04: FCO/PERF. RIH W/WFD 2.25" X VENTURI. HOOVER FROM 10270' TO 11461' CTMD AND SET DOWN 4K. POOH. RECOVERED 1/2 GALLON MATERIAL. CUT COIL. RIH WITH SWS MEMORY GAMMA/CCL W/2.20" CARRIER. SAT DOWN AT 10780', UNABLE TO WORK PAST, FLAG PIPE AT 10,777' CTMD, LOG TO 9700', POOH. ALL PERFS CORRELATED TO SLB MEMORY GR/CCUCNL DATED NOV. 7, 02. PERFORATE FROM 11,400' - 11,425' MD. CONTINUED ON 4/18/04 WSR. 04/18/04 CTU #5: CONTINUED FROM 04-17-04. PERFORATING. POOH W/ 1ST GUN (11,400'- 11,425') MD. RIH W / 2ND PERF GUN, (25' OF 1.56" 6 SPF 1606 PJ). PERF 11,375' - 11,400', POOH. RIH W/ 3RD PERF GUN, (25' OF 1.56" 6 SPF 1606 PJ). PERF 11,350'- 11,375', POOH. CONTINUED ON 4/19/04. 04/19/04 CTU #5: CONTINUED FROM 4/18/04. PERFORATING: RIH W/ SLB MEMORY GR/CCL. LOG FROM 11000' TO 9775' MD. TIE INTO SWS MEM GR/CCUCNL LOG DATED 11/07/02. PERFORATE 50' W/ 1.56" 6 SPF 1606 PJ GUNS IN 2 GUN RUNS. CUT 100' FROM COIL. PERFORATE 10,750'-10,775' MD. PERFORATE 10,900'-10,925' MD. CONTINUED ON WSR 4/20/04. 04/20/04 Perforate 10725'-10750' 6 SPF, 10875'-10900' 6 SPF FLUIDS PUMPED BBLS 412 293 110 799 787 2401 60/40 Methonal Diesel Biozan Xslick 1 % KCL Slk 1 % KCL w/lub-tex TOTAL Page 1 ) ) 01-19A Completion 1REE = F~ WELLHEAD = F~ '",^","^............,................. .mm.m nonm " ,_...,w.''''~'''',"^''"^'''''''''"^''''''''''''''''''~'''''' AC1UA TOR = AXELSON ",,,,,,,,,,,,,,,.......,..,..W"""""',,,,,,,,,,,,,,,,..'.",,,"^,""".,.....,,-""'''''' "........"..... """.W.''''',,,,,,,,,,,.,,, KB. I3..EV = 70' sF'. I3..EV;-~~~--~~~ KOP~';---~~'~-~~~3006Î iVax'An-¡~ïe"'=~16f@f1. 509ï .oaturrïï\ÏÖ..;~..m...""".""'''.'.1'.ó653ï ï:~tuïn..i\/Ö = a"S"ÖO'SS 13-3/8" CSG, 72#, L-8Q, 10 = 12.347" H 2590' Minimum ID = 2.377" 2-78" LINER COLLARS H 1 4 1/2" "X" NIPR..E !D = 3,813" H 1 T' CSG, 26#, BTC-M, L-80, ¡O :::: Ô.27Ô'H r 41/2" "X" NiFPLE D '" 3.813" 14-1/2" TBG, 12.6#. 13Cr80. ¡O =: 3.958" 9133' 9026' 9120' H 9102' 5-1f2"lBG-PC, 17#, L-80, .0232bpf, 10=4.892" H 9242' 1 TOP OF 7' LNR, BOT HGR H 9305' 4-1/2"TBG, 12.6#, L-80, .0152 bpf, 10= 3.958" H 9340' ~ 1 9-5/8" CSG, 47#, L-8Q, 10= 8.681" H 9610' --4 1 3-1/2" LNR, 8.81#, L-80, .0087 bpf, 10 = 2.992" H 9771' ÆRFORA 1l0N SlJv1M1\RY REF LOG: ANGLE AT TOP PERF: 92 @ 10870' Note: Refer to Production œ for historical perf data SIZE SPF INlER\! AL Opn/Sqz OA TE 2" 4 10870-10930 0 11/07/02 2" 4 11330-11470 0 11/07/02 ~"..".~.m_.."m'l 1885' H BAKER ZXPPACKER WI C2 PRORLE -,,-1 2083' 1 I 4-'1i2" X NlFPLE 10:::: 3.8'13" I 1 ~ GASUFTMANDRa.S a ST MD TVO DE\! lYPE VlV LATCH 5 3532 3511 18 KBG-2 OMY BK 4 5401 5105 39 KBG-2 DCK-2 Ba< 3 6810 6188 40 KBG-2 OMY BK 2 8011 7128 36 KBG-2 DMY BK 1 8958 7919 30 KBG-2 DMY BK PORT DA lE 03106/04 03/06/04 03/06í04 03/06/04 03/06/04 9037' H BAKER4 1/2" x 7" 8-3 PKR !D '" 3,875" 9162' H UN!QUE OVffi8HOT I 9231' H 9-5/8" X 5-1 f2" BROWN PKR I ~ 9242' H 5-1/2" X 4-1/2" XO 1 ./A ~ 1 9311' H 3-3/4" BKROEPLOYrvENTSLV, 10 =3.0" ~ 9321' H 3-1/2" I-ESXNNIP, 10=2.750" 1 ~ I MLLOvr WINDOW 9834' - 9839' 9771' H 3-112" X 3-3/16" XO, D =2.880" 1 9830' H TOPOFWI-IPSTOCK 1 H 3-3116" X 2-718" XO, 10 = 2.440" 1 7"lNR, 29#, L-80, .0371 bpf, 10 = 6.184" H 10500' DÐ-l 10505' 13-3116" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.800" H 9897' I 11551' H PBTO 1 I 12-7/8" LNR,6.16#, L-80, .OO58bpf, 10=2.441" H 11584' 1 DATE 09/11/82 09/11/82 03/11/02 11/08/02 11/13/02 04/24/03 REV BY D<\ TE REV BY 00 Mv1ENTS 05/16/03 BJrvvTLH SET IBP & ANN COMM NOTE 00 MrvENfS ORIGINAL COMPLETION LAST WORKOV ER CTDSUSPENŒD (01-19A) DCRlKK CTDSIŒTRACK (01-19A) M-i/KA K GL V C/O KBlTP MN D & LNR TOP R<R - 9301' FRU~OE SA Y UNIT W8..L: 01-19A ÆRMIT No: 2020220 API No: 50-029-20800-01 SEC 6, T10N, R15E. 223327' FEL & 2387.66' FN... 8P Exploration (Alaska) ...... STATE OF ALASKA \ ALASKA_.l AND GAS CONSERVATION COav,,~ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 70' 8. Property Designation: ADL 028329 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 80' 2590' 9610' 529' 2273' 7279' Liner Liner Tieback Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Suspend ~ Repair Well ~ Pull Tubing 11584 9010 11551 9016 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic Test 0 Service 99519-6612 feet feet feet feet Size 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 7" 10870' - 11470' 9033' - 9029' Tubing Size (size, grade, and measured depth): 0 Waiver 0 Time Extension 0 Annular Disposal 5. Permit To Drill Number 202-022 6. API Number: 50-029-20800-01-00 0 Other 9. Well Name and Number: PBU 01-19A 10. Field / Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 80' 80' 1490 470 2590' 2590' 5380 2670 9610' 8490' 6870 4760 9305' - 9834' 8223' - 8682' 8160 7020 9311' - 11584' 8228' - 9010' 1885' - 9164' 1885' - 8099' 7240 5410 4-1/2" 12.6# x 5-1/2" 17# x 4-1/2" 12.6# 13Cr 1 L-80 9340' Packers and SSSV (type and measured depth): 7" Baker liner top packer at 9311'; 9-5/8" x 5-1/2" Brown 4-1/2" 'X' Nipple at 2083' packer at 9231'; 4-1/2" x 7" 'S-3' packer at 9037'; 9-5/8" x 7" Baker 'ZXP' packer at 1885'; REC'1:'.VI::U APR - 6 2004 Treatment description including volumes used and final pressure: Casing Leaks (See also Daily Drilling Reports) First attempt: 29.5 Bbls AS I, failed. s~co~ffiitCtft9.;¡~b~SßØtial success. Ran 7" Tieback Liner, cemented in place, passed. A'aSKa , .. . a nP-høra~ Representative Daily Average Production~r'nJectlon Data Gas-Met Water-Bbl CasinQ Pressure 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2413' - 2553' (Approximately) 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations 0 Well Schematic Diagram TubinQ Pressure 15. Well Class after proposed work: 0 Exploratory II Development 0 Service 16. Well Status after proposed work: II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 N/A Printed Name Terrie Hubble Signature ~Ñ\i1.. .N,,1~ Form 10-404 Revised 12/200~" 0 RIG I.~ A L Title Technical Assistant Phone Date Co/ocP (ff-{ Prepared By Name/Number: Terrie Hubble, 564-4628 564-4628 RR:nM~ RF. JUV\ .. "t",u ') ) Well: Field: API: Permit: 01-19A RWO Prudhoe Bay Unit 50-029-20800-01-00 202-022 Accept: Spud: Release: Rig: 02/20104 NIA 03/06/04 Nabors 4ES PRE-RIG WORK 12/06/02 DRIFT WI 3' STEM, 2.15 CENT., AND SAMPLE BAILER. TAGGED @ 4908' SLM AND OBTAINED SAMPLE OF CLAY TYPE MATERIAL. 12/23/02 RIH WITH 3" DJ NOZZLE TO 5400. NO BRIDGE @ 4809' SLM AS REPORTED. WELL IS TAKING FLUID. POH. RIH WI 2" JET SWIRL NOZZLE, SID AT 2 7/8" XO @ 9897', PUH AND DROP THROUGH NO PROBLEM. JET TO TD @ 11565' CTM. CHASE SOLIDS TO SURFACE AT 80% BASED ON RETURNS OF 1 1/4 : 2. 02/24/03 DRIFT 4' X 2.50" DRIVE DOWN BAILER THRU 3-1/2 LNR TOP @ 9318' SLM, STOP @ 9400' SLM (TARGET) AND POH WI ABOUT 1/2 GALLON OF liVERY THICK MUD" IN BAILER - TAG 3-1/2 LINER TOP @ 9318' SLM WI 3.70" LIB (CLEAN G FN) - LRS PUMP 291 BBLS WATER TO FLUSH TBG- SET LINER TOP TEST TOOL @ 9318' SLM - PUMP 25 BBLS 60/40 WI NO PRESSURE GAIN. 02/25/03 PULL LINER TOP TEST TOOL AFTER FAILED MIT ON TBG. WELL LEFT SHUT IN. 03/03/03 DRIFTED TO 3.5 XN NIPPLE W/2.84 CENT., AND 5' OF 2.5 DD BAILER. TAGGED XN @ 9320' SLM (DID NOT OBTAIN SAMPLE). SET CAT STANDING VALVE @ 9319' SLM. MIT TBG. FAILED. PULL STANDING VALVE. DRIFT WI BARBELL, 3.81" TO LINER TOP. RDMO. 04/20/03 WASH PACKER SEAT AND DEPLOYMENT SLEEVE WITH DIESEL, BIO SWEEPS, AND 1% KCL WATER. CHASE OUT @ 80%. MUIRIH WI BAKER KB LINER TOP PKR. LOADIFLUID PACK WELLBORE WI 1%KCL. TAG DEPLOYMENT SLEEVE @ 9332'. PUMP DOWN BACKSIDE. NO PT. GET POSITIVE COIL PRESSURE CONFIRMATION OF SLEEVE ENGAGEMENT. RETAG FOR SP ACEOUT. 04/21/03 TAG DEPLOYMENT SLEEVE, WORK SPACEOUT DEPTHS. PARK @ 9325', DROP 5/8" BALL, CIRC TO SETTING TOOL. SET DOWN IN DEPLOYMENT SLEEVE, PU FOR SPACE OUT. SET KB @ 9328' (CTM). COULD NOT GET PT ON BACKSIDE. TRIED TO PULL RELEASE, TRIED TO PUMP SHEAR OFF KB. FINALLY PULLED FREE. POOH. TAG IN TREE. RECIPROCATE AND WORK TOOLS, PUMP AROUND PACKER AND WORK UNTIL PACKER CAME FREE. POP OFF WELL. REMOVE BHA. KB PACKER WAS RETRIEVED, LESS 1 RUBBER ELEMENT. FP WELL TO 2500' WI METH/WTR. RDMO. 04/22/03 RAN 4-PRG GRAB. RETRIEVE RUBBER ELEMENT, FROM 9526 WLM. NOTE 1" PIECE OF ELEMENT MISSING. START IN HOLE W/CALLlPER. 01-19A, Rig Workover, Pre-Rig. . Jk Page 2 ) 04/24/03 RIH WI LINER TOP PACKER. TAG UP AND STAB INTO LINER. SPACE OUT AND DROP 5/8" BALL. PRESSURE UP TO 2500 PSI AND ATTEMPT TO TEST DOWN BACKSIDE. UNABLE TO GET A GOOD TEST, PRESSURE UP DOWN THE COIL AND SHEAR OFF THE PKR, POOH. RIH WITH GH SEAL UNIT. STING INTO PACKER AND JAR (3 TIMES). PUMP BS VOLUME, PRESSURED UP TO 300 PSI @ 3.8 BPM. IA PRESSURE INCREASED -80 PSI. POOH. FIP TUBING AND IA. JOB COMPLETE. 05/11/03 LOGGED LEAK DETECTION LOG WHILE PUMPING CRUDE DOWN TUBING. ORIGINAL SUSPECT INTERVAL NOT LEAKING. FOUND LEAK: 70% INTO 2380-2390,30% SPREAD OVER 2390-2440. TEMPERATURE INDICATES FLUID LEAKING OUT TUBING BUT NOT FLOWING DOWN IA. LEAK WAS TAKING 3 BPM AT 350 PSI PUMP PRESSURE. SEE EVENT LOG FOR FURTHER DETAILS. 05/16/03 DRIFTED WI 2.77" CENT AND SAMPLE BAILER TO 9292' SLM. CALIPER TUBING FROM 9270' SLM TO SURFACE (GOOD DATA). BAKER 2.5" IBP SET IN 4.5" TUBING WITH MID OF ELEMENT AT 9250'. TOP OF FISHING NECK AT 9243' - 3' BELOW MILLOUT EXTENSION. 12/17/03 DRIFT TO 5.5" X 4.5" XO W 4.5" CENT @ 9213' SLM 29' CORRECTION, XO AT 9242' MD. (PRE RWO). 12/18/03 DUMP BAIL 75 LBS OF SLUGGETS ON TOP OF IBP, FILL @ 9225'SLM. APROX 8' (75#) OF SLUGGITS ON TOP OF IBP. (PRE RWO) 12/20/03 CHEM CUT 5.5" TUBING AT 91571, BETWEEN BOTTOM TWO GLM'S, TIED INTO TTALLLY, TUBING PUNCHED AT 9140-9142'. 01/04/04 T/I/O=SI/160/50. BLEED IA & OA (PREP FOR RIG). IA FL @ SURFACE. OA FL @ NEAR SURFACE. BLED lAP FROM 160 PSI TO 80 PSI IN 1 HR, ALL FLUID. lAP INCREASED FROM 80 PSI TO 140 PSI IN 1 HR 45 MINS. FINAL WHP'S SI/140/1 O. ) ) BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/19/2004 06:00 - 14:00 8.00 MOB N WAIT PRE Wait on Weather to lower Derrick. Ambient temperature = -47 F. Clean and maintain Rig. 14:00 - 16:00 2.00 MOB P PRE Ambient temperature = -35.8 degs F. Hold PJSM with special discussion on cold weather operations. Scope and lower Derrick. Prep to move off Location. 16:00 - 00:00 8.00 MOB P PRE Move Sub Base, Pits, Pipe Shed, and Camp from A-Pad to DS1-19a. 2/20/2004 00:00 - 02:00 2.00 P PRE Set Rig Mats and Herculite. Spot Sub, Pits, and Pipe Shed. Spot Tiger Tank and lay lines. Ready to raise and scope Derrick...however Ambient Temperature = -45 deg F. Accept Rig at 02:00 hrs. Wait on Weather. 02:00 - 06:00 4.00 RIGU N WAIT PRE Maintain Rig. Take on 1 load of 120 deg F. Sea Water. 06:00 - 08:30 2.50 RIGU P PRE Ambient Temperature = -36 deg F. PJSM. Raise and scope Derrick. 08:30 - 09:30 1.00 KILL P DECOMP Pick up Lubricator and pull BPV. Lay down same. TP = 150 psi. CP = 130 psi. 09:30 - 10:00 0.50 KILL P DECOMP PJSM with all. 10:00 - 10:30 0.50 KILL P DECOMP Test lines to 3,500 psi. Rubber Boot in Flow Line leaking. Change out. Re-test lines to 3,500 psi. Good test. 10:30 - 14:00 3.50 KILL P DECOMP Circulate well with 140 deg F Sea Water at 6 bpm/310 psi. 640 bbls pumped. Monitor well. 14:00 - 18:00 4.00 KILL P DECOMP Monitor well, tubing flowing. Reverse circulate 100 Bbls. Monitor well, annulus flowing. Pump 100 Bbls down tubing. Monitor well; tubing flowing. Reverse circ 100 Bbls; tubing flowing. Returns over shaker were of the "Silly Putty" nature. 18:00 - 21 :00 3.00 KILL P DECOMP Continue circulating and monitoring flows every 100 Bbls. Returns became clear, hot seawater. 21 :00 - 22:30 1.50 KILL P DECOMP SI well 30 minutes, monitor pressure. TP = 0 psi, CP = 0 psi. Open both sides and annulus flowed at 4 BPH, clear, clean seawater, but no gas, oil, or formation fines (Silly Putty). Annulus flow rate bled off to almost no flow. No flow from tubing. 22:30 - 23:00 0.50 KILL P DECOMP P/U FMC BPV (bottom half of TWC) and set in hanger. 23:00 - 00:00 1.00 KILL P DECOMP N/D tree. 2/21/2004 00:00 - 01 :30 1.50 WHSUR P DECOMP Install TWC and Blanking Plug. Test. Nipple down Production Tree. 01 :30 - 03:00 1.50 BOPSUP P DECOMP N/U BOPE. Rig up test equipment. 03:00 - 08:30 5.50 BOPSURP DECOMP Test BOPE to BP/AOGCC requirements at 250/3500 PSI. Did not get a good test on the Pipe Rams. Changed out 31/2" x 6" VB Rams and installed 51/2" Pipe Rams. Completed test. State's right to witness test waived by J. Chrisp. 08:30 - 09:00 0.50 BOPSUR P DECOMP Rig down test equipment. Blow down lines. 09:00 - 10:30 1.50 WHSUR P DECOMP Pick up Landing Jt. Pull Blanking Plug. Lay down same. Pick up DSM Lubricator and Pulling Tool. Pull TWC. Lay down same. 10:30 - 11 :30 1.00 PULL P DECOMP Pick up Landing Jt and XO. Screw into Tbg Hanger (5 3/4" RH Acme. 9 3/4u Turns). BOLDS. 11 :30 - 14:00 2.50 PULL P DECOMP Pull Hanger free at 155K. Work 5 1/2" Tbg String up to 200K. Tubing free at Chemical Cut at -9, 157'...however dragging through till laying in bottom of Well. Continue to work Tbg at 200K, 225K, 250K, and 275K. (Max pull 290K). Loosing hole I as fill falls in behind. Hanger to Floor. 14:00 -15:00 1.00 PULL P DECOMP Lay down Tubing Hanger. Continue to work Joint #1 out of Printed: 3/8/2004 8:41 :44 AM ) ) BP EXPLORATION Operations Summary Report Page 2 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/21/2004 14:00 - 15:00 1.00 PULL P DECOMP hole. Still having to pull up to 275K. Control line coming out of hole as well. LD Jt #1. 15:00 - 17:00 2.00 PULL P DECOMP Rig up to circulate down tubing while working Tubing. Start pulling Jt #2 out of hole. Circulating does not apear to help as circulation continues through holes in Tubing at -2,400'. 17:00 - 21 :00 4.00 PULL N DPRB DECOMP Discuss options with Anchorage and decide to chemical cut tubing above 2nd GLM, - 4750'. Wait on SWS. 21 :00 - 00:00 3.00 PULL N DPRB DECOMP R/U SWS. Hold PJSM for String Shot and Chemical cutter. R/U SWS packoff and pump-in sub. RIH wi string shot; calibrate off #2 GLM @ 4850'; fire shot from 4760' to 4773' @ 2347 hrs. 2/22/2004 00:00 - 01 :15 1.25 PULL N DPRB DECOMP POOH wi SWS string shot. RID string shot assy, R/U Chem cutter assy. 01 :15 - 02:15 1.00 PULL N DPRB DECOMP RIH wi SWS chemical cutter. Tied in with GLM #2. Fired cutter @ 02:15 hrs, wi good results. Depth of cut is 4770' elm...middle of second full Jt above GLM #2. 02:15 - 03:15 1.00 PULL N DPRB DECOMP POOH wi chem cutter, clear drill floor of all personnel for SWS to break out assy. 03: 15 - 04:00 0.75 PULL N DPRB DECOMP PIU tubing. Pulled free with 76K. Continue to POOH to the next collar where loose, encapsulated control lines were wrapped. Rig up Spooling Unit. 04:00 - 06:30 2.50 PULL N DPRB DECOMP POOH and UD 5-1/2", 17# L-80 Tbg to SSSV. 06:30 - 07:00 0.50 PULL N DPRB DECOMP Lay down SSSV. Recovered Control Line, 26 Clamps, and 4 Bands. Rig down Spooling Unit. 07:00 - 09:30 2.50 PULL N DPRB DECOMP Continue POOH with 51/2" Tbg to Chemical Cut Stub. Recovered 117 full Jts, 19.84' Chemical Cut Stub (Good clean cut...normal O.D.), SSSV, and 1 GLM. Note: Jt # 57 had 4 ft of Perforation holes. Jts #58, 59, and 60 were found to be perforated their entire lengh and Jt #61 had 14' of Perforation hole. It appears Perforating Gun had been loaded at 4 spf x 120 deg Phasing. Exit holes -1/4". Also a large hole in Jt #58, (3" x 2" ,2ft below the collar, was found caused from outside inward jetting. The jetting also caused a 2" x 2" exit hole on the opposite side of the tube) was found at -2,459-ft. 10:00 - 10:30 0.50 PULL N DPRB DECOMP Rig down 5 1/2" handling equipment. 10:30 - 11 :30 1.00 FISH N DPRB DECOMP Install Wear Bushing. Rig up to handle 31/2" Drill Pipe and BHA #1. 11 :30 - 12:30 1.00 FISH N DPRB DECOMP Make up BHA #1 as follows: 8 1/8" OS with 5 1/2" Grapple, Extention, Bumper Sub, Oil Jar, XO, Drill Collars, and XO. 12:30 - 16:30 4.00 FISH N DPRB DECOMP RIH with BHA #1 and single in with 31/2" Drill Pipe (141 total Jts) from Pipe Shed. 16:30 - 17:00 0.50 FISH N DPRB DECOMP Pick up Kelly. Tag TOF at 4,790-ft 4es KB. 17:00 - 20:30 3.50 FISH N DPRB DECOMP Latch Fish. Attempt to break circulation..,no joy. Work Pipe up to 275 K. Continue dragging remaining 51/2" Completion Tbg up hole through Fill. UD two jts 3-1/2" DP. 20:30 - 21 :00 0.50 FISH N DPRB DECOMP Attempt to break circulation and work pipe. Circulation established @ 2050 hrs @ 5 BPM, 1200 psi; after 2000 stks, dropped to 1000 psi. Pulled on pipe, came free @ 176K, from 8951'. 21 :00 - 00:00 3.00 FISH N DPRB DECOMP Gas at surface at 2105 hrs, continue circulating at 5 BPM, 1000 psi. Foamy retums over shaker: gas, gray silts, diesel, I and crude oil. Hanging wt 160K. Circulate total of 14,500 3.00 I FISH strokes. 2/23/2004 00:00 - 03:00 IN DPRB DECOMP Monitor well. Foam cleared up. Mix weighted pill and pump I I I Printed: 3/8/2004 8:41:44 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task Code NPT Phase 2/23/2004 00:00 - 03:00 3.00 FISH N DPRB DECOMP 03:00 - 03:30 0.50 FISH P DECOMP 03:30 - 07:30 4.00 PULL P DECOMP 07:30 - 08:00 0.50 PULL P DECOMP 08:00 - 09:00 1.00 BOPSUB P DECOMP 09:00 - 10:00 1.00 BOPSUB P DECOMP 10:00 - 11 :00 1.00 BOPSUB P DECOMP 11 :00 - 12:00 1.00 CLEAN P DECOMP 12:00 - 13:00 1.00 CLEAN N DPRB DECOMP 13:00 - 14:30 1.50 CLEAN N DPRB DECOMP 14:30 - 15:30 1.00 CLEAN P DECOMP 15:30 - 20:00 4.50 CLEAN P DECOMP 20:00 - 21 :30 1.50 CLEAN N DPRB DECOMP 21 :30 - 00:00 2.50 CLEAN N DPRB DECOMP 2/24/2004 00:00 - 02:00 2.00 CLEAN N DPRB DECOMP 02:00 - 04:30 2.50 CLEAN N DPRB DECOMP 04:30 - 08:30 4.00 CLEAN N DPRB DECOMP 08:30 - 10:00 1.50 CLEAN N DPRB DECOMP 10:00 - 11 :30 1.50 CLEAN P DECOMP 11 :30 - 13:30 2.00 CLEAN P DECOMP 13:30 - 14:00 0.50 CLEAN P DECOMP 14:00 - 16:00 2.00 CLEAN P DECOMP 16:00 - 18:00 2.00 CLEAN P DECOMP 18:00 - 21 :30 3.50 CLEAN P DECOMP Page 3 of 10 Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Description of Operations down tubing to balance fluids. POOH LID single DP, SIB 46 stds 3-1/2" DP, 3 stds DCs. B/O & LID BHA #1and fished cut-off jt. The string pull wt started at a free-up wt of 176K Ibs. As soon as start of POOH, wt dropped to 160 K and gradually decreased from there wi no need to work pipe through tight spots. Change out 3.5" pipe handling equpmt; R/U 5-1/2" tubing handling equpmt. POOH and lay down remaining 5 1/2" Completion. Total recovered Completion = 219 jt, SSSV, 9 GLMs wi Pup Jts, Cut off Stub = 20.00'. Chemical Cut Stub recovered showed clean cut. Normal OD. Tubing Punches were also good. Rig down 51/2" handling equipment. Clear Floor. Pump out BOP Stack. Pull Wear Bushing. Set Test Plug. Change out 5 1/2" Pipe Rams. Install 2 7/8" x 5" VB Pipe Rams. Test Pipe Rams at 250/3500 psi. Good. Rig down test equipment. Pull Test Plug. Install Wear Bushing. Rig up to handle 31/2" Drill Pipe. Pick-up BHA #2 as Follows: 8 1/2" Five Blade Junk Mill, Bit Sub, Bumper Sub, Oil Jar, 9 ea 6 1/4" Drill Collars, and XO. RIH with BHA #2 and 31/2" Drill Pipe from Derrick. Stop at 4,690'. Cut and Slip Drilling Line. (84') Continue RIH picking up single 3 1/2" Drill Pipe from Pipe Shed. Change out shaker screens from 84 mesh to 110 mesh. R/U to make full circulation,Vis seawater. Add two jts 3-1/2" DP and lower to +1- 9155', pull back to 9150', 4ES RKB, and circulate. Full circulation wi Vis seawater: DPV = 61 Bbls, A V = 561 Bbls. Full circulation of Hi-Vis system, but returns still containing fine, gray, silty sand. Hook-up Kelly to rotate and reciprocate while circulating at 6 BPM, 900 psi, 80 RPM. The amount of returns began gradually decreasing - 0130 hrs to as little as two fist sized mounds on the shaker by 0200 hrs. String rotation helped greatly to move solids uphole. Fluid swap (622 Bbls) to clean, 100 F seawater. Stopped rotating @ 0300 hrs. Returns continued to decrease to a trace of silty, sand in discontinuous patches along screen edges. Set back Kelly. POOH with 31/2. Drill Pipe (278 jts) and Drill Collars. Lay down BHA #2. Clear Floor. Pick up BHA #3 as Follows: 8 1/2" x 51/2" Dress shoe, 3 ea Extentions, Bushing, XO, Boot Baskets, XO, Drill Collars, XO. RIH wi BHA # 3 on 31/2" DP to 2700'. DP started flowing back. Circulate & pump weighted pill down DP. Con't to RIH wi BHA # 3 on 31/2" DP to 9161'. P/U kelly break circulation & wash down thru fill from 9161 to 9179'. Top of tbg stub @ 9164', Set back kelly & P/U single jt of DP. R/U & begin reverse circulating. Reversed @ 4 1/2BPM, 250 Psi. Lost 14 bbls in 5 Printed: 3/8/2004 8:41 :44 AM .) ) BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/24/2004 18:00 - 21 :30 3.50 CLEAN P DECOMP min. Losses to great to continue. Blow own lines, Ud single & kelly up. Break circulation & circulate the long way. Rotate & reciprocate DP just above tbg stub @ 9164'. Mix & pump 40 Bbl Hi-vis sweep. Well cleaned up while circulating. Sweep came back clean. 21 :30 - 22:00 0.50 CLEAN P DECOMP Slowly circ & RIH to 9179'. Had to rotate slightly to get over tbg stub. Saw pump pressure increase of 50 psi when bottomed out. Pick back up & shut down pump. Run back to 9179' wlo circulating. No fill noted. P/U 152K, SIO 120K, Rot 135K. 22:00 - 22:30 0.50 CLEAN P DECOMP Monitor well. Set back kelly, blow down lines & LID 4 singles of DP. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH & stand back 31/2" DP. 2/25/2004 00:00 - 02:00 2.00 CLEAN P DECOMP Con't to POOH & stand back 3 1/2" DP and Drill Collars. 02:00 - 03:00 1.00 CLEAN P DECOMP Break out & UD BHA # 3. Clean out boot baskets. Baskets contained mud, steel shavings & cement-like material. clear & clean rig floor. 03:00 - 05:00 2.00 EVAL P DECOMP M/U 95/8" RTTS & RIH wi 3 stands of DCs. Con't to RIH wi RTTs on 31/2" DP to 2375'. 05:00 - 06:00 1.00 EVAL P DECOMP Set RTTS. Test 9 5/8" Casing to 3,500 psi/30+ min and record on chart. Good test. Blow down lines. Release Pkr. 06:00 - 07:00 1.00 EVAL P DECOMP POOH with 31/2" Drill Pipe. 07:00 - 08:00 1.00 EVAL P DECOMP Lay down 6 1/4" Drill Collars. Lay down RTTS Pkr. 08:00 - 09:30 1.50 CASE P TIEB1 Clear Floor. Rig up to run 7" Liner. Inspect Tail Pipe and Shoe Track. 09:30 - 10:00 0.50 CASE P TIEB1 Hold PJSM with all. 10:00 - 11 :30 1.50 CASE P TIEB1 Pick-up 9 5/8" x 5 1/2" Unique Overshot (w/3 Brass screws...11 k shear), 5 1/2" x 4 1/2" XO, 4 1/2" Pup Jt, 4 1/2" Pup Jt, 41/2" x 3.813" X-Nipple w/PXX Plug installed, 4 1/2" Pup Jt, 4 1/2" x 5 1/2" XO, 5 1/2" Pup Jt, 5 1/2" x 7" Ported (4 ea x 1/2" holes). Dump 3 sks of Sluggetts on top of PXX Plug followed by 6 sks of Sand. Sand top 6" below the Ported XO. Baker-Loc'd Tail Pipe connections. Pick-up Shoe Track as Follows: "A" Jt 7" 261b/ft L-80 BTC-M Csg, 7" Float Collar, "B" Jt 7" 261b/ft L-80 BTC-M Csg, Baker Landing Collar. 11 :30 - 21 :00 9.50 CASE P TIEB1 RIH with 7" 26 Ibltt L-80 BTC-M Csg. Install RH Turbolators (free-floating) on ever other Jt up to 2,600'. Installed same on every Jt from 2,600' to top of Liner. M/U liner hanger, ZXP packer & running assy. RIH to 7340'. 21 :00 - 22:00 1.00 CASE P TIEB1 RID 7" liner handling tools. R/U 3 1/2" DP handling tools. Clear & clean rig floor. Break circulation thru liner. 22:00 - 23:00 1.00 CASE P TIEB1 RIH wi liner on 31/2" DP to 9151'. 23:00 - 00:00 1.00 CASE P TIEB1 Tagged Fill @ 9151'. Work string up & down. Made 10' to 9161'. 2/26/2004 00:00 - 01 :00 1.00 CASE P TIEB1 Con't to work liner by reciprocating. Could not get deeper than 9161'. Stacked up 20k weight. Saw no indication of pin shear in overshot. Appears to have fill on top of tbg stub @ 6164'. 01 :00 - 02:00 1.00 CASE N DPRB TIEB1 POOH wi liner on 3 1/2" DP. 02:00 - 02:30 0.50 CASE N DPRB TIEB1 Break out & UD liner hanger assy. Noted sand on hanger & ZXP assy. 02:30 - 06:00 3.50 CASE N DPRB TIEB1 I POOH & UD 7" liner. 70 jts laid down @ 0600 hrs. 06:00 - 10:30 4.50 CASE N DPRB TIEB1 Finish laying down 174 Jts 7" Liner. 10:30 - 12:30 2.00 CASE N DPRB ¡TIEB1 I Heat Baker-Loc'd connection on "B" Jt and lay down. Heat I I Baker-Loc'd connection between X-Nipple lower Pup Jt and I I Printed: 3/8/2004 8:41 :44 AM '> ) BP EXPLORATION Operations Summary Report Page 5 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2004 10:30 - 12:30 2.00 CASE N DPRB TIEB1 Pup Jt on Unique Overshot and lay down. Send TP in for inspection, re-torque, and re-Baker-Loc Threads. 12:30 - 13:30 1.00 CASE N DPRB TIEB1 Rig down Liner/Tailpipe handling equipment. Clear and clean Floor. 13:30 - 14:30 1.00 CASE N DPRB TIEB1 Pick-up Halco 9 5/8" RBP and Running Tool. 14:30 - 15:30 1.00 CASE N DPRB TIEB1 RIH with RBP and 31/2" Drill Pipe. 15:30 - 16:00 0.50 CASE N DPRB TIEB1 Set RBP at 2,625' RKB (2,643' 4 es tally at Floor). 16:00 - 17:00 1.00 CASE N DPRB TIEB1 POOH with 31/2" Drill Pipe and Running Tool. 17:00 - 19:00 2.00 CASE N DPRB TIEB1 Install 7" shooting nipple thru stack. Dump 27 sx of sand down well on top of RBP. Wait for sand to fall to 2643'. 19:00 - 20:30 1.50 CASE N DPRB TIEB1 RIH wi mule shoe on 31/2" DP to tag sand. Tagged up on RBP @ 2643'... no sand. 20:30 - 21 :30 1.00 CASE N DPRB TIEB1 POOH wi DP & LID mule shoe. 21 :30 - 23:00 1.50 CASE N DPRB TIEB1 M/U retreiving tool on 3 1/2" DP & RIH. Tagged up on sand @ 2633'. P/U & wait 15 min, RIH & tag @ 2633'. P/U & wait 10 min, RIH & tag @ 2616'. Sand has apparently hit bottom. 23:00 - 00:00 1.00 CASE N DPRB TIEB1 POOH wi retreiving tool & 31/2" DP. 2/27/2004 00:00 - 01 :00 1.00 CASE N DPRB TIEB1 Finish POOH & UD retreiving tool. M/U mule shoe on 31/2" DP & RIH. Tag up on sand @ 2616'. P/U to 2598'. 01 :00 - 01 :30 0.50 CASE N DPRB TIEB1 Hold PJSM wi all hands prior to cementing. Perform injectivity test as follows: 2 BPM @ 125 psi; 3 BPM @ 250 psi; 4 BPM @ 400 psi. Pressure test cementing lines to 2500 psi. 01 :30 - 04:30 3.00 REMCM-N DPRB TIEB1 Set balanced plug accross perfs & squeeze as follows: Pump 10 Bbls of fresh water spacer. Mix & pump 29.5 Bbls of Artic Set I cement @ 15.7 ppg. Displace wI 11 Bbls of seawater. Fill hole & close annular. Perform hesitation squeeze by pumping 2 Bbls of cmt @ 112 BPM every 10 min. Max squeeze pressure obtained was 200 psi. CIP @ 0230 hrs. Final squeeze was @ 0400 hrs. wi 115 psi. Squeezed total of 15 Bbls of cement into perfs. Est top of cement @ 2400'. 04:30 - 05:00 0.50 REMCM-N DPRB TIEB1 Blow down cementing lines. Circulate thru DP & mud manifold to clear any residual cement from lines. 05:00 - 06:30 1.50 REMCM-N DPRB TIEB1 UD 1 single of DP & POOH. 06:30 - 07:00 0.50 BOPSUP P TIEB1 Pull Wear Ring. 07:00 - 09:30 2.50 BOPSUP P TIEB1 Set Test Plug. Rig up testing equipment. Have FMC replace one Packing Gland Nut on Tbg Spool before test. 09:30 - 12:30 3.00 BOPSURP TIEB1 Test BOPE per BP/AOGCC requirements at 250/3500 psi. Good Test. State granted permission to perform Weekly BOP Test one day early so we could test while WOC. State's right to witness test waived by J. Jones. 12:30 - 14:30 2.00 REMCM-N DPRB TIEB1 Rig line to test Cement Squeeze (9 hrs WOC). Hole remains full. Pumped -1 bbl...Squeeze did not hoJd...broke at 150 psi. Injection 1 bpm/100 psi x 5 min. Blow down Pump and Lines. Discuss Plan Forward with Anch Eng. 14:30 - 15:30 1.00 REMCM-rN DPRB TIEB1 P/U & M/U BHA #4 to drill out cement as follows: 81/2" Bit, Bit Sub, Jars, X-over, 3 ea 6 1/4" DCs, X-over. 15:30 - 16:30 1.00 REMCM-N DPRB TIEB1 RIH wI BHA # 4 on 3 1/2" DP. Tag up on cement @ 2403'. 16:30 - 21 :30 5.00 REMCM-N DPRB TlEB1 Drill out sqeeze cement plug from 2403' to 2570'. 80 RPMs, PP 350 psi, 5 BPM, WOB 10K. P/U 51 K, SIO 51 K, Rot 51 K. 21 :30 - 22:30 I 1.00 REMCM-N DPRB TIEB1 Circulare hole clean. 6112 BPM @ 600 psi. Monitor well. 22:30 - 23:30 1.00 REMCM-N DPRB TIEB1 POOH wi BHA # 4. I 0,50 I REMCM-N \23:30 - 00:00 i DPRB TIEB1 Break out & UD BHA #4, 2/28/2004 00:00 - 01 :30 1.50 REMCM-N DPRB TIEB1 Con't to RIH wi muleshoe on 31/2" DP Tag up @ 2570'. I I Printed: 3/812004 8:41 :44 AM ) ') BP EXPLORATION Operations Summary Report Page 6 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/28/2004 01 :30 - 02:00 0.50 REMCM-N DPRB TIEB1 Perform injectivity test thru holes in pipe as follows: 1 BPM @ 100 psi, 2BPM @ 170 psi, 3BPM @ 260 psi, 4 BPM @ 420 Bbls. 02:00 - 02:30 0.50 REMCM-N DPRB TIEB1 Hold PJSM. R/U Schlumberger & pressure test lines to 2500 psi. 02:30 - 05:00 2.50 REMCM-N DPRB TIEB1 Re-squeeze holes in 9 5/8" casing as follows; Mix & pump 5 Bbls of artic Set I neat cement, 45 Bbls Of Artic Set I wI cellophane & up to 15 #/bbl aggregate. Displaced well wI 1 bbl of fresh water & 8 bbls of seawater. Pulled 8 stands & squeezed well. Pumped 8.4 Bbls @ 1 BPM pressure increased to 200 psi, wait 10 min. Pumped 8 bbls @ 1 BPM & pressure increased to 300 psi. Wait 10 min. Pumped 5 Bbls @ 1 BPM & pressure increased to 600 psi. Wait 5 min & pumped less than 1 Bbl & pressure incresed to 650 psi. Sd. CIP & 0430 Hrs. Bled off pressure. & R/U cementing equip. 05:00 - 06:00 1.00 REMCM-N DPRB TIEB1 Circulate bottoms up @ 5 BPM, 400 psi. Monitor well. Prep to POOH. Start wac at 05:00 hrs. 06:00 - 07:00 1.00 REMCM-N DPRB TIEB1 POOH with 31/2" Drill Pipe. Lay down Mule Shoe. 07:00 - 08:30 1.50 REMCM-N DPRB TIEB1 Service Rig. Clear and Clean Floor. 08:30 - 09:30 1.00 REMCM-N DPRB TIEB1 Pick-up BHA #5 as Follows: 8 1/2" Bit, Bit Box, Oil Jar, XO, 9 ea Drill Collars, XO 09:30 - 10:00 0.50 REMCM-N DPRB TIEB1 RIH to 1,500'. Park Bit. Continue to wac 10:00 - 13:00 3.00 REMCM-N DPRB TIEB1 Continue wac. Maintain Rig...Cleaning and misc repairs. 13:00 - 13:30 0.50 REMCM-N DPRB TIEB1 Pressure test Squeeze. Hole remains full. Test and record on chart at 650 psi/5 min. Increase pressure to 1,100 psi/10 min. Good Test. 13:30 - 14:00 0.50 REMCM-N DPRB TIEB1 RIH and tag TOC at 2,303' 14:00 - 15:00 1 .00 REMCM-N DPRB TIEB1 Pick-up Kelly. Drilled "fast" Cement from 2,303' - 2,339'. Returns are soft. Stop Drilling. Clean up hole. Discussed with Anch Eng and decided to continue to wac 2 more hours. 15:00 - 17:00 2.00 REMCM-N DPRB TIEB1 wac. Drill down to 2,351' at 1ft/min. Cement now taking weight 10K - 15K. Retruns are "crumbly" but still smi-soft. Still have 44' of cement above top of damaged Casing area. Stop drilling until 18:30 hrs. 17:00 - 18:30 1.50 REMCM-N DPRB TIEB1 Wait on Cement. 18:30 - 19:00 0.50 REMCM-N DPRB TIEB1 Test cement wI drill. Drill from 2346 to 2346' ; 10' of cement in 18 min. 10-15K WOB, 80 RPMs, 4 BPM @ 300 psi. Circ bottoms up & check sames. Cement appears to be hard wI lots of aggregate in sample. 19:00 - 00:00 5.00 REMCM-N DPRB TIEB1 Con't to drill out squeeze plug from 2346 to 2570'. 10-15K WOB, 80 RPMs, 4 BPM @ 300 psi. Torq 4K. Had several short intervals of softer cement, then hardened up, All above perfs. Samples over shaker looked good. 2/29/2004 00:00 - 01 :00 1.00 REMCM-N DPRB TIEB1 Circulate bottoms up unti cement returns cleaned up. 5 BPM @ 600 psi. 01 :00 - 02:00 1.00 REMCM-N DPRB TIEB1 Pull up above perfs & R/U to pressure test squeeze job. Pressure up to 250 psi & held OK" increase pressure to 500 psi & slowly leaked to 470 & flattened out, Increase to 750 psi & pressure bled off quickly to 200 psi. Re-pressure to 750 psi & bled right off. Pressured up to 1000 psi & it took 1 12 BPM to maintain, then started to break down where 1/2 BPM held 900 102:00 - 03:30 psi & continued down. 1.50 REMCM-N DPRB TIEB1 Run back to bottom. P/U kelly & con't to drill & clean out I Printed: 3/8/2004 8:41 :44 AM ) ) BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/29/2004 02:00 - 03:30 1.50 REMCM-N DPRB TIEB1 cement from 2570 to 2604'. Hit sand & wash down thru sand from 2604 to 2640'. WOB 10-15K, 80 RPMs, Torq 4K, PP 4 BPM @ 350 psi. 03:30 - 04:30 1.00 REMCM-N DPRB TIEB1 Circulate bottoms up. 6 1/2 BPM @ 600 psi. Monitor well. 04:30 - 06:30 2.00 REMCM-N DPRB TIEB1 POOH wi bit & BHA. 06:30 - 08:00 1.50 REMCM-N DPRB TIEB1 Pick-up Halco Running/Pulling Tool. RIH to top of Sand at 2,640'. Pull up hole. 08:00 - 08:30 0.50 REMCM-N DPRB TIEB1 Perform Reverse Circulation Test at 3 bpm/250 psi, 4 bpm/350 psi, and at 5 bpm/525 psi. No Fluid loss or gain during test. 08:30 - 09:30 1.00 REMCM-N DPRB TIEB1 Reverse out Sand on top of Halco RBP. Latch RBP and release. Blow down lines. 09:30 - 11 :00 1.50 REMCM-N DPRB TIEB1 POOH with 31/2" Drill Pipe and RBP. Lay down RBP and RIP Tool. 11 :00 - 12:30 1.50 REMCM-N DPRB TIEB1 Clear and Clean Floor. 12:30 - 14:00 1.50 CASE N DPRB TIEB1 Pick-up BHA #6 as Follows: 8 1/2" x 5 1/2",3 ea Extentions, XO, Top Sub, XO, 9 5/8" Csg Scraper, Boot Baskets, XO, Bumper Sub, Oil Jar, XO, Drill Collars, XO. 14:00 - 17:30 3.50 CASE N DPRB TIEB1 RIH with BHA #6 and 31/2" Drill Pipe. Tagged up on fill @ 9108". 17:30 - 18:00 0.50 CASE N DPRB TIEB1 P/U kelly & break circulation. Wash down from 9108 to 9139'. Make connection. 18:00 - 19:30 1.50 CASE N DPRB TIEB1 Rotate wash down from 9139 to 9165'. Tag stub @ 9165' & con't to wash down to 9179'.over tbg stub. Had to rotate to get over stub 1 st time, then slid over wlo rotation. Pumped 4 BPM @ 900 psi. 60 RPMs. P/U 157K, SIO 118K, Rot 137K. 19:30 - 23:00 3.50 CASE N DPRB TIEB1 Close annular & begin reverse circulating. Pumped 20 Bbls Hi-Vis sweep. Pumping @ 3 BPM 400psi. Losses approx 79 Bbls in 3 hrs. Well cleaned up, however appears to recirculating fines. 23:00 - 00:00 1.00 CASE N DPRB TIEB1 Take on clean 8.5 ppg 80 deg. seawater & mix 20 Bbl sweep. Begin pumping & displacing old cement water out of wellbore. Checked displaced fluid weight @ 8.7 ppg. 3/1/2004 00:00 - 04:00 4.00 CASE N DPRB TIEB1 Con't to displace well wi clean seawater. Pumping @ 3BPM, 400 psi. Losses incresed wi clear clean fluid. Hole cleaned up. While pumping sweep had intermittant increse in losses & had to increse rate to keep returns. Lost a total 228 Bbls during the entire night of circulating. (26.8 BPH loss) Last 10 min increased circ @ 4 BPM, lost 7 Bbls. SID & monitor well. Hole full. Fluid level dropping very very slowly. 04:00 - 08:00 4.00 CASE N DPRB TIEB1 POOH wi BHA #6. clean pits, 08:00 - 09:00 1.00 CASE N DPRB TIEB1 Cut & slip 84' of drilling line. 09:00 - 11 :00 2.00 CASE N DPRB TIEB1 Con't to POOH wi BHA #6. UD BHA #6 11 :00 - 12:00 1.00 CASE N DPRB TIEB1 Clean out boot baskets. Clear rig floor. UD tools. 12:00 - 13:00 1.00 CASE N DPRB TIEB1 Clean rig floor. Service rig & equip. 18:00 - 20:00 2.00 CASE N DPRB TIEB1 R/U 7 " casing tools. Wait on 7" liner assys. clean rig. 20:00 - 20:30 0.50 CASE N DPRB TIEB1 Unload, tally and inspect 7" liner assy. Drop 1 1/2" ball through Liner Hanger Assembly to check drift. Install 5 1/2" Insert Ball Seat in 5 1/2" Pup Jt. 20:30 - 21 :00 0.50 CASE N DPRB TIEB1 Hold PJSM & Review 7" Liner running procedure. 121 :00 - 22:00 1.00 CASE N DPRB TIEB1 M/U Liner Tail Pipe as Follows: 95/8" x 51/2" 9CR Unique I Overshot, 5 1/2" 171b/ft L-80 Pup Jt, Halco Float Collar, 5 1/2" ! 17 bllft Pup Jt, Baker Insert Ball Seat, 5 1/2" x 7" XO, 1 Jt 7" 26 Printed: 3/8/2004 8:41 :44 AM ) ') BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 Date From - To Hours Task Code NPT Phase Description of Operations 3/1/2004 21 :00 - 22:00 1.00 CASE N DPRB TIEB1 Ibltt L-80 Csg, 7" Halco ES Cementer pined (3 ea) for 1,650 psi shear, 2 Jts 7" L-80 Csg, 7" Baker Landing Collar. All connections Baker-Loc'd. Check floats. 22:00 - 00:00 2.00 CASE N DPRB TIEB1 P/U & RIH wi 7" liner. Fill every 10 jts. Had 21jts in hole @ midnight. 3/2/2004 00:00 - 09:30 9.50 CASE N DPRB TIEB1 Con't to RIH wI 7" liner. Fill pipe every 1 0 jts. 09:30 - 10:30 1.00 CASE N DPRB TIEB1 PJSM. P/U Baker Liner Hanger & ZXP Packer & running tool. LID casing running tools & prep floor to run Drill Pipe. 10:30 - 12:00 1.50 CASE N DPRB TIEB1 RIH wi liner & accessories on 3 1/2" DPI 59 jts drill pipe run. 12:00 - 13:30 1.50 CASE N DPRB TIEB1 M/U 10' pupl M/U Schlumberger cementing head. Circulate @ 3 bpm I 200 psi. 13:30 - 16:00 2.50 CASE N DPRB TIEB1 Continue circulating & rig up Schlumberger cementers. Verify over tubing stub. End of Unique overshot @ 9174'. Previous top of tubing stub @ 9165' DPM. See pressure increase pumping @ 3 bpm I 200 psi @ 9158'. Pressure climbed to 350 psi before stacking out wi top of overshot @ 9165'. Pick up & rotate (2) turns & work torque down. Pumping @ 4.5 bpm I 500 psi, see pressure increase @ 9158' & continue slacking off watching pressure climb to 650 psi. Stack 20K on stub, 4.5 bpm I 650 psi, 100% return rate. Conclude we have swallowed stub. Pick up & slack off to 9163', (2' up from being bottomed out on stub). Bottom of overshot @ 9172'. 16:00 - 17:00 1.00 CASE N DPRB TIEB1 PJSM. Drom 1 1/2" ball & circulate down. Observe ball on seat wI 195 bbls away. Pressure up slowly to 1700 psi & observe Halliburton sleeve open. Circulate to verify. 17:00 - 18:00 1.00 CASE N DPRB TIEB1 Crew change. Conduct Pre job Safety Meeting. Presure test lines to 5000 psi, OK. 18:00 - 20:00 2.00 CEMT N DPRB TIEB1 Cement 7" liner as follows: Pump 45 Bbls of fresh water spacer. Mix & pump 197 bbls of Class 'G' cement wi .2% D-46, .3% D-65,.4% D-167, .6% B-155. Wt= 15.8 ppg, Yld 1.16 cuft/sx, 5.096 gal/sx mix water. SID & drop plug. Displace wI 10 Bbls of fresh water followed by 270 bbls of seawater. Bump plug wI 3000 psi. Slack off 86K. Con't to pressure up to 3100 ps & set packer. Con't to pressure up to wi 4000 psi. Release pressure & check float, held Ok. PD @ 2000 hrs. WOC. 20:00 - 21 :00 1.00 CEMT N DPRB TIEB1 Slack off & Rotate 12 turns. P/U Pull out of hanger 7' wI setting tool. Reverse circulate 3 DP volumes. 3 BPM @ 100 psi. Had cement to surface ( approx 1.2 Bbls of watered down cement) Bump down 2 times wI 25K. Verify set. Monitor well. Hole full. Prep to POOH. 21 :00 - 23:00 2.00 CEMT N DPRB TIEB1 POOH & UD hanger setting tool. 23:00 - 00:00 1.00 CEMT N DPRB TIEB1 P/U & M/U BHA #7 as follows: 6 1/8" Bit, Bit sub, Jars, 10" 4 3/4" DCS. TL = 323.28'. 3/3/2004 00:00 - 00:30 0.50 CEMT N DPRB TIEB1 Finish M/U BHA #7 & RIH wI same. TL = 323.28'. 00:30 - 01 :30 1 .00 CEMT N DPRB TIEB1 RIH wI BHA #7 on 31/2" DP to 1752'. 01 :30 - 08:00 650 CEMT N TIEB1 WOC. Circulate wI charge pump. Load tally Prep 41/2" tubing for completion. 08:00 - 09:00 1.00 CEMT P TIEB1 PJSM. Pressure test liner & 9 5/8" casing from 1900' to surface I @ 3500 psi I 30 minutes, charted, very good test. Bleed I pressure. 09:00 - 13:00 4.00 I CEMT P TIEB1 RIH w/3 1/2" DP & cleanout BHA. Run 89 stands, (267 jts), i and pick up singles. Tag cement on # 270 @ 8900'. UD 270. I I Printed: 3/8/2004 8:41 :44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/3/2004 3/4/2004 3/5/2004 Date ') ) BP EXPLORATION Operations Summary Report 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Page 9 of 10 Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 13:00 - 14:30 From - To Hours Task Code NPT Phase Description of Operations 14:30 - 17:00 17:00 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 10:00 10:00 - 13:30 13:30 - 15:00 15:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 22:30 22:30 - 23:30 23:30 - 00:00 1.50 CEMT P TIEB1 2.50 CEMT P TIEB1 5.50 CEMT P TIEB1 1.50 CEMT P TIEB1 0.50 CEMT 2.50 CEMT 1.00 CEMT 1.00 CEMT 1.00 CEMT 4.00 CEMT 3.50 CEMT P P P P P P P TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 1.50 CEMT P TIEB1 7.00 CEMT P 1.00 CEMT P 1.00 WHSUB P TIEB1 TIEB1 TIEB1 0.50 RUNCOrvP 1.50 RUNCOMP 0.50 RUNCOtvP 0.50 RUNCOrvP 13.00 RUNCOrvP COMP COMP COMP COMP COMP 1.00 RUNCOfvP COMP 1.00 RUNCOrvP COMP 4.50 RUNCOrvP I I I 1.001 RUNCO~ 0.50 I RUNCO~ I I I I COMP COMP COMP PJSM. Kelly up & establish parameters. 145K up wt, 11 OK down wt & 125K rotating wt. Bring on pump @ 4 bpm 1750 psi. Rotate @ 60 RPM, 5000 ftllbs of torque off bottom & mill cement @ 75-100' I hr w/5-8K WOB. Tag up & drill hard @ 8953'. Double check pipe count. Landing collar should be @ 8996'. (slid up hole?) Continue milling on landing collar. 60 RPM, 15-20K WOB. Seeing rubber in returns. Plug may be spinning. Continue milling on plug I landing collar I cement. Thru plug I collar OK. Drilling cement. Drill cement to 9077' & hit ES Cementer. Con't to drill & bottomed out on 5 1/2" x 7" X-over @ 9120'. 4 BPM @ 800 psi. 60-90 RPMs, WOB 10-15K. P/U 145K, S/O 110K, Rot 125K. Circulate, rotate & reciprocate pipe. Pump 20 Bbl Hi -Vis pill. 6 BPM @ 1300 psi. Circulate hole until clean. Had cmt, rubber & aluminum millings from sweep. Con't to circulate hole clean. 6 BPM @ 1300 psi. POOH wi BHA # 7. LID BHA # 7. Clear & clean rig floor. Load tally & strap BHA #8. Begin M/U & RIH wi BHA #8 RIH w/4 3/4" cleanout BHA. Tag @ 9119', 13' in on jt # 274. PJSM. Pick up kelly & establish parameters. 155K up wt, 108K down wt, 125K rotating wt. Bring on pump @ 4 bpm 11000 psi & commence milling cement with little resistance, 5K WOB, 60 RPM, 5000 ftllbs of torque. Find ball & landing collar @ 9141' DPM. Drill up same, drill thru Halliburton Float Collar @ 9152' DPM & cleanout to 9180' DPM, (15' inside tubing stub). PJSM. Mix & pump 30 bbls Hi Vis Sweep & circulate around @ 5 bpm 11450 psi. Fine sand I cement back. PJSM. POOH laying down DP. Break out & LID BHA # 8. Pull wear bushing. Clean out junk baskets. Cement & aluminum millings in junk baskets. Clear & clean rig floor. R/U torq turn equip. & tubing equip. Hold PJSM & review running procedure. P/U & M/U tubing tail pipe assy, Baker-Loc & RIH. Run 41/2" completion. Torque turn all connections to 4440 ft-Ibs. 40 jts in hole @ 0600 hrs. PJSM. Make up circ head on #213. Establish parameters. Up wt 11 OK, down wt 83K. Bring on pump @ 2 bpm 1100 psi & lower jt # 213. See pressure increase gradually & good indication of being located out 21.5' in on # 213. PJSM. Space out. Lay down # 213, #212, & #211. Make up 32' of space out pups. Hanger & pups = 8', RKB = 18.32'. Space out will put mule shoed jt 5' from being located out. M/U hanger on jt #211. M/U landing jt. Reverse circulate 290 bbls of heated seawater. Follow wi 290 Bbls of heated inhibited seawater. 3 BPM @ 200 psi. RID torque turn equip. . Land tubing hanger. RILDS. Drop balllrod to set packer. Pressure up on tubing & set packer. Hold pressure for 30 min Printed: 3/8/2004 8:41 :44 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/5/2004 3/6/2004 Date ') ) BP EXPLORATION Operations Summary Report 01-19 01-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Page 10 of 10 Start: 2/18/2004 Rig Release: 3/6/2004 Rig Number: 4ES Spud Date: 8/25/1982 End: 3/6/2004 From - To Hours Task Code NPT Phase Description of Operations 23:30 - 00:00 00:00 - 01 :30 0.50 RUNCOMP 1.50 RUNCOMP COMP COMP 01 :30 - 03:00 1.50 WHSUR P COMP 03:00 - 04:30 1.50 BOPSUPP COMP 04:30 - 06:30 2.00 WHSUR P COMP 06:30 - 08:00 1.50 WHSUR P COMP 08:00 - 11 :30 3.50 WHSUR P COMP 11 :30 - 13:30 2.00 WHSUR P COMP 13:30 - 15:00 1.50 WHSUR P COMP @ 3500 psi & chart same. Bled off tbg pressure to 1500 psi & SI tbg. Pressure up on annulus & test to 3500 psi for 30 min. Chart same. Bled off tbg pressure & shear DCK valve @ 5406'. Valve sheared but did not get good positive shear. R/U & pump down annulus, 2 BPM @ 2200 psi, then pump down tbg, 2 BPM @ 1800 psi. Verifiy shear. Suck out stack. Blow down lines. Set BPV. (FMC type) tested to 1000 psi, Ok. N/D BOPE. Set stack back. N/U adapter flange & X-mas tree. Test void to 5000 psi, OK. PJSM. Pull BPV, set test plug, test tree @ 5000 psi, OK. Pull test plug. PJSM. Rig up Little Red. Test lines to 3000 psi, OK. Pump down II A @ 1 bpm 12750 psi, 140 bbls 70 degree diesel. High pressure due to appearent incomplete shear On DCK valve. PJSM. Rig down Little Red & allow diesel to U-tube. PJSM. Pick up lubricator. Set BPV. Remove secondary annulus valve. Secure well. Release Rig @ 15:00 hrs 03/06/2004. Printed: 3/8/2004 8:41 :44 AM ) ) Well: Field: API: Permit: 01-19A RWO Prudhoe Bay Unit 50-029-20800-01-00 202-022 Accept: Spud: Release: Rig: 02/20104 NIA 03/06/04 Nabors 4ES POST RIG WORK 03/12/04 PULL B&R. PULL STA # 4 @ 5384 SLM, DCK. RIH WI KlO TOOL HIT SSSVN AND BIRD NEST WIRE. SWAB GOT SHUT ON WIRE. FISH WIRE. 03/13/04 FISH WIRE AND TOOL STRING. SET GENERIC GLV IN STA #5 @ 3532' MD (1/4",1500#). SET GENERIC OGLV IN STA #4 @ 5401'MD (5/16"). PULLED RHC PLUG BODY FROM 9102' MD. 03/26/04 MU/RIH WNENTURI. SOLID TAG @ 9182'. KEEP TAGGING SAME SPOT. POOH. VENTURI PACKED W/SILLY PUTTY-LIKE MATERIAL. MU/RIH W/2.75" JSN. TAG @ 9193'. FLO PRO SWEEPS TO HARD TAG @ 9242'. POOH @ 80%. MU/RIH WI 2ND VENTURI.TAG AT 9241', WORK VENTURI. POOH. RECOVER SMALL AMOUNT OF SOLIDS. 03/27/04 RIH WITH JARS I HYD JDC PULLING TOOL. TAG IBP @ 9248'. JAR ACTION, BUT CAN'T LATCH IBP. POOH. 03/28/04 ATTEMPT TO PULL IBP. 03/29/04 ATTEMPT TO PULL IBP, UNABLE TO PULL, (OBSTRUCTION ON FISH-NECK). 03/30/04 MU/RIH WI 2.5" DJN. SET DOWN @ 9190', JET TO 9204'. (ELECTRONIC COUNTER READING SHALLOW, ACTUALLY AT -92421) CANNOT JET DEEPER. PUMP 3 FLOPRO SWEEPS, PU'S CONSISTENTLY STICKY. POOH CHASING @ 80%. REPLACE ELECTRONIC DEPTH COUNTER. MU/RIH WI JARS/SURECATCH FISHING TOOL. UNABLE TO LATCH FISH - JARS NOT WORKING. POH. 03/31/04 RIH BHA #5: MTR & WASHOVER SHOE. WASH 30' FILL TO 9262'. POOH. TATTLETALES SHOW WASHOVER SHOE OVERSHOT IBP FISH NECK ROUGHLY 5'. CUT 102' PIPE. MU/RIH W/BHA #6: BOWEN JARS, SURECATCH FISHING TOOL. SET DOWN @ 9182', CANNOT WORK THROUGH, NO JAR ACTION. POOH. MU/RIH W/BHA #7: DAILY JARS, HYD CNTRLZR, SURECATCH FISHING TOOL.SET DOWN AT 9231' (PKR?). UNABLE TO GO PASS. POOH. 04/01/04 BREAK OFF HYD CENTRALIZER. PUIRIH WI BHA #8: 2-1/8" MTR AND SURECATCH. LATCH AND JAR IBP FREE. POOH. RECOVERED IBP (2 RUBBERS AND MULTIPLE BANDS MISSING). CUT 100' OF PIPE. MU/RIH WI BHA #9: DAILEY JARS, MTR, VENTURI. SET DOWN @ 9232', NO MOTOR WORK. FLAG PIPE @ 9212'. POOH. RECOVERED 1 METAL BAND. MU/RIH WI BHA#10: DAILEY JARS, VENTURI (NO MOTOR).UNABLE TO GO BELOW 9235' CTM. THIS DEPTH CORRELATES WITH GLM AT 9182' (LDL 5/11/03) - 9187' (ORIGINAL TT 9/10/82). POOH FP WELL. 04/02/04 FINISH POOH I FP WELL - RECOVER -1 BAND + 1 RUBBER SMALL AMT OF SOLIDS RDMO. NOTIFY DSO OF WELL SHUT IN. ) FI\IC FI\IC AXELSON 70' TREE = WELLHEAD = ACTUATOR = KB. 8..EV = BF. 8..EV = KOP = 3000' Max Angle = 101 @ 11509' Datum rvD = 10053' Datum lV D = 8800' SS 13-3/8"CSG, 72#, L-80, ID= 12.347" H 2590' Minimu m ID = 2.377" 2-78" LINER COLLARS l-r 9133' I 1-1 9026' 7" CSG, 26#, BTC-M, L-80, ID = 6.276'H 9120' 14-1/2" TBG, 12.6#, 13CrBO, ID = 3.958" 1 4 1/2" "X" NIPA..E ID = 3.813" 1 L 4 1/2" "X" NIFPLE D = 3.813" H 9102' 15-112" 1BG-PC, 17#, L-80, .0232 bpf, ID= 4.892" 1-1 9242' 1 TOP OF 7" LNR, BOT HGR 1--1 9305' ) 01-19A DRAFT.. FROM DRlU..G ~ 1 4-1/2"TBG, 12.6#, L-80, .0152bpf,ID=3.958" I-{ 9340' 1 9-518" CSG, 47#, L-80, ID = 8.681" 1-1 9610' ~ 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" H 9771' FERFORA 1l0N SUMMl\RY REF LOG: ANGLE AT TOP PERF: 92 @ 10870' Note: Refer to Production DB for historical perf data SIZE SPF INTERJ AL OpnlSqz DATE 2" 4 10870-10930 0 11/07/02 2" 4 11330-11470 0 11/07/02 g ~. . ~ ..,. - ~, X X K X ~ X L~ X X X -~. t~~ K ~ I 1885' H BAKffi ZXP PA CKffi W/ C2 PROFILE 1 I 2083' I I 4-1/2" X NIFPLE ID = 3.813" 1 ~ ST MD 5 3532 4 5401 3 6810 2 8011 1 8958 GAS LIFT MANDR8..S TV D DEV 1Y PE V LV LA TCH PORT 1)1.\ TE 3511 18 KBG-2 DMY BK 03/06104 5105 39 KBG-2 OCK-2 B8< 03/06104 6188 40 KBG-2 DMY BK 03/06104 7128 36 KBG-2 DMY BK 03/06104 7919 30 KBG-2 DMY BK 03106104 ". .~. I 903T 1-1 BAKER4 1/2" x 7" S-3 PKR ID = 3.875" I 9162' H UNIQUE OV ffiSHOT I 9231' H 9-5/8" X 5-112" BROWN PKR I J 9242' 1-1 5-1/2" X 4-1/2" XO 1 9311' I~ 3-3/4" BKRDEPLOYIVENTSLV, ID =3.0" 1 9321' I~ 3-1/2" HES XN NIp, ID = 2.750" 1 ~ I MILLOUT WINOOW 9834' - 9839' 9771' 1--1 3-112" X 3-3/16" XO, D =2.880" 1 9830' I~ TOP OF WHIPSTOCK I 1'1 3-3/16" X 2-7/8" XO, ID = 2.440" I I 11551' H PBTD 1 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 10500' ŒJ--1 10505' 13-3116" L!\R, 6.2#, L-80, .0076 bpf, ID = 2.800" H 9897' I 12-7/8" Lf\R,6.16#, L-80, .OO58bpf,ID=2.441" H 11584' 1 FRU[]-iOE SAY UNIT WB..L: 01-19A FERfv11T No: 2020220 API No: 50-029-20800-01 SEC 6, T10N, R15E, 223327' FEL & 2387.66' HI.. DATE 09/11/82 09/11/82 03/11/02 11/08/02 11/13/02 04/24/03 ÆVBY 1)1.\ TE REV BY COM'v1ENTS 05/16/03 BJtNTLH SETIBP&ANNCOMMNOTE COMIVENTS ORIGINAL COMPLETION LAST WORKOV ER CTDSUSP~ŒD (01-19A) DCRlKK CTDSIŒTRACK (01-19A) M-f/KA K GL V C/O KBlTP MN D & LNRTOP R<R- 9301' BP EXploration (Alaska) ') ) f)OC) -aa& WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard OkIand 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 RE: MWD Fonnation Evaluation Logs: 01-19A, AK-MW-22177 Ol-19A: Digital Log Images 50-029-20800-01 1 CD Rom / () J-/C)L' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~ ~~'-~ ~é:'~ RECEIVED F~~P 2 6 ?n04 ,_.~.J .....1. .ß.~aska au & Gas Cons. Commission þ¡f¡~~e ~~~\rx'\~ Scblum_epgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 A TTN: Beth Well Job# Log Description Date D.S. 1-19A ð~~~ LDL D.S.13-19 .1 ~1 - \ 'X''l") - INJECTION PROFILE D.S. 7-13B!9-~ '- \ \ lo 23057 MCNL 05/11/03 05/07/03 01/15/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED MAY 30 2003 Alaska Oii & Gas Cons. Commi8eion AnchOl'8ge Blueline NO. 2785 Company: 05/15/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk Color Prints 1 1 1 CD "-" }{~JÔ-~ ..".,. ~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received~~~~~ ) J ótœ-{J;) ;;{ II ~t.ol WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 01, 2003 RE: MWD Formation Evaluation Logs 01-19A, AK-MW-22177 1 LDWG formatted Disc with verification listing. API#: 50-029-20800-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: \L2 /. ()n - - ) Si~.~ \'\i.J~"''' \~, ~-- ~ . ;I<m-"'" APR ..\ 7 M t,t1."", Ii. t\lrl,,:W 'Iio" Schlumbepgel' Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 A TIN: Beth Well K-317B ó(O/-/5~ L5-09 I q ()-/~4 L-02 ~n J-~OJ L-02 L-02 L-02 L-02 V D.S. 1-19A rl~ -Œd. J-27 A d Orl-~(> 0 L3-02 J~In-J 54 K-317B ;:} l¡- J 5 (i. K-317B K-317B Job# Log Description Date 23013 MCNL 23007 RST-SIGMA 23003 OH EDIT PEX,AIT & BHC (PDC) 23003 PEX-RESISTIVITY 23003 PEX-NEUTRON/DEN 23003 PEX-BHC 23003 PEX-CALIPER. 22510 MCNL (PDC) 23014 MCNL 23006 RST-SIGMA 23045 OH EDIT LWD GR & ROP5 23045 MD SLlMPULSE GR 23045 TVD SLlMPULSE GR 01/02/03 11/03/02 12/08/02 12/08/02 12/08/02 12/08/02 12/08/02 11/06/02 11/15/02 11/10/02 12/30/02 12/30/02 12/30/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED fE8 07 2003 Alaeka Oit & Gas Cons. Commission Anchorage Blueline NO. 2835 Company: 01/30/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Lisburne Sepia Color Prints 1 1 1 1 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATIN: Beth Receíve~ CD ~ 1 1 1 1 1 1 1 ...-- ~ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ~"'""'~'''''"w:~af; 165' SNL, 462' EWL, SEC. 08, T10N, R15E, UM t2/T;~ ! ~";;y~ At top of productive interval _L!:...'f~l::..~! ~';;;..~;~' 2817' NSL, 2263' WEL, SEC. 06, T10N, R15E, UM '.\Ær~L;\.¡;;) ,I..,.......,....';.~.....".;.;~:'.t.'...'....... . .... .......) At t?tal depth, ---;Jl?-_...-.- if.,'" ;:., ,. ,.,.><,>¡, ," 3352 NSL,3265 WEL, SEC. 06, T10N, R15E, UM -. ..y,-~. -.. ..' .. :,._".;c=.,~'.,/" 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 70' ADL 028329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/2/2002 I 11/5/2002 ' 11/8/2002 " 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11584 9010 FT 11551 9016 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, CNL, CCL 23. CASING SIZE 20" 13-3/8" 9-518" ]I' 3-1/2" x 3-3/16" x 2-7/8" WT. PER FT. 91.5# 72# 47# 29# 8.81# / 6.2# /6.16# 27. Date First Production November 14, 2002 Date of Test Hours Tested Classification of Service Well 7. Permit Number 202-022 302-321 8. API Number 50- 029-20800-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 01-19A 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2168' MD 1900' (Approx.) -V(.)~Ø?Ù 1&$'1' H1P 8c,B~ '"7Y¿) GRADE H-40 L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 80' 30" 1950# Poleset Surface 2590' 17-1/2" 2202 sx Fondu, 400 sx PF 'C' Surface 9610' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 9305' 9834' 8-1/2" 385 sx Class 'G' 9311' 11584' 3-3/4" 150 sx Class 'G' TUBING RECORD SIZE DEPTH SET (MD) 5-1/2'" 17#, L-80 9242' 4-1/2", 12.6#, L-80 9242' - 9340' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9834' Set Whipstock 9834' P&A 2 Previous Sidetrack Attempts with 11 Bbls Class 'G', Pressure to 1500 psi Freeze Protected with 32 Bbls MeOH 25. MD TVD AMOUNT PULLED PACKER SET (MD) 9231' CHOKE SIZE GAS-OIL RATIO 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 10870' - 10930' 9033' - 9033' 11330' - 11470' 9028' - 9029' 1400' PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. - No core samples were taken. R E C E , V E D Form 10-407 Rev. 07-01-80 OIL-BBL GAs-McF WATER-BBL ~ßOMS BFL Ð(-r.... CG '~1 ,--. . OIL GRAVITY-API (CORR) DEC 2 7 2002 A1~sRa Oil & Ga. s Cons. C. ommiss~(mf'..'- Anchorage LJ Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 3 9977' 8803' Zone 2C 10097' 8899' Zone 28 10170' 8946' Zone 2A 10320' 90191 31. List of Attachments: Summary of Pre-Rig Work, Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed TerrieHUbble~~ ~ Title Technical Assistant Datel::t-Â7.0~ 01-19A 202-022 302-321 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Mary Endacott, 564-4388 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ') ) Well: Field: API: Permit: 01-19A Prudhoe Bay Unit 50-029-20800-01 202-022 Rig Accept: 1 0/31/02 Rig Spud: 11/02/02 Rig Release: 11/08/02 Drilling Rig: Nordic #1 PRE-RIG WORK 03/23/02 DRIFT AND TAGGED WI 3.80 CENT. TEL, AND 3.65 LIB TO 9881' CORRECTED TO (GOOD IMPRESSION OF COIL FISH). RAN PDS MEM GRICCL AND LOGGED FROM 9850' AMS TO 9100' AMS. LEFT WELL SHUT IN. 1 0/22/02 DRIFT TO FISH @ 9865' SLM, CALIPER LINER FROM 9860' SLM TO 9328' SLM. RDMO. WELL TO REMAIN SHUT IN. 1 0/24/02 MIT-OA, 3000 psi, PASSED. 1 0/27/02 PPPOT-T PASSED, PPPOT-IC FAILED (VOID WOULD NOT BLEED TO ZERO). 10/30/02 DRIFT & TAG WI 3.65" DUMMY WHIPSTOCK @ 9894' SLM. TARGET WAS 9830 I ELM. PERFORATE 9830' - 9840' WI 3 3/8" PJ LOADED 4 SPF. ALL SHOTS FIRED. 10/31/02 SET BAKER GEN 11,4 1/2" X 7" WHIPSTOCK WI TOP AT 9830' (ORIENTED 36 DEG LEFT OF HIGH SIDE). TWO PIP TAGS @ 9840'. TAG AND CONFIRM GOOD SET. NOTIFY PAD OPER OF STATUS. WELL SHUT IN WAITING FOR RIG. ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 3/312002 00:00 - 06:00 6.00 MOB P PRE Mobilze Nabors 35 from S-17C to DS 1-19A 06:00 - 14:00 8.00 RIGU P PRE RIU Nabors 35. DS CTU #4 is in Deadhorse changing out CT spool, making modifications to suction of unit's pump and misc. other work. They called at 1030 hrs with update. Found some cracks in the derrick that's needs welded. ETA on location 2300 hrs. 14:00 - 19:00 5.00 BOPSURP SURF Accept Nabors 3S. Start nipple up of BOPE. Same time Veco set in backside and upright tanks. 19:00 - 22:30 3.50 BOPSUR P SURF Set test plug in wellhead. Grease all bope valves. AOGCC rep Chuck Sheve has wavied witnessing test of BOPE. 22:30 - 00:00 1.50 BOPSUR P SURF Test BOPE 5 min 5k psi high I 5 min 250 psi low. DS CTU #4 arrived location at midnight. Now has 30 hrs total maint time for this month. 3/4/2002 00:00 - 03:25 3.42 BOPSUR P SURF Finish testing BOPE. DS CTU #4 on location at OOOOhrs. Start r/u. 03:25 - 04:00 0.58 BOPSUR P SURF Pull test plug f/wellhead. 04:00 - 04:25 0.42 SlWHIP P WEXIT PJSM on p/u and stabbing of coil to injector. 04:25 - 10:30 6.08 SlWHIP P WEXIT Continue r/u of CTU stab pipe finish connect elec/pump control lines from Nabors rig. Make up DS CTC replace pack-off and brass in the stuffing box. PJSM covering meth direction. And flush new CT with 1.375" ball. 10:30 - 10:45 0.25 SlWHIP P WEXIT PJSM review methanol handling procedures for CT cleanout. 10:45 - 11 :35 0.83 SlWHIP P WEXIT Drop 1.375" ball and sweep CT with 54 bbls methanol. 11 :35 - 13:20 1.75 SlWHIP P WEXIT Cut-off CTC and recover ball. Rehead CTC pull test 30k and PT to 3500 psi. 13:20 - 14:40 1.33 SlWHIP P WEXIT Displace methanol from coil. Same P/U BHA #1. 14:40 -15:15 0.58 SlWHIP P WEXIT PT MHA to 3500 psi. Stab onto well 15:15 - 16:10 0.92 SlWHIP P WEXIT RIH to 3500' displacing diesel in wellbore 16:10 - 17:40 1.50 SlWHIP P WEXIT Continue RIH tag up at XN nipple 9328'. Stop correct coil depth -13' correction. RIH back to XN nipple. 17:40 - 18:10 0.50 SlWHIP P WEXIT Mill out XN nipple. Run through w/o pump ok. 18:10 - 18:55 0.75 SlWHIP P WEXIT Continue RIH to top of whipstock. No cement. Find pinch point at 10087'. Flag pipe. 18:55 - 00:00 5.08 SlWHIP P WEXIT Start time milling window at 10089.4' mill to 10092.2' Milled wI <2k wob. 3/512002 00:00 - 03:30 3.50 SlWHIP P WEXIT Continue milling window f/1 0092.2' to 10096.5' Window: 10089.4' - 10096.5' 03:30 - 04:30 1.00 STWHIP P WEXIT Drill cmtlformation from 10097.1' to 10107'. WOB 2500# Sample show 95% cement 04:30 - 05:20 0.83 STWHIP P WEXIT Backream through window @ 1.2'/min and back down through window. Stopped at 10108' not stacking weight. RIH to 10121' still not stacking weight. P/U to window RIH dry tag at 10150'. P/U RIH min rate tag at 10172'. P/U above window. RIH dry no problems through window and tagged again at 10172'. Each time P/U apprx 3-5k overpull at 10105'. 05:20 - 07:40 2.33 STWHIP P WEXIT TOH. BHA parted at the non-rotating joint. 07:40 - 09:40 2.00 STWHIP N DFAL WEXIT Gather up fishing tools. Fish looking up: lower portion of disconnect (3.062"00 0.99' long), XO, 2 jts 2 3/8" PH-6 tbg, XO, motor, string mill, window mill. Total length 79.65' Top offish 10027.35'. 09:40 - 10:00 0.33 STWHIP N DFAL WEXIT Tools on location. PJSM covering p/u bha, fishing procedure and bhalfish retrieval procedures on surface. 10:00 - 11 :40 1.67 STWHIP N DFAL WEXIT Cut 15' of coil. Cut-off DS eTC. MU Baker CTC pull test to Printed: 11/12/2002 10:38:32 AM ) ,) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: , . - ,. " . Ðate. . . Frôm~:To ..HOUf$.[åsk 'code';;NP:f. 3/5/2002 10:00 - 11 :40 1.67 STWHIP N DFAL WEXIT 11:40 -12:00 0.33 STWHIP N DFAL WEXIT 12:00 - 13:35 1.58 STWHIP N DFAL WEXIT 13:35 - 14:00 0.42 STWHIP N DFAL WEXIT 14:00 - 16:30 2.50 STWHIP N DFAL WEXIT 16:30 - 17:00 0.50 STWHIP N DFAL WEXIT 17:00 - 18:00 1.00 STWHIP N DFAL WEXIT 18:00 - 18:30 0.50 STWHIP N DFAL WEXIT 18:30 - 19:00 0.50 STWHIP N DFAL WEXIT 19:00 - 20:50 1.83 STWHIP N DFAL WEXIT 20:50 - 21 :00 0.17 STWHIP N DFAL WEXIT 21 :00 - 21:10 0.17 STWHIP N DFAL WEXIT 21:10-21:15 0.08 STWHIP N DFAL WEXIT 21:15-21:18 0.05 STWHIP N DFAL WEXIT 21:18 - 22:20 1.03 STWHIP N DFAL WEXIT 22:20 - 00:00 1.67 STWHIP N DFAL WEXIT 3/6/2002 00:00 - 00:45 0.75 STWHIP N DFAL WEXIT 00:45 - 02:00 1.25 STWHIP N DFAL WEXIT 02:00 - 03:14 1.23 STWHIP N DFAL WEXIT 03:14 - 06:15 3.02 STWHIP N DFAL WEXIT 06:15 - 09:30 3.25 STWHIP N DFAL WEXIT 09:30 - 10:15 0.75 STWHIP N DFAL WEXIT 10:15 - 12:00 1.75 STWHIP N DFAL WEXIT 12:00 - 13:30 1.50 STWHIP N DFAL WEXIT 13:30 - 15:30 2.00 STWHIP N DFAL WEXIT 15:30 - 17:45 2.25 STWHIP N DFAL WEXIT 17:45 - 19:30 1.75 STWHIP N DFAL WEXIT 19:30 - 21 :21 1.85 STWHIP N DFAL WEXIT 21 :21 - 22:15 0.90 STWHIP N DFAL WEXIT 45K PT to 3500. Continue p/u bha #2 Stab on to well. RIH w/ fishing BHA 114.58' Latch fish and jar starting at 10k over and progressing to 40 k over. On third lick at 40 over we came free moved up hole. POH with 2-3k drag. Lay down tool. No Fish. Wait on fishing tools. Crew change and PJSF for picking up fishing BHA. MU Fishing assembly BHA #3. RIH with BHA#3. Jar on fish 11 k to 14 k over string weight Break circulation 1.1@ 790 psi to 1.5 bpm@ 1420 psi. Jar on fish 16k over no go. Circulate while holding 21 k over pick up weight Jar on fish progessive increase over pull. Periodically circulating while hold strain on pipe. 1 bpm @ 700 psi, 1.2 bpm @ 925 psi, 1.6 bpm 1490 psi. Pull to pipe limit 90,000 46k over. Monitoring pipe life while jarring have set 20% pipe life as limit No positive indicators during jarring. Slack off to 8000. 17000 = slackoff weight. Circulate at 1.5 bpm @ 1425 psi. Note we can see pressure increase from 1490 psi to 3030 psi @1.5 bpm with BHA in compression. We believe we are pinching the flow path between the over shot and the upset on the fish. When be pick up to neutral weight the pressure drops back to 1400psi. However, there is no indication on the weight indicator of any pipe movement i.e. flicker. There is no indicating that we are circulating at the bit and no movement of the BHA. We believe to be stuck with cuttings. See Remarks Wait on crude oil while holding strain on pipe 30 over and circulating at 1.5 bpm. Circulate 10 bbl of crude to BHA spot 5 bbl at fish. Spot 5 bbl crude around fish. Hold 30 over. No results. Slack off and Hold. No results. Pressure backside to 500 psi and hold 36k over. Bleed off. Hold 21 k over while circulating at .3 bpm wait on HCL. Circulate 10 bbl of 15% HCL . Displace and spot 5 bbl out side fish. Bullhead .5 bbl every 15 minutes. Sit in compression. Bull head backside 700 psi .5 bbl every 15min. Pull to maximum (+/-93K). Pop free. POOH to check BHA. LD Fishing BHA #2. No recovery. Lost a 1/2" x 1" of spiral grapple. Set injector on back deck. Inspect same. Replace several broken chain bearings. MU undereaming assy with DB reamer with 6.250 blades. RIH with assembly Tag fish at 10044'. Correct depth to 10027' and flag pipe. POOH to 9957'. 43.5k# up wt. Begin reaming dn with 2.5 bpm, 1950 psi, 20 fph to start. Ream up 10,020' to 9,055'. POH to surface. Set injector back on deck. Printed: 11/1212002 10:38:32AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 3/6/2002 3/7/2002 22:15 - 00:00 00:00 - 00:15 00:15 - 02:00 02:00 - 02:40 1.75 STWHIP N 0.25 STWHIP N 1.75 STWHIP N 0.67 STWHIP N DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT 02:40 - 03:30 0.83 STWHIP N DFAL WEXIT 03:30 - 04:30 1.00 STWHIP N DFAL WEXIT 04:30 - 05: 15 0.75 STWHIP N DFAL WEXIT 05: 15 - 06:45 1.50 STWHIP N DFAL WEXIT 06:45 - 09:30 2.75 STWHIP N DFAL WEXIT 09:30 - 09:45 0.25 STWHIP N STUC WEXIT 09:45 - 10:30 0.75 STWHIP N STUC WEXIT 10:30 - 11 :00 0.50 STWHIP N STUC WEXIT 11 :00 -13:00 2.00 STWHIP N STUC WEXIT 13:00 -14:45 1.75 STWHIP N STUC WEXIT 14:45 - 16:45 2.00 STWHIP N STUC WEXIT 16:45 - 17:30 17:30 - 19:30 STUC WEXIT STUC WEXIT 0.75 STWHIP N 2.00 STWHIP N 19:30 - 20:00 0.50 STWHIP N 20:00 - 21 :50 1.83 STWHIP N 21:50 - 23:10 1.33 STWHIP N 23:10 - 23:55 0.75 STWHIP N 23:55 - 00:00 0.08 STWHIP N 3/8/2002 00:00 - 01 :00 1.00 STWHIP N 01 :00 - 02:15 1.25 STWHIP N 02:15 - 04:15 2.00 STWHIP N STUC WEXIT STUC WEXIT STUC WEXIT STUC WEXIT STUC WEXIT STUC WEXIT STUC WEXIT STUC WEXIT .9~çri,p~pn:ë)fØpå,àtioøs . PU whipstock and rig up Eline. Complete rigging up wireline. RIH with whipstock Tie in -3' correction. Didn't have sufficient distance between the fish and perferred setting depth of the whipstock to orient to the desired tool face. We had to move up one joint. Set whipstock with TOW 9950' RA 9960' with toolface 15L. POH Rig down Eline MU milling assembly for second window. TOW at 9950'. Tag whipstock at 9970 '. Correct to ELM depth of 9950'. Flag pipe at 9950 Begin milling window at 9949.5. 1850 psi @ 2.5 bpm. Mill to 9954'. 1650 psi FS @ 2.5 bpm. 400-600 dpsi. 300-1000# wob. Stall and try to PU. Stuck (stalled). Order crude and slick pill. Work pipe & pump. Pull up to 95K#. Pipe appeared to stretch up to 10'. Pressure back side and coil to 2100 psi. Work pipe to max of 81 K#. Cycle pipe. No movement. Bleed pressure rapidly and pull. No movement. Pressure to 2500 psi. Repeat. Same. Wait on fluids. Pump 15 bbls crude. Spot 5 bbls out of coil. Pressure annulus to 2000 psi to bull head away. Let soak. Work pipe to 90K#. No movement. Repeat 2 more times. Pump 18 bbls new flopro with 3% lubtex & 3% flolube. Spot 5 bbls out coil. Bullhead same & pressure annulus to 2500 psi. Work pipe to 85K#. No movement. Repeat several times. No movement. Wait on HCL acid from DS. Spot 6 bbls 15% HCL around fish. Allow to soak. Work pipe and pressure annulus. No movement. Circ ball to disconnect from fish. On seat at +/- 40 bbls away. Sheared at 4300 psi. POOH Inspect pin and bearings on injector. Install coil connector. Pull test to 45000# and pressue test to 3500 psi. PU fishing BHA Make up BHA for fishing milling assembly form second window. RIH to 9872. Pick up 38,000# S020,000# Latch fish. Jarred down progressively increasing set down weight from 2000 to -27000. No movement. Jarred up progessively increasing up force from 56,000 to 92,000. Attempted jarring while pumping, while pressuring system and while pumping down the back side without success. Some movement +- 2' was seen at 51000# but we were unable to progess it. A total of 75 jar licks 22 dn 53 up were made. Ran out of coil live . Disconnected. POH. Printed: 11/1212002 10:38:32 AM ) \) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 . Date, . . From-To Hours .Tà$k:',;.;c~.. ~PT' '. Rnãsé,. 3/8/2002 2.00 STWHIP N STUC WEXIT 02:15 - 04:15 10/31/2002 04: 15 - 06:00 1.75 STWHIP N STUC WEXIT 06:00 - 06: 15 0.25 STWHIP P WEXIT 06: 15 - 07:00 0.75 STWHIP N STUC WEXIT 07:00 - 07: 15 0.25 STWHIP P WEXIT 07:15 - 14:00 6.75 RIGD P COMP 14:00 - 20:00 6.00 RIGD P COMP 09:00 - 09:30 0.50 MOB P PRE 09:30 - 10:00 0.50 MOB P PRE 10:00 -10:30 0.50 MOB P PRE 10:30 - 11 :00 0.50 MOB P PRE 11:00 -15:00 4.00 MOB P PRE 15:00 - 16:30 1.50 MOB P PRE 16:30 - 16:45 0.25 MOB P PRE 16:45 - 17:00 0.25 MOB P PRE 17:00 - 18:00 1.00 BOPSURP PRE 18:00 - 18:15 0.25 BOPSUR P PRE 18:15 - 20:15 2.00 BOPSURP PRE 20: 15 - 00:00 3.75 BOPSURP PRE 00:00 - 04:45 4.75 BOPSURP DECOMP 04:45 - 05:00 0.25 BOPSUR P DECOMP 05:00 - 05:30 0.50 KILL P DECOMP 05:30 - 07:15 1.75 KILL P DECOMP 07: 15 - 07:30 0.25 KILL P DECOMP 07:30 - 09:30 2.00 KILL P DECOMP 09:30 - 09:45 0.25 KILL P DECOMP 09:45 - 10:00 0.25 PXA P DECOMP 10:00 - 10:15 0.25 PXA P DECaMP 10:15 - 10:30 0.25 PXA P DECOMP 10:30 - 11 :00 0.50 PXA P DECOMP 11/1/2002 11:00-11:15 0.25 PXA DECOMP P Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: , ., " , fDf:)$crip~.oJ1.'ØfØp~rati:on~ With only 4' of window cut it appears we jumped out early. Hovever, the cementing records and the CBL all indicate that the cement job was good and contrary to jumping out early. POH to 2000 and lay in freeze protection methanol. Hold PJSM.crew change mtg. LD fishing tools. Hold safety mtg before beginning RD. Rig down coil unit. Set BPV. Clean pits. ND BOPS. Release rig at 1400 hrs 3/8/02. CTU #4 off location at 1500 hrs. Continue to prep for move to DS 3-34A PJSM for moving rig off well. Review checklist, procedure, hazards and mitigations. Jack-up rig & move off 01-12A. Nipple up & pressure test tree cap on 01-12A. Meanwhile W/L unit is RID on 01-19. Load out 10 rig mats from 01-12A & tidy-up pad. Carryout pad inspections for 01-12A & 01-19. Rig Standby. W.O. tool services to level 01-19 location. PJSM. N/D 01-19 tree cap & set spill dike. PJSM for moving rig over well. Review checklist, procedure, hazards and mitigations. Mover rig over 01-19 & set down. Accept rig @ 17:00 hrs on 10/31/2002. PJSM. NU BOPE. Crew change & PJSM. Continue NU BOPE. Spot slop tank and berm. Move camp Perform initial BOPE press / function test. AOGCC test witness waived by John Spaulding. Finish initial BOPE test. PT inner reel valve Check well for press and bleed 20 psi to slop tank MU cement nozzle assy RIH w/ BHA #6 taking returns to slop tank. Tag whipstock @ 9856' & stack wt - holding. Correct to ELM pinch pt of 9835'. P/U 10' & flag pipe. PUH with no ~/pull. RBIH to flag. Held pre-spud/operations safety mtg. Review well plan, hazards, mitigations etc. Meanwhile displace wellbore to 2% KCL water. Continue displacing wellbore to 2% KCL water, diverting gassy returns to tiger tank. SI well & observe stable well. Observe Opsi on the IA & 965psi on the OA. Bleed down OA to 280psi. Inject KCL water @ 1500psi max & observe 0.2bpm injectivity. PJSM for cement job. Batch-up cement. Meanwhile circ well @ 1.2I1.2bpm & 950psi. DS flush lines with 5bbls of water. PIT est to 4000psi. Pump 5bbls of water ahead. Pump 10.6bbls Class G neat slurry at 15.8 ppg & follow with 5 bbl water behind. Displace with 2# bio KCL water @ 2.5bpm & 1250psi & reduce to 1 bpm as cmt reaches nozzle. SI choke with cement @ nozzle & WHP pressured up to 1500psi while reducing rate to 0.2bpm with ca. 0.3bbls squeezed away. Open choke. PUH laying in remaining cement to WCTOC @ 9555' & maintaining 1500psi WHP. Printed: 11/1212002 10:38:32 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N 1 Spud Date: 8/25/1982 End: 11/1/2002 11 : 15 - 11 :30 0.25 PXA P DECOMP PUH to safety @ 9200' circulating 0.9bpm & maintaining 1500psi WHP. 11 :30 - 12:00 0.50 PXA P DECOMP SI choke & maintain 1500psi for 30 min - observe no pressure loss. 12:00 - 12:20 0.33 PXA P DECOMP Bleed off pressures. RBIH jetting @ 2.6bpm & 1630psi to whipstock tray @ 9833' . 12:20 - 14:30 2.17 PXA P DECOMP POOH circulating contaminated cement OOH. Dumped 145bbls cmt contaminated KCI (max wt - 9.35ppg). 14:30 - 15:00 0.50 PXA P DECOMP LD cementing BHA. 15:00 - 16:00 1.00 PXA P DECOMP RIH with side jet nozzle to jet stack. Tag up @ 9.3'. Jet to surface. POOH & add 5' PH6 Pup/jt. RBIH & jet complete BOP. SI swab valve. 16:00 - 16:15 0.25 PXA P DECOMP PJSM for DS dimple CTCs science pull test. Review procedures & emphasize injector/pull plate is placed as close as possible to the floor & floor area is cleared of personnel with all entraces flagged off. 16:15 - 17:00 0.75 PXA P DECOMP Cut off Baker CTC. Install DS dimple CTC#1. Pull to failure @ 62k. 17:00 - 17:45 0.75 PXA P DECOMP Cut off DS CTC#1. Install DS dimple CTC#2. Pull to failure @ 61k. 17:45 - 18:30 0.75 PXA P DECOMP Cut off DS CTC#2. Install DS dimple CTC#3. Pull to failure @ 60k. Calc was to be 61.5k on all tests 18:30 - 19:50 1.33 STWHIP P WEXIT Install Baker CTC. PT 35k, 3500, psi. Safety mtg re: prespud/BHA MU milling BHA 19:50 - 21 :30 1.67 STWHIP P WEXIT RIH wI BHA #7 (3.80" mill). Comp str of cmt 2000 psi 21 :30 - 21 :40 0.17 STWHIP P WEXIT Tag pinch point at 9856.9' and corr to 9834.0'. PUH 41 k and start motor, 2.5/1930. First motor work at 9~4', flag it, stall at 9834.1', twice 21:40 - 22:10 0.50 STWHIP P WEXIT Milling window from 9833.9' 2.6/2080 PVT 178 ~ 22:10 - 22:50 0.67 STWHIP P WEXIT 9835.0' 22:50 - 23:40 0.83 STWHIP P WEXIT 9836.0' 23:40 - 00:00 0.33 STWHIP P WEXIT 9837.0'-9837.4' 11/2/2002 00:00 - 00:35 0.58 STWHIP P WEXIT 9837.4' Milling window wI avg 150 psi diff and 2k WOB 00:35 - 01 :30 0.92 STWHIP P WEXIT 9838.0' 01 :30 - 02:25 0.92 STWHIP P WEXIT 9839.0' and stalled (btm of window), PU 40k, clean. Drill formation slowly w/ 4k 02:25 - 03:00 0.58 STWHIP P WEXIT 9840.0' Chk tag at 9840.7', PUH 39.8k, clean 03:00 - 03:15 0.25 STWHIP P WEXIT 9841.0' PVT 175 400 psi and 6k 03:15 - 04:45 1.50 STWHIP P WEXIT 9841.1' Drilling formation too slow. PUH 38k, clean. POOH to check mill and put on SR 04:45 - 05:20 0.58 STWHIP P WEXIT Mill had bulls-eye wear in center (1/2" diameter wi no diamonds and 1" dia wi very worn diamonds), wI little wear in other areas 3.80"-. LD mill and make up a good used one along with 3.80" SR 05:20 - 07:00 1.67 STWHIP P WEXIT RIH wi BHA #8 to 9800'. Up wt check - 41.5k. Run-in wt - 23.5k. RIH to 9821' & correct CTD to 9800' (-21' normal correction). Bring pumps up 2.5/1980. Continue RIH & tag @ 9838'. 07:00 - 07:30 0.50 STWHIP P WEXIT Time mill @ 0.1'/6mins with 2.5/2.5bpm, 1980/2200psi & OK WOB. Milled to 9838.2' & stall 2x - seems like string reamer is @ window top. P/U clean @ 41 k. 07:30 - 12:30 5.00 STWHIP P WEXIT Ease-in from 9838.1'. Continue time milling @ 0.1'/6mins with Printed: 11/1212002 10:38:32AM 'I) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date F'roira'..Tø:Hours"Tâsl< . COde NI?Iehase 11/2/2002 07:30 - 12:30 5.00 STWHIP P 12:30 - 13:00 0.50 STWHIP P 13:00 - 13:10 0.17 STWHIP P 13:10 - 13:40 0.50 STWHIP P 13:40 - 14:45 1.08 STWHIP P 14:45 - 16:30 1.75 STWHIP P 16:30 - 17:15 0.75 STWHIP P 17:15 - 17:30 0.25 DRILL P 17:30 - 18:30 1.00 DRILL P 18:30 - 18:40 0.17 DRILL P 18:40 - 19:00 0.33 DRILL N 19:00 - 20:15 1.25 DRILL N 20: 15 - 20:25 0.17 DRILL N 20:25 - 22:00 1.58 DRILL P 22:00 - 22:30 0.50 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 22:30 - 23:05 0.58 DRILL P 23:05 - 00:00 0.92 DRILL P 11/3/2002 00:00 - 00:15 0.25 DRILL P 00:15 - 01 :15 1.00 DRILL P 01:15 - 01 :30 0.25 DRILL P 01 :30 - 04:00 2.50 DRILL P 04:00 - 05:20 1.33 DRILL P 05:20 - 05:50 0.50 DRILL P 05:50 - 07:30 1.67 DRILL P 07:30 - 07:45 0.25 DRILL P 07:45 - 08:00 0.25 DRILL P 08:00 - 09:00 1.00 DRILL P 09:00 - 09:45 0.75 DRILL P 09:45 - 10:00 0.25 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N 1 Spud Date: 8/25/1982 End: ~$ç~iptiQfJ:of~)perElti;(:)~š . 2.5/2.5bpm, 2100-2350psi & 2-4K WOB. Milled to 9843' & Stall 2x. Saw flag @ 9839' & increase in motor work from 9841.8'. P/U clean @41k. Ease-in & see motor work from 9842.6'. Mill to 9843.2' with 400psi motor work & 0 WOB. DS mill must be in open hole now with string reamer @ the window. Continue milling with 2.5/2.5bpm, 2000/2450psi & 0-1K WOB. Milled to 9843.4' & observe CT pressure drop to 2270psi - string reamer must have popped out of window btm. Mill formation with 2.5/ 2.5bpm, 2000/2200psi, 2K WOB & increased ROP. Milled to 9851' . Dress/drift window & make several backream passes with & without pumping. Window looks clean. TOW = 9834' & BOW = 9839' & TD = 9850'. Paint EOP flag @ 9700' & POOH window milling BHA#8. Layout & inspect milling BHA#1. Window mill gauge 3.79" & string reamer gauge 3.80". A little wear on mill taper. PJSM on M/U drilling BHA#9. M/U build section BHA#9 with 1.37 deg bend motor, MWD. M/U injector. RIH w/ BHA #9. SHT failed POOH for MWD Find MWD generator packed with metal fines. Displace surface lines and CT with used mud while empty and clean pits RIH w/ BHA #9RR SHT, ok. RIH RIH to 9831'. Corrto 9810'. Log up from 9800' to tie-in to "mother". Begin well displacement of bio water to used Flo Pro mud 2.7/3240/150R Corr -1'. Orient to go thru window to 40L. RIH thru window, clean and tag at 9850'. Chk TF at 54RL Orient around Drilling 2.5/3060/54L 60'/hr. See RA marker on depth at 9840'. Drill to 9898' Orient around Drill from 9898-9962' 2.4/2980/179R to drop into Z3 Orient to HS Drill from 9962' 2.5/31 00/1 OLat 50'/hr. Took a 5 bbl drink at 9970'. Drill from 9978' in Z3 at 10'/hr Drill to 9992' and penetration rate too slow due to stalls (hard Z3 rock). POOH for bit Change bit to tricone (M09X was 2-5-1 and starting to core) RIH w/ BHA #10 to 9822'. Correct CTD to 9800' (-22'). Run smoothly thru window & tag up @ 9980'. Orient TF to 10L & ream to btm @ 9992'. P/U wt = 40k. Slackoff wt = 21 k. Freespin @ 2.3bpm = 2900psi. Break-in bit & drill to 9997' with 2.3/2.3bpm, 2900/2950psi & <1 k WOB. Drill to 10030' with 20L TF, 2.3/2.3bpm, 2900/3050psi, 3k WOB 28fph ave ROP. Orient & drill to 10050' with 20L TF, 2.3/2.3bpm, 2900/3050psi, 3k WOB 30fph ave ROP. Should be out of Zone3 now. Last 10' was pretty hard. Continue drilling to 10058' with 20L TF, 2.3/2.3bpm, Printed: 11/1212002 10:38:32 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 11/3/2002 09:45 - 10:00 0.25 DRILL P PROD1 2900/3050psi, 3k WOB 39fph ave ROP. Will drill on till btms up confirms we're out of Zone3 or till 5hrs on bit. 10:00 - 10:20 0.33 DRILL P PROD1 Orient & drill to 10068' with 20-45R TF, 2.3/2.3bpm, 2880/3050psi, 3k WOB 40fph ave ROP. TF rolled over to 60R. 10:20 - 10:45 0.42 DRILL P PROD1 Orient TF to 1 OR. 10:45 - 12:00 1.25 DRILL P PROD1 Drill to 10095' with 15RTF, 2.3/2.3bpm, 2880/3050psi, 3k WOB 35fph ave ROP. Geo is seeing lot more sand than chert in 10050'sample. Decide to POOH for bit change & to P/U resistivity. 12:00 - 13:45 1.75 DRILL P PROD1 POOH BHA#10. 13:45 - 14:00 0.25 DRILL P PROD1 PJSM on UD BHA#10 & P/U BHA#11. 14:00 - 14:30 0.50 DRILL P PROD1 Download MWD memory data. UD BHA#10. Bit grades 2-4-1 with 1 failed cone bearing. 14:30 - 15:15 0.75 DRILL P PROD1 M/U BHA#11 with used HYC DS49, 1.37 deg bend motor & resistivity MWD. 15:15 - 16:00 0.75 DRILL P PROD1 Initialize MWD tool. M/U injector. 16:00 - 18:10 2.17 DRILL P PROD1 RIH with drilling BHA #11 to 3000'. SHT - OK. RIH to 9822'. Correct CTD to 9800' (-22'). Continue RIH thru window to 9900'. Ream to btm tagged @ 10095'. 18:10 - 18:20 0.17 DRILL P PROD1 Orient TF to 1 OR. 18:20 - 20:30 2.17 DRILL P PROD1 Drill from 10095' with 10L TF, 2.6/2.6bpm, 3000/3350psi. Drill to 10200' 90R 20:30 - 20:45 0.25 DRILL P PROD1 Orient around 20:45 - 21 :25 0.67 DRILL P PROD1 Drill from 10200-250' 2.5/3100/9L 21 :25 - 21 :50 0.42 DRILL P PROD1 Wiper to window 21 :50 - 23:40 1.83 DRILL P PROD1 Drilling from 10250' 2.6/3150/5R-54R. Drill to 10325' 23:40 - 23:55 0.25 DRILL P PROD1 Orient to left 23:55 - 00:00 0.08 DRILL P PROD1 Drill to 10330' 2.4/3020174L 11/4/2002 00:00-01:15 1.25 DRILL P PROD1 Drill from 10330-400" 2.5/3100/12L 01:15 - 01:30 0.25 DRILL P PROD1 Wiper to window, clean 01 :30 - 01 :45 0.25 DRILL P PROD1 Log tie-in up from 9895' Rig evacuation drill, discussion 01 :45 - 02:05 0.33 DRILL P PROD1 Add 1.0', RIH 02:05 - 04:00 1.92 DRILL P PROD1 Drill from 10400' 2.5/31 00/1 OR 04:00 - 04:30 0.50 DRILL P PROD1 Land well at 10467' MD, 8977' TVD. Drilling 2.5/3100/5R building angle to 95 deg 04:30 - 05:00 0.50 DRILL P PROD1 10490' Orient to left 05:00 - 05:40 0.67 DRILL P PROD1 Drilling 2.5/3100/90L Drill to 10519' and should be drilling like a house afire, motor stalls too quick 05:40 - 05:50 0.17 DRILL P PROD1 Survey 05:50 - 06:15 0.42 DRILL P PROD1 Wiper to window 06:15 - 07:30 1.25 DRILL P PROD1 POH for motor 07:30 - 07:45 0.25 DRILL P PROD1 PJSM on UD BHA#11 & P/U BHA#12. 07:45 - 08:00 0.25 DRILL P PROD1 UD BHA#11. Found nothing amiss with motor - will further check @ BHI shop. Bit grades 5-2-1. 08:00 - 09:15 1.25 DRILL P PROD1 MIU BHA#12 with new HYC DS49, 1.04 deg bend motor & resistivity MWD. Scribe tools. Download & initialize MWD tool. MIU injector. 09:15 -11:15 2.00 DRILL P PROD1 RIH with drilling BHA #12 to 3000'. SHT - OK. RIH to 9822'. Correct CTD to 9800' (-22'). Continue RIH thru window to 10519'. 11: 15 - 11 :20 0.08 DRILL P PROD1 Orient TF to 80R. 11 :20 - 11 :45 0.42 DRILL P PROD1 Drill to 10535' with 80R TF, 2.5/2.5bpm, 3000/3450psi, 2k Printed: 11/12/2002 10:38:32AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 11/4/2002 11 :20 - 11 :45 0.42 DRILL P PROD1 WOB 40fph aye ROP. No stalls. Geo wants to steer trajectory more to the North of polygon. Start pumping new mud downhole. 11 :45 - 12:30 0.75 DRILL P PROD1 New mud @ the bit. Continue drilling to 10597' with 80R TF, 2.8/2.8bpm, 3300/3550psi, 2k WOB 90fph aye Rap. 12:30 - 12:40 0.17 DRILL P PROD1 Orient 1 click & drill to 10611' with 90R TF, 2.8/2.8bpm, 3300/3550psi, 2k WOB 95fph aye ROP. 12:40 - 12:50 0.17 DRILL P PROD1 Orient TF to 115L. 12:50 - 12:55 0.08 DRILL P PROD1 Drill to 10616' with 140L TF, 2.8/2.8bpm, 3300/3450psi, 2k WOB 120fph aye ROP. 12:55 - 13:20 0.42 DRILL P PROD1 Orient 3 click & drill to 10656' with 120R TF, 2.8/2.8bpm, 3200/3550psi, 2k WOB 120fph aye ROP. 13:20 - 13:40 0.33 DRILL P PROD1 Orient 2 click & drill to 10690' with 80R TF, 2.8/2.8bpm, 3200/3750psi, 2k WOB 140fph aye ROP. 13:40 - 14:30 0.83 DRILL P PROD1 Wiper clean to window. RBIH to btm. 14:30 - 15:10 0.67 DRILL P PROD1 Orient TF around to 75R. 15:10 - 17:00 1.83 DRILL P PROD1 Orient & drill to 10786' with 80L TF, 2.8/2.8bpm, 3200/3450psi, 2k WOB 63fph aye ROP. 17:00 - 17:05 0.08 DRILL P PROD1 Orient TF to HS. 17:05 - 17:30 0.42 DRILL P PROD1 Drill to 10813' with 1L TF, 2.8/2.8bpm, 3000/3350psi, 2k WOB 67fph aye ROP. 17:30 - 17:50 0.33 DRILL P PROD1 Orient TF around to 70L. 17:50 - 18:20 0.50 DRILL P PROD1 Drill to 10850' with 80L TF, 2.8/2.8bpm, 3000/3250psi, 2k WOB 70fph aye ROP. 18:20 - 18:50 0.50 DRILL P PROD1 Wiper to window. 18:50 - 19:05 0.25 DRILL P PROD1 Log tie-in up from 9890' 19:05 - 19:45 0.67 DRILL P PROD1 No corr. RIH and tag TD at 10850'. Orient 19:45 - 20:10 0.42 DRILL P PROD1 Drilling 2.5/3000/65L holding 91 deg from 8963' TVD. Drill to 10890' 20:10 - 20:35 0.42 DRILL P PROD1 Orient around 20:35-21:15 0.67 DRILL P PROD1 Drilling 2.5/3000/147L-90L. Drill to 10947' 21:15 - 21:25 0.17 DRILL P PROD1 Orient two clicks while swapping mud pumps due to valve washing out 21 :25 - 22:00 0.58 DRILL P PROD1 Drilling from 10947' 2.6/3100/13L-1 L. Drill to 11000' and losing angle in soft sand 22:00 - 22:35 0.58 DRILL P PROD1 Wiper to window 22:35 - 23:50 1.25 DRILL P PROD1 POOH for motor bend 23:50 - 00:00 0.17 DRILL P PROD1 Adjust motor to 1.37 deg. Change bit (4-3-1) 11/5/2002 00:00 - 01:10 1.17 DRILL P PROD1 Download res data. MU drlg assy 01:10 - 03:00 1.83 DRILL P PROD1 RIH w/ BHA #13 03:00 - 03:30 0.50 DRILL P PROD1 Corr -22' at 9822'. RIH thru window, clean at 90L. Precautionary ream to TD 03:30 - 03:45 0.25 DRILL P PROD1 Tag TD at 11007', carr to 11000'. Orient to HS 03:45 - 04:05 0.33 DRILL P PROD1 Drill from 11000' 2.5/2850/22L Drill to 11028' and see that previous motor had started good build at 11000' 04:05 - 04:20 0.25 DRILL P PROD1 Orient around 04:20 - 04:35 0.25 DRILL P PROD1 Drill from 11028-11060' 2.5/2850/90L and shoot for 8958-61' TVD 04:35 - 05:20 0.75 DRILL P PROD1 Orient to knock down build. Drill from 11060-11115' 2.5/2850/174L 05:20 - 05:35 0.25 DRILL P PROD1 Orient to hold at 8960' TVD. Stack out before TD. 100' wiper. 05:35 - 05:50 0.25 DRILL P PROD1 Drill from 11115-11150' 2.5/2900/80L 05:50 - 06:20 0.50 DRILL P PROD1 Wiper to window, clean Printed: 11/1212002 10:38:32AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 11/5/2002 06:20 - 06:35 0.25 DRILL P PROD1 Log tie-in up from 9890' 06:35 - 07:15 0.67 DRILL P PROD1 Add 7.0', RIH to btm. 07:15 - 07:30 0.25 DRILL P PROD1 Orient Tf to 120L to knock down angle. 07:30 - 07:50 0.33 DRILL P PROD1 Drill to 11185' with 120L TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 120fph aye ROP. StII building angle. TVD up to 8952'. 07:50 - 08:10 0.33 DRILL P PROD1 Orient TF to LS to further knock down angle. Aiming for 84 degs to bring TVD to 8960'. 08:10 - 08:50 0.67 DRILL P PROD1 Drill to 11246' with 160R TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 80fph aye ROP. Should have 84 degs @ the bit. 08:50 - 09:00 0.17 DRILL C PROD1 Orient TF to 90L. 09:00 - 09:35 0.58 DRILL C PROD1 Drill to 11287' with 100L TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 60fph aye ROP. See slight build. 09:35 - 09:50 0.25 DRILL C PROD1 Orient TF to 130R. 09:50 - 10:00 0.17 DRILL C PROD1 Drill to 11296' with 170R TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 57fph aye ROP. 10:00 -10:10 0.17 DRILL C PROD1 Orient TF to 130L. 10:10 -10:15 0.08 DRILL C PROD1 Drill to 11302' with 130R TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 50fph aye ROP. Drilling ratty. 10:15-11:35 1.33 DRILL C PROD1 Wiper clean to window. RSIH to btm. 11 :35 - 11 :50 0.25 DRILL C PROD1 Orient & drill to 11322' with 130R TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 90fph aye ROP. 11 :50 - 12:05 0.25 DRILL C PROD1 Orient & drill to 11328' with 100R TF, 2.8/2.8bpm, 3000/3350psi, 2k WOS & 90fph aye ROP. 12:05 -12:15 0.17 DRILL C PROD1 Orient & drill to 11341' with 60L TF, 2.8/2.8bpm, 3000/3350psi. Stacking wt. 12:15 - 12:25 0.17 DRILL C PROD1 100' Wiper. 12:25 - 12:50 0.42 DRILL C PROD1 Orient & drill to 11382' with 20L - HS TF, 2.8/2.8bpm, 3000/3350psi & 120fph aye ROP. 12:50 - 13:00 0.17 DRILL C PROD1 Orient TF to 90L. 13:00 - 13:35 0.58 DRILL C PROD1 Drill to 11430' with 90-120L TF, 2.8/2.8bpm, 3000/3350psi & 120fph aye ROP. Stacking wt. 13:35 - 15:15 1.67 DRILL C PROD1 Wiper clean to window. RSIH to btm. 15:15 - 16:50 1.58 DRILL C PROD1 Drilling ahead at 11498'. Free spin 2750 psi. Pit vol=143 bbls. 16:50 -17:10 0.33 DRILL C PROD1 Angle at bit 102 deg. Orient to 130L to hold angle. 17:10 - 17:50 0.67 DRILL C PROD1 11522', Resume drilling. 17:50 - 18:00 0.17 DRILL C PROD1 11541', 100' wiper trip. Pumped 6% lubetex pill, ROP took off. Adding additoinal 3 drums to pits to raise lubetex concentration. Note - No Flolube available on rig or at plant. 18:00 - 18:10 0.17 DRILL C PROD1 Resume drilling. Can't make much progress. 115' since last wiper. 18:10 - 19:00 0.83 DRILL C PROD1 11545', Wiper trip to shoe. 19:00 - 19:35 0.58 DRILL C PROD1 Log tie-in up from 9890' 19:35 - 20:25 0.83 DRILL C PROD1 Add 13.0', RIH 20:25 - 20:45 0.33 DRILL C PROD1 Tag TD at 11552.9'. DriIl2.6/3000/101L. Drill to 11583', stacking. Overpulls and can't get back to btm. Lose ground to 11540'. Nearing lockup with res tool and mud, 101 deg at bit 20:45 - 21 :55 1.17 DRILL C PROD1 Sackream and work back to TD. No shale showing on GR, but definitely in it. Wiper to window while cuss n discuss, clean 21 :55 - 22:05 0.17 DRILL P PROD1 Log tie-in down from 9875' 2.6/2800/19R 22:05 - 22:50 0.75 DRILL P PROD1 Add 5.6', RIH to TD, clean 22:50 - 23:55 1.08 DRILL P PROD1 Sackream OOH leaving fresh mud in OH (pit volume makeup) 23:55 - 00:00 0.08 DRILL P PROD1 Flag at 9200' EOP. POOH for liner Printed: 11/12/2002 10:38:32 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 11/6/2002 00:00 - 01 :30 1.50 DRILL P PROD1 POOH for liner 01 :30 - 03:00 1.50 DRILL P PROD1 LD drilling BHA. Download resistivity data 03:00 - 03:15 0.25 CASE P COMP RU to run liner 03: 15 - 03:30 0.25 CASE P COMP Safety mtg re: liner 03:30 - 06:30 3.00 CASE P COMP MU 53 jts 2-7/8" 6.16# L-80 STL w/ pup and float equipment Crew chg safety mtg MU 4 jts 3-3/16" 6.2# L-80 TC11 MU 15 jts 3-1/2" 8.81# L-80 STL liner 06:30 - 07:00 0.50 CASE P COMP Safety meeting with day tour crew reguarding liner MU. 07:00 - 08:25 1.42 CASE P COMP MU 3-3/16" Tell, 3-1/2" STL liner. Winds 18 mph, gusting to 40 mph. 08:25 - 09:25 1.00 CASE P COMP MU Baker CTLRT, MHA. C/o CTC Pull test to 35klbs, PT to 3500 psi, passed ok. MU SWS injector to BHA. MU injector to Wellhead. 09:25 - 11 :00 1.58 CASE P COMP RIH with liner. Weight check at 9700'=39,500 Ibs. RIH in open hole. Make -33' correction at 9200' EOP flag. Tag bottom, PU at 43klbs. Set down again to confirm tag. Good tag at 11584'. Made it to TD slick with no problems. 11 :00 - 11 :45 0.75 CASE P COMP SI pumps, drop 5/8" ball to release from liner. Chase with mud. CT volume from dart=57.6 bbls. Ball on seat at 46.1 bbls. Pressure up to 4200 psi. Good indication of release at expected pressure. PU 2' to confirm free from liner. PU weight 31 klbs. 11 :45 - 14:30 2.75 CASE P COMP Swap to 2% KCL. Chase mud OOH. 14:30 - 14:50 0.33 CASE P COMP Safety meeting prior to cementing. Attended by rig crew, rig SWS Crrs, cementers, Peak vac truck driver. 14:50 - 15:15 0.42 CASE P COMP Circulate KCI while waiting on cementers to get up to weight. 90% returns. 15:15 - 16:30 1.25 CASE P COMP Cement is up to weight, flood lines and PT to 3500 psi. Begin pumping cement as per proceedure. 15.8 ppg, Class G. Additives D-600 @ 2 gps, D-135 @ 0.15 gps, KCL 0.3% BWOC, D-47 @ 0.2 gps, D-65 @ 0.45%, D-800 @ 0.2 % BWOC. Pump cement into coil at 2 bpm, out rate 1.65 bpm. Pump 30.5 bbls. SD, drop dart. Launch at 500 psi. Check and confirm dart is away. Continue pumping, chasing dart with 50 bbls of 2# biozan/2% KCL water. Pumping at 3.2 in/2.8 out. Dropped rate to 1.3 bpm with 45 bbls away, and out rate went to 1.1 bpm. Returns improved with cement behind pipe, 1.3/1.2. Lost 2.5 bbls of cement while displacing. An extra 3.5 bbls was pumped at start of job. Cement should be at top of liner. 16:30 - 18:00 1.50 CASE P COMP POOH at 80 fpm, chasing cement out of hole. Pumping 3.3 bpm. Getting 100% returns while POOH. Got good cement shows in returns while POOH at expected bottoms up from top of liner. 18:00 - 18:45 0.75 CASE P COMP Tag up at surface. Stand back injector. Lay down Baker CTLRT. All recovered as expected. 18:45 - 19:00 0.25 CASE P COMP Safety mtg re: source/CSH 19:00 -19:30 0.50 EVAL P COMP Load CNL tools to floor. MU 2.30" mill, 2-1/8" motor, SWS CNL flow thru carrier 19:30 - 21:15 1.75 EVAL P CaMP PU 8 CSH singles and 33 CSH doubles Printed: 11/1212002 10:38:32AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 11/6/2002 21:15 - 22:40 1.42 EVAL P COMP RIH w/ BHA #14 22:40 - 00:00 1.33 EVAL P COMP Log down at 30'/min from 9000' 11/7/2002 00:00 - 00: 15 0.25 EVAL P COMP Tag PBD at 11558' CT, solid. Did not attempt to drill. Fin circ mud to mill 00:15.01 :00 0.75 EVAL P COMP Log up from PBD at 60'/min leaving hi LSRV mud in liner 01 :00 - 02:05 1.08 EVAL P COMP POOH 02:05 - 02:20 0.25 EVAL P COMP Safety mtg re: CSH 02:20 - 03:30 1.17 EVAL P COMP Standback CSH 03:30 - 03:40 0.17 EVAL P COMP Safety mtg re: source 03:40 - 04:00 0.33 EVAL P COMP LD CNL tools, motor and mill 04:00 - 05:20 1.33 EVAL P COMP RU to PT wellbore. Comp str of cement=1600 psi. WO cement while download data. Load perf guns in pipeshed 05:20 - 06:00 0.67 EVAL P COMP Cement at 2000 psi. PT we II bore to 2000 psi and hold for 30 min. Lost 100 psi. No change to IA or OA 06:00 - 06:30 0.50 PERF P COMP Crew change. Safety mtg re: perf guns 06:30 - 07:00 0.50 PERF P COMP PU Perf Guns 07:00 - 07:15 0.25 PERF P COMP Review BHA prior to picking up CSH. 07:15 - 08:40 1.42 PERF P COMP PU CS hydrill work string. 08:40 - 09:00 0.33 PERF P COMP Make up SWS MHA, PU injector. 09:00 - 09:30 0.50 PERF N SFAL COMP RIH with perf guns. BHA length = 2529'. Weight cell looks like we are snubbing, POH to check. 09:30 - 10:15 0.75 PERF N SFAL CaMP Got weight back just before tag up. Check weight cell. Bleed down a little. Works fine now. 10: 15 - 11 :45 1.50 PERF P COMP RIH again with perforating BHA. Weight and circ pressure are fine. 11:45-12:15 0.50 PERF P COMP Tag bottom make -14' correction to ELM PBTD of 11546' from MCNL log. PU to shot depth for first gun, 11470.7'. Connect annular pressure monitor from DHD group. Review with SWS, Nordic driller, DHD hand proceedure for firing guns. Bring pressure up as required by SWS TCP hand. Can only achieve 1000 psi. Unable to pressure up wellbore more than that. Well taking fluid at 3 bpm, 1000 psi. IAP=O, OAP=60 psi and steady. The liner lap is possibly leaking? May have broken down after PT last night? No stopping HDF firing head to investigate as minimum pressure for firing sequence has been achieved. Wait 6 minutes. Got good indication of fire of guns. Perforated 11330'-11470'. 12:15 -13:15 1.00 PERF P COMP Pull into depth for 2nd gun. Position over interval 10870'.10930'. Pump 19 bbls offlopro mud, drop 5/8" ball. Chase with KCL. Coil vol=57.6 bbls. Ball landed at 56 bbls away. Pressured up to 3000 psi over, got good indication of guns firing. 13:15 -13:45 0.50 PERF P COMP POOH circulating accross the top to preserve flopro mud perf pill in liner. 13:45 - 15:15 1.50 PERF P COMP Getting some gas bubbles back in returns. Stop with SWS ported firing head at 9000'. Circulate to ensure that wellbore is clean prior to POOH. Pump at 2.2 bpm, 3300 psi. Getting 1 for 1 returns with some gas bubbles and crude stains. 15:15 - 16:10 0.92 PERF P COMP 210 bbls away, Returns are clean, POOH. 16:10 -16:20 0.17 PERF P COMP Tag up at surface, perform no flow test. Still getting burps of gas and crude. Need to get returns clean prior to laying out CS hydril work string. Call for 300 bbls of 2% KCL. Plan to bullhead from surface prior to rigging off injector. Printed: 11/1212002 10:38:32 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/3/2002 Rig Release: 11/8/2002 Rig Number: N1 Spud Date: 8/25/1982 End: 1117/2002 16:20 - 18:30 2.17 PERF N WAIT COMP Waiting on 300 bbls of 2% KCL to kill well. 18:30 - 18:50 0.33 PERF N DFAL COMP Safety mtg re: well kill 18:50 - 21 :00 2.17 PERF N DFAL COMP Start pumping 0.5 bpm down CT and get rate to 2.0 bpm down BS w/530 psi WHP. IA at 700 psi. Assume that a DGLV is leaking and burped some crude and gas into tubing since IA has been 0 psi thruout well and must be a two way leak. Small drip of crude from flange downstream of IA valve. OA 100 psi. Safety mtg re: IA bleed down Bleed IA to flowback tank while pump min rate down BS and CT 21 :00 - 23:30 2.50 PERF N DFAL COMP IA at 500 psi and bleeding down slowly w/ crude/diesel returns probably due to positive WHP due to min rates. WO dirty truck to arrive to suck flowback tank and additional KCL water 23:30 - 00:00 0.50 PERF N DFAL COMP Dirty vac on location. SD pumping and bleeding w/ 300 psi WHP, 500 psi lA, 126 psi OA. Monitor pressures for 10 min and had 180 psi WHP, 370 lAP, 125 OA. Resume pumping min rates and WHP at 400, lAP 600 so 200 psi differential. SI IA valve Begin liquid pack w/2% KCI at 4 bpm down BS w/ pump #1 and 1.0 bpm dn CT w/ pump #2 at 700 psi WHP stable 11/8/2002 00:00 - 01 :00 1.00 PERF N DFAL COMP Continue liquid pack w/2% KCI at avg 5.2 bpm w/ 835 psi max WHP. SD after pumping a total of 330 bbls and monitor WHP bleed to zero. With WHP at 130 psi, open IA to 360 psi. OA 360 psi 01 :00 - 01 :30 0.50 PERF P COMP Monitor well for stability, IA 115, OA 320 Safety mtg re: well control/LDDP 01 :30 - 01 :50 0.33 PERF P COMP Set back injector. RU to LD CSH 01 :50 - 03:10 1.33 PERF P COMP POOH LDDP 03:10 - 03:30 0.33 PERF P COMP Safety mtg re: well control/perf guns IA 105, OA 225 03:30 - 04:30 1.00 PERF P COMP POOH LD perf guns-all shots fired. Load out perf guns 04:30 - 05:30 1.00 EVAL P COMP RU nozzle assy and observe hole full, but frothing good. Bullhead 32 bbls MeOH down tubing for freeze protection. MIRU DS N2 pumper 05:30 - 05:45 0.25 DEMOB P POST SI swab, master, lA, OA. Final WHP 130, IA 260, OA 160 and all are bleeding off. Cool down DS N2. Safety mtg re: N2 05:45 - 07:00 1.25 DEMOB POST Blow down coil with N2 and bleed off. 07:00 - 08:45 1.75 DEMOB P POST Cut coil connector, unstab pipe, rig down goose neck, stab injector in stabbing box, prepare for derrick down move. 08:45 - 10:20 1.58 DEMOB P POST Nipple down stack, prepare for move. Rig released at 0930 hrs 11/8/02 10:20 - 10:40 0.33 DEMOB P POST Safety meeting prior to moving rig. 10:40 - 11 :40 1.00 DEMOB P POST Move ahead 2', nipple up tree cap, PT same. 11 :40 - 12:00 0.33 MOB P PRE Move rig 15' ahead to lay down wind walls for move to J-27a. (Continued on J-27a Telex). Printed: 11/12/2002 10:38:32AM Well: Field: API: Permit: ) ) 01-19A Prudhoe Bay Unit 50-029-20800-01 202-022 Rig Accept: 10/31/02 Rig Spud: 11/02/02 Rig Release: 11/08/02 Drilling Rig: Nordic #1 POST RIG WORK 11/12/02 RUN GENERICS. SET 5-1/2" SS CATCHER @5041' WLMD. PULL DGLV FROM GLM #2. 11/13/02 PULLED DGLV'S FROM GLM'S 1 & 2. SET GENERIC G/L DESIGN. PULL CATCHER. RETURNED WELL TO DSO. WELL TO REMAIN SHUT IN. ) ) ~Od- D;l~ 20-Nov-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 01-19A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,800.00' MD Window / Kickoff Survey 9,830.00' MD (if applicable) Projected Survey: 11,584.00' MD Please call me at 273-3545 if you have any questions or concerns; Regards, William T. Allen Survey Manager RECE\\lEO DEC 062002. (j( & Gas eons. Commission A\as\œ t Anchorage Attachment( s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 01 01-19A .~ Job No. AKMW22177, Surveyed: 6 November, 2002 Survey Report 19 November, 2002 Your Ref: API 500292080001 Surface Coordinates: 5940734.19 N, 697777.47 E (70014' 31.9871" N, 148024' 09.2250" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 940734.19 N, 197777.47 E (Grid) Surface Coordinates relative to Structure Reference: 1210.54 S, 505.80 E (True) Kelly Bushing: 70.00ft above Mean Sea Level Elevation relative to Project V Reference: 70.00ft Elevation relative to Structure Reference: 70.00ft spe""'r'Y-5Ur'! i:)RILLING ,gtEAVfEËs A Halliburton Company Survey Ref: svy11368 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01- 01-19A Your Ref: API 500292080001 Job No. AKMW22177, Surveyed: 6 November, 2002 BPXA North Slope Alaska Measured 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) (°/1 OOft) 9800.00 31.000 326.000 8583.21 8653.21 2740.39 N 2484.88 W 5943408.44 N 695221.54 E 3330.51 Tie On Point - 9830.00 31.000 325.700 8608.93 8678.93 - 2753.18 N 2493.56 W 5943420.99 N 695212.54 E 0.515 3343.34 Window Point 9870.05 34.800 322.390 8642.55 8712.55 2770.76 N 2506.35 W 5943438.23 N 695199.29 E 10.493 3361.79 9912.92 34.360 318.860 8677.85 8747.85 2789.56 N 2521.77 W 5943456.63 N 695183.37 E 4.784 3383.14 9948.85 28.370 315.920 8708.52 8778.52 2803.34 N 2534.40 W 5943470.07 N 695170.40 E 17.202 3400.00 ~ 9997.25 31.670 312.030 8750.43 8820.43 2820.12 N 2551.84 W 5943486.38 N 695152.52 E 7.912 3422.46 10030.15 35.590 306.880 8777.82 8847.82 2831.65 N 2565.92 W 5943497.54 N 695138.14 E 14.726 3439.84 10060.83 39.120 306.710 8802.20 8872.20 2842.80 N 2580.83 W 5943508.30 N 695122.95 E 11.511 3457.83 10087.58 43.000 304.420 8822.37 8892.37 2853.00 N 2595.12 W 5943518.12 N 695108.39 E 15.555 3474.91 10120.08 48.280 303.710 8845.08 8915.08 2866.01 N 2614.37 W 5943530.62 N 695088.81 E 16.321 3497.62 10154.95 53.740 307.410 8867.02 8937.02 2881.79 N 2636.38 W 5943545.81 N 695066.39 E 17.693 3523.95 10187.03 53.130 314.280 8886.15 8956.15 2898.62 N 2655.86 W 5943562.13 N 695046.48 E 17.301 3548.31 10228.53 57.800 313.400 8909.67 8979.67 2922.28 N 2680.51 W 5943585.14 N 695021.21 E 11 .388 3580.03 10256.00 63.170 313.580 8923.20 8993.20 2938.73 N 2697.85 W 5943601.13 N 695003.45 E 19.557 3602.27 10288.30 67.930 318.160 8936.57 9006.57 2959.84 N 2718.29 W 5943621.69 N 694982.46 E 19.586 3629.13 10316.80 67.750 323.100 8947.32 9017.32 2980.23 N 2735.03 W 5943641.64 N 694965.19 E 16.065 3652.29 10349.05 68.550 318.340 8959.33 9029.33 3003.39 N 2753.98 W 5943664.29 N 694945.64 E 13.921 3678.53 10385.53 75.240 318.510 8970.66 9040.66 3029.32 N 2776.97 W 5943689.61 N 694921.97 E 18.344 3709.57 10417.38 80.790 318.690 8977.27 9047.27 3052.68 N 2797.57 W 5943712.42 N 694900.77 E 17.434 3737.41 10446.92 86.610 321.330 8980.51 9050.51 3075.17 N 2816.42 W 5943734.40 N 694881.33 E 21.610 3763.32 10483.72 93.920 320.980 8980.34 9050.34 3103.81 N 2839.49 W 5943762.43 N 694857.52 E 19.887 3795.43 10515.60 93.830 320.450 8978.19 9048.19 3128.43 N 2859.63 W 5943786.51 N 694836.75 E 1.683 3823.33 10568.48 94.710 324.510 8974.25 9044.25 3170.24 N 2891.74 W 5943827.47 N 694803.55 E 7.835 3868.77 '"-' 10616.38 94.540 330.140 8970.38 9040.38 3210.41 N 2917.50 W 5943866.95 N 694776.74 E 11.721 3907.70 10682.63 90.460 325.500 8967.49 9037.49 3266.40 N 2952.74 W 5943922.00 N 694740.05 E 9.320 3961.35 10714.50 91.280 322.570 8967.01 9037.01 3292.19 N 2971.45 W 5943947.29 N 694720.66 E 9.546 3988.36 10745.48 90.660 318.160 8966.48 9036.48 3316.04N 2991.21 W 5943970.61 N 694700.29 E 14.373 4015.61 10790.96 90.840 315.520 8965.89 9035.89 3349.21 N 3022.31 W 5944002.95 N 694668.33 E 5.818 4056.87 10825.83 92.600 313.580 8964.84 9034.84 3373.66 N 3047.15 W 5944026.74 N 694642.86 E 7.510 4089.06 10858.78 91.720 310.060 8963.60 9033.60 3395.61 N 3071.68 W 5944048.04 N 694617.75 E 11 .004 4120.03 10883.85 93.130 307.760 8962.54 9032.54 3411 .34 N 3091 .17 W 5944063.25 N 694597.86 E 10.754 4143.99 10923.63 87.470 306.620 8962.33 9032.33 3435.38 N 3122.85 W 5944086.45 N 694565.56 E 14.514 4182.37 10953.95 86.870 303.010 8963.83 9033.83 3452.66 N 3147.70 W 5944103.08 N 694540.26 E 12.055 4211.89 10978.42 87.400 299.480 8965.05 9035.05 3465.34 N 3168.60 W 5944115.20 N 694519.04 E 14.570 4236.01 11006.70 92.070 297.720 8965.18 9035.18 3478.87 N 3193.42 W 5944128.08 N 694493.88 E 17.647 4264.09 19 November, 2002 - 14:46 Page2of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01. 01.19A Your Ref: API 500292080001 Job No. AKMW22177, Surveyed: 6 November, 2002 BPXA North Slope Alaska Measured 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) (o/100ft) 11036.50 96.830 296.660 8962.87 9032.87 3492.44 N 3219.84 W 5944140.95 N 694467.11 E 16.362 4293.67 11068.00 97.620 294.730 8958.91 9028.91 3505.99 N 3247.99 W 5944153.76 N 694438.61 E 6.575 4324.86 11107.83 91.720 292.960 8955.67 9025.67 3522.03 N 3284.29 W 5944168.84 N 694401.91 E 15.460 4364.51 11135.85 93.040 289.970 8954.50 9024.50 3532.27 N 3310.34 W 5944178.39 N 694375.60 E 11 .656 4392.50 11168.35 95.330 285.210 8952.13 9022.13 3542.07 N 3341.22 W 5944187.37 N 694344.46 E 16.217 4424.81 ~" 11200.58 91.980 282.920 8950.08 9020.08 3549.88 N 3372.42 W 5944194.37 N 694313.08 E 12.582 4456.66 11240.55 85.990 285.910 8950.78 9020.78 3559.82 N 3411.10W 5944203.29 N 694274.14 E 16.747 4496.25 11273.85 85.730 279.750 8953.19 9023.19 3567.20 N 3443.47 W 5944209.81 N 694241.59 E 18.467 4529.02 11303.25 84.140 276.750 8955.79 9025.79 3571.40 N 3472.45 W 5944213.25 N 694212.52 E 11.513 4557.47 11341 .53 84.320 270.060 8959.64 9029.64 3573.66 N 3510.44 W 5944214.51 N 694174.47 E 17.394 4593.54 11378.10 90.570 270.410 8961.27 9031.27 3573.81 N 3546.96 W 5944213.71 N 694137.97 E 17.117 4627.46 11412.48 90.400 263.710 8960.98 9030.98 3572.05 N 3581.27 W 5944211.04 N 694103.71 E 19.494 4658.61 11443.38 92.160 257.720 8960.29 9030.29 3567.06 N 3611.75 W 5944205.27 N 694073.38 E 20.199 4685.00 11473.20 94.890 254.370 8958.45 9028.45 3559.89 N 3640.62 W 5944197.34 N 694044.70 E 14.475 4709.09 11508.75 101.150 247.320 8953.49 9023.49 3548.37 N 3673.84 W 5944184.95 N 694011.79 E 26.368 4735.57 11540.85 100.090 245.030 8947.57 9017.57 3535.62 N 3702.70 W 5944171.45 N 693983.28 E 7.750 4757.55 11584.00 100.090 245.030 8940.01 9010.01 3517.69 N 3741.21 W 5944152.51 N 693945.25 E 0.000 4786.54 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 292.000° (True). ~ Magnetic Declination at Surface is 26.178°(01-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 11584.00ft., The Bottom Hole Displacement is 5135.25ft., in the Direction of 313.236° (True). 19 November, 2002.14:47 Page 3 of 4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01. 01-19A Your Ref: API 500292080001 Job No. AKMW22177, Surveyed: 6 November, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9800.00 9830.00 11584.00 8653.21 8678.93 9010.01 2740.39 N 2753.18 N 3517.69 N 2484.88 W 2493.56 W 3741.21 W Tie On Point Window Point Projected Survey .~. Survey tool program for 01-19A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 11584.00 9010.01 MWD Magnetic(01-19A) ~ 19 November, 2002.14:47 Page 4 of 4 DrillQuest 3.03.02.004 ) ) To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: October 10,2002 Re: CTD Sidetrack of well 01-19a; Drilling permit 202-022 Operations were shut down on March 8th, 2002. Nordic 2 is scheduled to return to the well and resume operations. The down hole target location is unchanged. The previous two sidetrack attempts will be cemented, following are the plan forward steps. 1. Run casing caliper over whipstock interval. 2. E-line perforate at whipstock set depth. 3. E-line set a mechanical whipstock at approx. 9,830'. 4. Use se')i e oil to cement squeeze the perfs at the whipstock and the old window attempts with appro ( 10 Is cement. 5. Wind - -III be milled to 3.8" with drilling coil. Setting the whipstock and pumping cement will commence on approx. Oct 18, 2002. Drilling coil is scheduled to drill the sidetrack on Oct 30, 2002. 1JJ~~ M.S. Endacott CTD Drilling Engineer 564-4388, 440-0186 CC: Well File Terrie Hubble ., ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL \Li ,A- tQ ( It { O-L. Jk 4t1{~ rO/I'/o 1.. I"^ t- b 1. Type of Request: 0 Abandon 0 Alter Casing III Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 0 Suspend 0 Plugging 0 Time Extension 0 Perforate 0 Repair Well 0 Pull Tubing 0 Variance III Other 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Resume Operations 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) RKB = 70' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 165' SNL, 462' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 2555' NSL, 2000' WEL, SEC. 06, T10N, R15E, UM At effective depth 2638' NSL, 2056' WEL, SEC. 06, T10N, R15E, UM At total depth 3186' NSL, 3028' WEL, SEC. 06, T10N, R15E, UM (Planned) 12. Present well condition summary Total depth: measured true vertical 8. Well Number 01-19A 9. Permit Number 202-022 10. API Number 50- 029-20800-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Effective depth: measured true vertical 9950 feet 8782 feet 9950 feet 8782 feet Plugs (measured) Set Baker Whipstock at 10080' (02/02) (fOWat 10089'); Set 2nd Baker Whipstock at 9950' (02/02) (fOW at 9950') Junk (measured) Window milling assemblies stuck and left in the hole for both windows. Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 1950# Poleset 80' 80' 2202 sx Fondu, 400 sx PF IC' 2590' 2590' 500 sx Class 'G', 300 sx PF 'C' 9610' 8490' 385 sx Class 'G' 9305' - 9950' 8223' - 8782' 80' 20" 2590' 13-3/8" 9610' 9-5/8" 645' 7" Perforation depth: measured None true vertical None RECEIVED OCT 1 0 2002 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9242'; 4-1/2", 12.6#, L-80 to 9340' Alaska OU& Gas Gons. Commission Packers and SSSV (type and measured depth) BOT packer at 9231'; 5-1/2" Otis 'ROM' SSSV Nipple at 2168' Anchorage 13. Attachments 181 Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended 181 BOP Sketch 14. Estimated date for commencing operation October 18, 2002 16. If proposal was verbally approved Service Name of approver Date Approved Contact Engineer NameINumber. Mary Endacott, 564-4388 17. I hereby certify that the foregoing is true and correct 0 the best of my knowledge Signed Mary En;:J!tJJ:;i'~';)'i{"ii?iff{ßW¡'¡~;~'Z(";'i;c!¥'}i{JA% " ....~at~ .. ~~j¡ol() 2 ~. Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Subsequent form required 10- t../ 0 7 r Ct.' 9 Onglnal Signed By r¡ :~m~y (Rd1tli T~kx Commissioner r, !,\ i [\: ~ \1 ~ \1: ['~-'\ L- Prepared By Name/Number: Sandra Stewman, 564-4750 I Approval No. :5 {'IÄ .- .3 J-. J Mechanical~ntegrity Tpst- 'T.esr p.:JfE f4 'S5PO Approved by order of the Commission Form 10-403 Rev. 06/15/88 Date 10 I~ C'd- Submit In T~iplicate , TREE ='¡ FMC WELLHEAD= FMC ACTUATOR;w'."'ÃXElS'OÑ'.. . KEr'EL§T;-ww,w ",. ..........,... '-'70 ....~..w,^,.................,,,w",,,,,,w,,.w...=w.......................--..,,.........=.,.,......,.........N''''' .... BF. ELEV = ? 'KOF>; ...,.. .. ... w3ÖÒÖ w§,~:~:~~!~~'~:.~':.~~"~"~8~~. Datum MD = 10053 'OatlJ'ìñ'iVõ;^-'.m"'^'^'8àõõ's'§ 13-3/8"CSG, 72#, L-80, ID=12.347 1---1 2590' ~ Minimum ID = 3.80n @ 9328 4 1/2" Otis XN Landing nipple 15-1/2" TBG-PC, 17#, L80, 8rd AßM, - 9242' 0.0232bpf, ID=4.892 I TOP OF 4-1/2" TBG - 9242' I TOP OF 7" LNR, B,OT HNGR 1---1 9305' 4-1/2" TBG-PC?, 12.6#, L80, STC, 0.0152bpf, ID=3.958 1--1 9340' 9-5/8" CSG, 47#, L-80,ID=8.6811---1 9610' ~ ÆRFORA TION SUMMARY REF LOG: BHCS on 9/7/1982 ANGLEATTOPÆRF: 31 @ 9755 Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8 6 10154-10184 S 1/5/1989 3-3/8 4 10178-10183 S 9/14/1995 3-3/8 3 10194-10204 S 8/13/1989 3-3/8 3 10204-10216 S 8/13/1989 NA 2 10214-10218 S 10/1/1993 17" LNR, 29#, L-80, STC, 0.0371 bpf, ID=6.184 1---1 10500' I ~-i 10505' I DATE 09/11/82 09/11/82 11/09/00 02/08/01 02/15/01 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER CONVERTED TO CANVAS FINAL CORRECTIONS DA TE REV BY COMMENTS 02/21/02 CWS/KK SET WHIPSTOCK/CEMENT 03/11/02 DACltlh FISH IN WNDW (CTD SUPS.) 10/08/02 MSE DRLG DETAIL, D8.ETE IAXDA PRUDHOE BAY UNIT WELL: 01-19 PERMIT No: 82-125 API No: 50-029-20800-00 SEC 6 T10N R15E 2233.27 FEL 2387.66 FNL BP Exploration (Alaska) SIS-LG SIS-MD TP ') SAFETY NOTES: CTD SUSPENDED SIDETRACK OF WB.L 03/11102 DUE TO FISH IN WINDOW 01-19 2168' 1--1 5-1/2" OTIS RQM SSSV NIPPLE, ID= 4.562 I 8 GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 1 2915 2913 9 DMY T-2 10/21/01 ~ 2 4948 4750 36 DMY RA 10/21/01 3 6561 6000 40 DMY T-2 10/21/01 4 7729 6904 38 DMY RA 10/21/01 5 8352 7407 35 DMY RA 10/21/01 L 6 8429 7471 34 DMY RA 10/21/01 7 8778 7764 31 DMY RA 10/21/01 8 8854 7830 30 DMY RA 10/21/01 9 9116 8057 29 DMY T-2 10/21/01 10 9188 8120 28 DMY RA 10/21/01 0 0 0 c, 9210' l-i 5-1/2" BROWN PBR ASSY I '" :g ~ 9231' l-f 9-5/8" X 5-1/2" SROWN PA CKER I \ ! 9242' 1---1 XO 5-1/2" X 4-1/2" 1 ., II'" J l 9328' 11 4-1/2" OTIS XN LANDING NIP, mHled to 10=3.80" 3/4/02 9340' 1---1 4-1/2" TUBING TAIL I 9338' l-i ELMO- IT-LOGGED 1/20/88 I .. 9706' 1---1 ELMD tv1A RKER ?" pup JTS I ~.., <:.,L:~;~ 9872' 1---1 FISH, WINDOW MILLING ASSY, 81.9' OAL 1 I 9950' 1---1 TOP OF WHIPSTOCK #2 I I 10024' 1---1 FISH, WINDOW MILUNG ASSY I 10080' - TOP OF WHIPSTOCK #1 I 10107' - ~ ) ) 01-19A Proposed CTD ST L TREE=\ FMC WELLHEAD= FMC 'ACTUÃTÕR;"."''''Ã5("ELšoi\JW Kè: 'ELí3i..;w..m......wmw.mwwyÓ V"''''''''''''W''''W'''''W'''''',.....,.w.''W~.W'''''.....w........-"''''''''.w.'.WN.WN.V.="'W'."W.'.W"'''w... BF. ELEV = ? . KOÞ';'.'W' .. .. 3000 'w~~w~.'~~.ì~'.~:'w"w,w"",^,-"-,^,w",w,,. Datum MD = 10053 ",[5arû'm"'T\7B;"w",--"w'''''''''''~'''''ä8Õ'ÕN'SŠ 13-3/8"CSG, 72#, L-80, ID=12.347 1--1 2590' Minimum 10 = 15-1/2" TBG-PC, 17#, L80, 8rd ABM, - 0.0232bpf,ID=4.892 TOPOF 4-1/2" TBG-PC - TOPOF 7" LNR, B.OT HNGR 1--1 (f) r-4 L 0 c c 1'1, ". ~ I ~ :8: 9242' 9242' 9305' \ TOPOF 3-1/2" liner 1--1 9300' I Proposed Liner Celoont Top 1--19300' 4-1/2" TBG-PC?, 12.6#, L80, BTC, 0.0152bpf, ID=3.958 1--1 9340' 9-5/8" CSG, 47#, L-80, ID=8.681 1--1 9610' 1- ~ I TOP OF WHIPSTOCK #3 ÆRFORA TION SUMMARY REF LOG: BHCS on 9/7/1982 ANGLEATTOPÆRF: 31 @ 9755 Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8 6 10154-10184 S 6/27/1997 3-3/8 4 10194-10218 S 6/27/1997 3-3/8? 10232-10238 S 4/26/1990 3-3/8? 10238-10254 S 2í24í2002 ~ '..- , ~~ \ \ \ ,-.7(::'(' I---J \ \ :1.' ,,'Il I H 9830' I--""""\J.}. /" I %'11) I ~~./" ....... . .,6'..'-..". 1 . . . ,'.," ---1PßTNTD .~~~:..~;:.:-..., . '- -~- '~ ::'~ ~_~~r ~ .:::~. ':".. . ~-=---~U1[=::-==-=1 . <:~;-:. ..:\:.. 12-7/8" L-80 Liner, Cmtd & Perforated 1-111213'1 - --- -- - - - - - '-'. ~~; .:- 1 II . .. ... lrAJj m IX y~ 7" LNR, 29#, L-80, .0371 bpf, 10=6.184 l--t 10500' I ~--t 10505' 1 DATE 09/11/82 09/11/82 11/09/00 02/08/01 02/15/01 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER CONVERTED TO CANVAS FINAL CORRECTIONS SIS-LG SIS-MD TP DATE 02/21/02 03/11/02 10/08/02 10/10/02 SAFETY NOTES: CTD SUSPENDED S!DETRACKOFWELL 03/11/02 DUE TO FISH IN W!NDOW ~ 2168' 1--1 5-1/2" OTIS RQM SSSV NIPPLE, ID= 4.562 I GAS LIFT MANDRELS STA MD TVD DEV 1YÆMAN 1 2915 2913 9 RL5524 2 4948 4750 36 RL5524 3 6561 6000 40 RL5524 4 7729 6904 38 RL5524 5 8352 7407 35 RL5524 6 8429 7471 34 RL5524 7 8778 7764 31 RL5524 8 8854 7830 30 RL5524 9 9116 8057 29 RL5524 10 9188 8120 28 RL5524 LA TCH T-2 RA T-2 RA RA RA RA RA T-2 RA ~ I 9210' l-i 5-1/2" BRO\NN PBRASSY 1 1 9231' l--t 9-5/8" X 5-1/2" BROWN PACKER I 9242' 1--1 XO 5-112" X 4-1/2" I 9310' 1--1 3 1/2" XN 2.75" No Go I 9328' - 4-1/2" OTIS XN LANDING NIP, I milled to ID:<:\.80" 3/4/02 9340' - 4-112" TUBING TAIL 1 9338' 1--1 ELMO- IT-LOGGED 1/20/88 I . ."' ,. .' I . ",.' . . ,:.:: 1 9872' I 1- FISH, WINDOW MILLING ASSY, 81.9' OAL 1 --1 1 l--t 1-1 REV BY COMMENTS CWS/KK SET WHIPSTOCKIC8v1ENT DACltlh FISH IN WNDW (CTD SUPS.) MSE DRLG DETAIL, DELETE IAXDA MSE PROPOSED COIL SIDETRACK PRUDHOE BAY UNrr WELL: 01-19A ÆRMrr No: 202-022 API No: 50-029-20800-01 SEC6 T10N R15E2233.27 FEL 2387.66 FNL BP Exploration (Alaska) ) NORDrt 2. BOP-Tree KB Elevation I~:II..I.,.,.".,..,. ............. ..~ ............... ........ '..ï~i~..~I~~r.,.,.. ,'...'. .........'..,.: .:[r,rr.:.D ...........'...~u:E~,:'~~'~:~o with 60 Otis Un~ns r3W 5000 psi :::::,: rr¡:::NÚ~~~i~~tt4..:.' 17 1/16" 5000 psi BOP's. 10 = 7.06" I . . . . . . ... ...... . I I ""'.'.".","':.1:::::::,::::::;::::::;::::1...~" 171/16" 5000 psi, RX-46 I t.....:...:...': ..-.'..'..':'..."'.'J mm ~ it ~ '~',,:,::,:::,:::,1"--<4. -. .... ....~..... j ., ......... .... ~ ,.., .:.~~~.UJI!rn ,.,...... J:::::::::::::~:::::::::::::::~::J.. I - Tree Size I SSV ~ I Master Valve I I .",,'q.,.m"--:""Y'.u,.,.,m.u; I Base FlanQe I I ,,"'" ",,", I Page 1 í'\ LJ 0 04 000 LJ - N I ~0 9~ f f~J ,b ~. Q) ::Ji ,- H3 û- ~ c ~ " .---.J...ci ~Ci O~ ) ç: (-1 0 ('r,t~ ;¡ (1) \ \..{ .~ I~ ~n I..J v> ~ ~ tiC \, BP Amoco WELLPATH DETAILS P18n#S 01-18A 500282080001 ......t Wellpath: Tie on MD: Rig. R.f. Datum: 01.1. 9830.00 31 .188/24/198200:00 v.s~:.: O.11J!: 282.00' ~~= 0-00 ::::Tto REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: 01-19, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot - 19 (O.DON,O.OOE) Measured Depth Reference: 31 : 198/24/198200:00 70.00 Calculation Method: Minimum Curvature +EI-W DLe. TF8ce vSec Target 1 9800.00 31.00 328.00 8583.21 2740.40 -2484.87 0.00 0.00 3330.50 2 Ø830.oo 31.00 325.70 8808.83 2753.18 .2493.55 0.52 269.87 3343.34 3 9848.00 32.74 324.84 8824.22 2780.99 .2498.96 10.00 -15.00 3H1.28 4 9898.00 38.08 316.00 8885.49 2782.88 .2518.99 12.00 -60.00 3378.12 5 9958.00 27.92 318.00 8723.11 2808.55 -2542.00 12.00 180.00 3409.00 ; ~g:~~~ ::: ~:::~ ::~:g: ~;;~:g~ :~~::~~ ~~gg .a::~ :nw 8 11043.37 85.1. 288.85 8962.89 3278.08 -3352.84 12.00 78.00 4338.88 9 11153.37100.81 289.01 8941.73 3320.35 .3452.99 12.00 85.00 4445.38 1011213.00 100.81 306.29 8938.73 3351.94 ~3502.30 12.00 89.33 4502.93 TVD MD Annotation 8583.21 8800.00 TIP 8808.93 9830.00 KOP 8824.22 8848.00 1 8885.49 9888.00 2 8723.11 9981.00 3 8977-04 10483.37 4 8972-08 10883.37 5 8882.88 11043.37 8 8947.73 11153.37 7 8938.73 11213.00 TO +E1.W Shape ~m~ff:r.1 i~~~ I~i:ä iÞ:!.ti ~rn 8400 8450 8500 _8550 C æ 8600 0 1!!.8650 t 8700 . ell 8750 '3 8800 i 8850 > . 8900 2 I- 8950 - 9000 9050 9100 9150 bp ... .... INTEl) LEGEND - 01-19 (01-19) - 0S-06 (0S-06) - 0S-06A (0S-06A) - 0S-08 (0S-08) 05-41 (05-41) - Plan#501-19A - Plan #5 T ^M ¿ Azimuths to True North Plan: Plan #5 (01-19/Plan#5 01-19A) Magnetic North: 26.52° Created By: Brij Potnls Date: 3/14/2002 Magnetic Field Contact Information: Strength: 57515nT D~a¿;g~7~ 2/~88; g~~;1¡: (g~r¿;t~¡~~I~ÇCqCOm Model: BGGM2001 Baker Hughes INTEQ: (907) 267.6600 4400 _3900 C æ 3800 0 0 3700 - ... - - ~3600 ;~-- -m. .c =+~u 1:: 3500 0 ~ 3400 ' - . :ë 3300 - .. - :I - 0 3200 en 3100 .-=r=_Lt- I ~ 2900 i-_L~#- 2 2800 , ,-j- .., -$ '.; ¡ ..---J~-:---=-._~==::= -=JDop -. " ,....,. . ., . . , . . . , I.. ., '. .' I '.'. I TIP 2700 ~lnITfn:j1T,1-FH,n1TI,! I II IFl~ 1-" IllTnT~IIII'1 -=fhn~" I Tirl, ~1~rr:-;-~1,1 I I~' II ;rl""'-r1;nTT~Tr~1TTrlì~n~ -4300 -4200 -41 00 -4000 -3900 -3800 -3700 -3600 -3500 -3400 -3300 -3200-31 00 -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100 -2000 -1900 -1800 -1700 West(-)/East( +) [100ftlin] I I I 3000-::'. I '.. . I InrrllT11 ¡¡Ir 4000 4050 4100 4150 4200 Vertical Section at 292.00° [50ft/in] 3/111/2002 11 :00 PM ') ) BP Baker Hughes INTEQ Planning Report BP Amoco Prudhoe Bay PB OS 01 01-19 Plan#5 01-19A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Company: Field: Site: Well : Wellpath: Field: PB OS 01 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 01-19 01-19 Well Position: Well: R .1~l.EQ Date: 3/14/2002 Time: 16:00:39 Co-ordinate(NE) Reference: Well: 01-19, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,292.00Azi) Survey Calculation Method: Minimum Curvature Db: Page: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 5941932.14 ft 697237.60 ft Latitude: Longitude: North Reference: Grid Convergence: 70 14 43.905 N 148 24 24.004 W True 1.50 deg Slot Name: 19 +N/-S -1211.74 ft Northing: 5940734.19 ft +E/-W 508.35 ft Easting: 697777.46 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 14 31.987 N 148 24 9.225 W Wellpath: Plan#501-19A 500292080001 Current Datum: 31 : 198/24/198200:00 Magnetic Data: 3/14/2002 Field Strength: 57515 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description Dip. Dir. 01-19A Polygon3.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 T\'D ft 0.00 0.00 0.00 0.00 0.00 01-19A T3.3 01-19A T3.2 8947.00 8965.00 01-19A T3.1 8977.00 Annotation MD TVD ft ft 9800.00 8583.21 TIP 9830.00 8608.93 KOP 9848.00 8624.22 1 9898.00 8665.49 2 9966.00 8723.11 3 10483.37 8977.04 4 10883.37 8972.08 5 11043.37 8962.89 6 11153.37 8947.73 7 11213.00 8936.73 TO Height 70.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 01-19 9830.00 ft Mean Sea Level 26.52 deg 80.80 deg Direction deg 292.00 +N/-S ft 0.00 Map l\Iap <-- Latitude --> <- Longitude --> +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft ft ft ft 3635.77 -3840.85 5944267.74 693842.76 70 15 7.735 N 148 26 0.937 W 3635.77 -3840.85 5944267.74 693842.76 70 15 7.735 N 148 26 0.937 W 3019.29 -3831.98 5943651.74 693867.80 70 15 1.672 N 148 26 0.670 W 2821.42 -2540.64 5943487.83 695163.82 70 14 59.732 N 148 25 23.112 W 3346.76 -2583.91 5944011.82 695106.78 70 15 4.898 N 148 25 24,376 W 3333.20 -3441.60 5943975.76 694249.78 70 15 4.761 N 148 25 49.321 W 3308.56 -3341.21 5943953.77 694350.78 70 15 4.520 N 148 25 46.401 W 3143.45 -2766.30 5943803.81 694929.79 70 15 2.898 N 148 25 29.679 W ) ) BP Baker Hughes INTEQ Planning Report l:\lLf) Company: BP Amoco Date: 3/14/2002 Time: 16:00:39 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-19, True North Site: PB DS 01 Vertical (TVD) Reference: System: Mean Sea Level Well: 01-19 Section (VS) Reference: Well (0.00N,0.00E,292.00Azi) Wellpath: Plan#5 01-19A Sur\'e)' Calculation Method: Minimum Curvature Db: Oracle Plan: Plan #5 Date Composed: 3/14/2002 KOP above fish. Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 1\'ID Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/10Off deg 9800.00 31.00 326.00 8583.21 2740.40 -2484.87 0.00 0.00 0.00 0.00 9830.00 31.00 325.70 8608.93 2753.18 -2493.55 0.52 0.00 -1.00 269.87 9848.00 32.74 324.84 8624.22 2760.99 -2498.96 10.00 9.68 -4.78 -15.00 9898.00 36.08 316.00 8665.49 2782.66 -2516.99 12.00 6.67 -17.69 -60.00 9966.00 27.92 316.00 8723.11 2808.55 -2542.00 12.00 -12.00 0.00 180.00 10483.37 90.00 316.00 8977.04 3112.02 -2835.11 12.00 12.00 0.00 0.00 10883.37 91.34 268.01 8972.08 3257.55 -3195.18 12.00 0.33 -12.00 -88.20 11043.37 95.19 286.85 8962.89 3278.06 -3352.84 12.00 2.41 11.78 78.00 11153.37 100.61 299.01 8947.73 3320.35 -3452.99 12.00 4.93 11.05 65.00 11213.00 100.61 306.29 8936.73 3351.94 -3502.30 12.00 0.00 12.21 89.33 Survey Incl Aiim SSTVD VS J)LS TFO deg dêg ft ft . dêg/1PQft døg 9800.00 31.00 326.00 8583.21 2740.40 -2484.87 5943408.30 695221.68 3330.50 0.00 0.00 TIP 9825.00 31.00 325.75 8604.64 2751.06 -2492.10 5943418.76 695214.18 3341.19 0.52 269.87 MWD 9830.00 31.00 325.70 8608.93 2753.18 -2493.55 5943420.85 695212.68 3343.34 0.52 270;09 KOP 9848.00 32.74 324.84 8624.22 2760.99 -2498.96 5943428.52 695207.06 3351.28 10.00 345;00 1 9850.00 32.86 324.46 8625.90 2761.88 -2499.59 5943429.38 695206.41 3352.20 12.00 300.00 MWD 9875.00 34.46 319.88 8646.71 2772.81 -2508.09 5943440.09 695197.62 3364.17 12.00 300.32 MWD 9898.00 36.08 316.00 8665.49 2782.66 -2516.99 5943449.70 695188.47 3376.12 12.00 304.13 2 9900.00 35.84 316.00 8667.11 2783.50 -2517.81 5943450.52 695187.63 3377.19 12.00 180.00 MWD 9925.00 32.84 316.00 8687.75 2793.64 -2527.60 5943460.40 695177.57 3390.07 12.00 180.00 MWD 9950.00 29.84 316.00 8709.10 2802.99 -2536.63 5943469.51 695168.30 3401.95 12.00 180.00 MWD 9966.00 27.92 316.00 8723.11 2808.55 -2542.00 5943474.93 695162.79 3409.00 12.00 180.00 3 9975,00 29.00 316.00 8731.02 2811.63 -2544.98 5943477.93 695159.73 3412.92 12.00 0.00 MWD 10000.00 32.00 316.00 8752.56 2820.76 -2553.79 5943486.82 695150.68 3424.51 12.00 0.00 MWD 10025.00 35.00 316.00 8773.41 2830.68 -2563.38 5943496.49 695140.84 3437.11 12.00 0.00 MWD 10050.00 38.00 316.00 8793.50 2841.38 -2573.71 5943506.91 695130.24 3450.70 12.00 0.00 MWD 10075.00 41.00 316.00 8812.79 2852.81 -2584.75 5943518.05 695118.90 3465.22 12.00 0.00 MWD 10100.00 44.00 316.00 8831.22 2864.96 -2596.48 5943529.88 695106.85 3480.65 12.00 0.00 MWD 10125.00 47.00 316.00 8848.74 2877.78 -2608.87 5943542.37 695094.14 3496.93 12.00 0.00 MWD 10150.00 50.00 316.00 8865.31 2891.25 -2621.87 5943555.49 695080.78 3514.04 12.00 0.00 MWD 10175.00 53.00 316.00 8880.87 2905.32 -2635.46 5943569.20 695066.83 3531.91 12.00 0.00 MWD 10200.00 56.00 316.00 8895.39 2919.95 -2649.60 5943583.46 695052.31 3550.50 12.00 0.00 MWD 10225,00 59.00 316.00 8908.82 2935.12 -2664.24 5943598.23 695037.28 3569.76 12.00 0.00 MWD 10250.00 62.00 316.00 8921.13 2950.77 -2679.36 5943613.48 695021.76 3589.63 12.00 0,00 MWD 10275.00 65.00 316.00 8932.29 2966.86 -2694.90 5943629.16 695005.80 3610.07 12.00 0.00 MWD 10300.00 68.00 316.00 8942.26 2983.34 -2710.82 5943645.22 694989.45 3631.01 12.00 0.00 MWD 10313.10 69.57 316.00 8947.00 2992.13 -2719.31 5943653.78 694980.74 3642.17 12.00 0.00 01-19A T 10325.00 71.00 316.00 8951.01 3000.18 -2727.09 5943661.63 694972.75 3652.40 12.00 360.00 MWD 10350.00 74.00 316.00 8958.53 3017.33 -2743.65 5943678.33 694955.74 3674,18 12.00 0.00 MWD 10375.00 77.00 316.00 8964.79 3034.74 -2760.46 5943695.29 694938.48 3696.29 12.00 0.00 MWD 10375.92 77.11 316.00 8965.00 3035.38 -2761.09 5943695.92 694937.84 3697.11 12.00 360.00 01-19A T 10400.00 80.00 316.00 8969.78 3052.36 -2777.48 5943712.46 694921.01 3718.67 12.00 0.00 MWD 10425.00 83.00 316.00 8973.48 3070.14 -2794.66 5943729.78 694903.37 3741.25 12.00 0.00 MWD 10450.00 86.00 316.00 8975.87 3088.04 -2811.94 5943747.22 694885.63 3763.99 12.00 0.00 MWD 10475.00 89.00 316.00 8976.97 3106.00 -2829.29 5943764.72 694867.81 3786.80 12.00 0.00 MWD 10483.37 90.00 316.00 8977.04 3112.02 -2835.11 5943770.59 694861.84 3794.45 12.00 0.00 4 10500.00 90.06 314.00 8977.03 3123.78 -2846.86 5943782.03 694849.78 3809.75 12.00 271.80 MWD 10525.00 90.16 311.00 8976.98 3140.67 -2865.29 5943798.43 694830.91 3833.17 12.00 271.80 MWD ) ) I BP Baker Hughes INTEQ Planning Report I~l U) Company: BP Amoco Date: 3/14/2002 Time: 16:00:39 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-19. True North Site: PB DS 01 Vertical (TV D) Reference: System: Mean Sea Level Well: 01-19 Section (VS) Reference: Well (0.00N,0.00E,292.00Azi) Wellpath: Plan#501-19A Survey Calculation Method: Minimum Curvature Db: Oracle Survey 1\'ID Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10OO deg 10550.00 90.25 308.00 8976.89 3156.57 -2884.58 5943813.82 694811.22 3857.01 12.00 271.79 MWD 10575.00 90.34 305.01 8976.76 3171.44 -2904.67 5943828.15 694790.74 3881.21 12.00 271.78 MWD 10600.00 90.44 302.01 8976.59 3185.24 -2925.52 5943841.40 694769.55 3905.70 12.00 271.77 MWD 10625.00 90.53 299.01 8976.38 3197.93 -2947.05 5943853.52 694747.69 3930.42 12.00 271.75 MWD 10650.00 90.62 296.01 8976.14 3209.47 -2969.22 5943864.48 694725.22 3955.30 12.00 271.72 MWD 10675.00 90.70 293.01 8975.85 3219.84 -2991.97 5943874.25 694702.22 3980.28 12.00 271.69 MWD 10700.00 90.79 290.01 8975.52 3229.01 -3015.22 5943882.80 694678.73 4005.27 12.00 271.66 MWD 10725.00 90.87 287.01 8975.16 3236.94 -3038.92 5943890.11 694654.83 4030.22 12.00 271.62 MWD 10750.00 90.95 284.01 8974.76 3243.63 -3063.00 5943896.16 694630.58 4055.05 12.00 271.57 MWD 10775.00 91.03 281.01 8974.33 3249.04 -3087.40 5943900.93 694606.05 4079.70 12.00 271.53 MWD 10800.00 91.11 278.01 8973.86 3253.17 -3112.05 5943904.41 694581.30 4104.10 12.00 271.47 MWD 10825.00 91.18 275.01 8973.36 3256.01 -3136.88 5943906.60 694556.41 4128.19 12.00 271.42 MWD 10850.00 91.25 272.01 8972.83 3257.54 -3161.83 5943907.47 694531.43 4151.89 12.00 271.36 MWD 10875.00 91.32 269.01 8972.27 3257.76 -3186.82 5943907.04 694506.45 4175.15 12.00 271.30 MWD 10883.37 91.34 268.01 8972.08 3257.55 -3195.18 5943906.61 694498.09 4182.82 12.00 271.23 5 10900.00 91.75 269.96 8971.63 3257.25 -3211.80 5943905.88 694481.48 4198.12 12.00 78.00 MWD 10925.00 92.37 272.90 8970.73 3257.88 -3236.78 5943905.84 694456.50 4221.51 12.00 78.05 MWD 10950.00 92.98 275.84 8969.56 3259.78 -3261.67 5943907.09 694431.57 4245.31 12.00 78.16 MWD 10975.00 93.59 278.78 8968.13 3262.95 -3286.43 5943909.62 694406.74 4269.45 12.00 78.30 MWD 11000.00 94.18 281.73 8966.44 3267.40 -3310.97 5943913.41 694382,09 4293.86 12.00 78.46 MWD 11025.00 94.77 284.68 8964.49 3273.09 -3335.23 5943918.47 694357.69 4318.49 12.00 78.66 MWD 11043.37 95.19 286.85 8962.89 3278.06 -3352.84 5943922.98 694339.96 4336.68 12.00 78.89 6 11050.00 95.52 287.58 8962.27 3280.01 -3359.15 5943924.76 694333.60 4343.26 12.00 65.00 MWD 11075.00 96.78 290.32 8959.59 3288.08 -3382.65 5943932.21 694309.89 4368.08 12.00 65.07 MWD 11100.00 98.02 293.07 8956.37 3297.25 -3405.69 5943940.77 694286.63 4392.87 12.00 65.36 MWD 11125.00 99.25 295.84 8952.62 3307.48 -3428.18 5943950.40 694263.87 4417.56 12.00 65.72 MWD 11150,00 100.45 298.63 8948.34 3318.75 -3450.08 5943961.10 694241.69 4442.08 12.00 66.13 MWD 11153.37 100.61 299.01 8947.73 3320.35 -3452.99 5943962.62 694238.74 4445.38 12.00 66.61 7 11175.00 100.63 301.65 8943.74 3331.08 -3471.33 5943972.86 694220.12 4466.41 12.00 89.33 MWD 11200.00 100.62 304.70 8939.13 3344.52 -3491.90 5943985.76 694199.21 4490.51 12.00 89.82 MWD 11213.00 100.61 306.29 8936.73 3351.94 -3502.30 5943992.91 694188.62 4502.93 12.00 90.38 TD ,:k3s G ~TT;4L ) '\/---'---'-- .'.;;;;;.:.;";;.:.;;,,:.;.;:;.~.;.,;:;:.;.;..;.=.;".~~;;.,:~: ~i " ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7tJ1Street Suite # 700 Anchorage, Ataska 99501 RE: Distribution - Final Print( s} The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford. TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE loG TVPE DIGITAL MVLAR / ' BLUE LINE REPORT OR SEPIA PRINT(S) OR CD-ROM FILM COLOR 1 1 1 Open Hole Res. Eva!. CH 1 1 1 dDd -Odd. ; OS 01-19A 3/23/02 Mech. CH 1 Caliper Survey Signed: C--~~ ~þ~ Print Name: Date: RECEIVED f :'" !"; () r,'liì? f-\~~' ~-\ t..: ;J ~~~v\J- Alaska Oil & Gas Cons, Commission Anchorage PRoACTivE DiAGNOSTic SERVicES, INC., } 10 K STREET SUÌTE 200, ANClioRAGE, AK 99~01 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: \ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '\ 1. Operations performed: B Operation Shutdown 0 Stimulate 0 Pull Tubing 0 Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Plugging 0 Perforate 0 Repair Well 0 Other 5. Type of well: ŒI Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) RKB = 70' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 165' SNL, 462' EWL, SEC. 08, T10N, R15E, UM At top of productive interval NIA At effective depth 2638' NSL, 2056' WEL, SEC. 06, T10N, R15E, UM At total depth 2638' NSL, 2056' WEL, SEC. 06, T10N, R15E, UM 8. Well Number 01-19A 9. Permit Number I Approval No. 202-022 302-094 10. API Number 50- 029-20800-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9950 feet 8782 feet 9950 feet 8782 feet Plugs (measured) Set Baker Whipstock at 10080' (02/02) (TOW at 10089'); Set 2nd Baker Whipstock at 9950' (02/02) (Tow at 9950') Junk (measured) Window milling assemblies stuck and left in the hole for both windows. Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 1950# Poleset 80' 80' 2202 sx Fondu, 400 sx PF 'C' 2590' 2590' 500 sx Class 'G', 300 sx PF 'C' 9610' 8490' 385 sx Class 'G' 9305' - 9950' 8223' - 8782' 80' 20" 2590' 13-3/8" 9610' 9-5/811 645' 711 Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 5-1/211, 17#, L-80 to 9242'; 4-1/2", 12.6#, L-80 to 9340' Packers and SSSV (type and measured depth) BOT packer at 9231'; 5-1/211 Otis 'ROM' SSSV Nipple at 2168' 13. Stimulation or cement squeeze summary See attached Summary Intervals treated (measured) RECEIVED Treatment description including volumes used and final pressure MAR 2 8 2002 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl .[111111811&611"-- GI.utlulDn Casing preS~Ubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 0 Copies of Logs and Surveys run ŒI Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~ ~ Title Technical Assistant 16. Status of well classifications as: ŒI Oil 0 Gas 0 Suspended Service Form 10-404 Rev. 06/15/88 ORIGINAL Date 03-~ 7.0~ Prepared By Name/Number: Terrie Hubble, 564-4628 ~. . Submit In Duplicate ~ ) ) BP EXPLORATION Operations Summary Report Page 1 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NABORS NABORS 3S Start: 3/3/2002 Rig Release: 3/2/2002 Rig Number: Spud Date: 3/3/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 3/3/2002 00:00 - 06:00 6.00 MOB P PRE Mobilze Nabors 3S from S-17C to DS 1-19A 06:00 - 14:00 8.00 RIGU P PRE RIU Nabors 3S. DS CTU #4 is in Deadhorse changing out CT spool, making modifications to suction of unit's pump and misc. other work. They called at 1030 hrs with update. Found some cracks in the derrick that's needs welded. ETA on location 2300 hrs. 14:00 - 19:00 5.00 BOPSUR P SURF Accept Nabors 3S. Start nipple up of BOPE. Same time Veco set in backside and upright tanks. 19:00 - 22:30 3.50 BOPSUR P SURF Set test plug in wellhead. Grease all bope valves. AOGCC rep Chuck Sheve has wavied witnessing test of BOPE. 22:30 - 00:00 1.50 BOPSURP SURF Test BOPE 5 min 5k psi high / 5 min 250 psi low. DS CTU #4 arrived location at midnight. Now has 30 hrs total maint time for this month. 3/4/2002 00:00 - 03:25 3.42 BOPSUR P SURF Finish testing BOPE. DS CTU #4 on location at OOOOhrs. Start r/u. 03:25 - 04:00 0.58 BOPSUR P SURF Pull test plug f/wellhead. 04:00 - 04:25 0.42 STWHIP P WEXIT PJSM on p/u and stabbing of coil to injector. 04:25 - 10:30 6.08 STWHIP P WEXIT Continue r/u of CTU stab pipe finish connect eleclpump control lines from Nabors rig. Make up DS CTC replace pack-off and brass in the stuffing box. PJSM covering meth direction. And flush new CT with 1.375" ball. 10:30 - 10:45 0.25 STWHIP P WEXIT PJSM review methanol handling procedures for CT cleanout. 10:45 -11:35 0.83 STWHIP P WEXIT Drop 1.375" ball and sweep CT with 54 bbls methanol. 11 :35 - 13:20 1.75 STWHIP P WEXIT Cut-off CTC and recover ball. Rehead CTC pull test 30k and PT to 3500 psi. 13:20 - 14:40 1.33 STWHIP P WEXIT Displace methanol from coil. Same P/U BHA #1. 14:40 - 15:15 0.58 STWHIP P WEXIT PT MHA to 3500 psi. Stab onto well 15:15 -16:10 0.92 STWHIP P WEXIT RIH to 3500' displacing diesel in wellbore 16:10 -17:40 1.50 STWHIP P WEXIT Continue RIH tag up at XN nipple 9328'. Stop correct coil depth -13' correction. RIH back to XN nipple. 17:40 - 18:10 0.50 STWHIP P WEXIT Mill out XN nipple. Run through w/o pump ok. 18:10 - 18:55 0.75 STWHIP P WEXIT Continue RIH to top of whipstock. No cement. Find pinch point at 10081'. Flag pipe. 18:55 - 00:00 5.08 STWHIP P WEXIT Start time milling window at 10089.4' mill to 10092.2' Milled w/ <2k wob. 3/5/2002 00:00 - 03:30 3.50 STWHIP P WEXIT Continue milling window f/1 0092.2' to 10096.5' Window: 10089.4' - 10096.5' 03:30 - 04:30 1.00 STWHIP P WEXIT Drill cmtlformation from 10097.1' to 10101'. WOB 2500# Sample show 95% cement 04:30 - 05:20 0.83 STWHIP P WEXIT Backream through window @ 1.2'/min and back down through window. Stopped at 10108' not stacking weight. RIH to 10121' still not stacking weight. P/U to window RIH dry tag at 10150'. P/U RIH min rate tag at 10172'. P/U above window. RIH dry no problems through window and tagged again at 10172', Each time P/U apprx 3-5k overpull at 10105'. 05:20 - 07:40 2.33 STWHIP P WEXIT TOH. BHA parted at the non-rotating joint. 07:40 - 09:40 2.00 STWHIP N WEXIT Gather up fishing tools. Fish looking up: lower portion of disconnect (3.062"od 0.99' long), XO, 2 jts 2 3/8" PH-6 tbg, XO, motor, string mill, window mill. Total length 79.65' Top offish 10027.35'. 09:40 - 10:00 0.33 STWHIP N WEXIT Tools on location, PJSM covering p/u bha, fishing procedure and bha/fish retrieval procedures on surface. 10:00 - 11 :40 1.67 STWHIP N WEXIT Cut 15' of coil. Cut-off DS CTC. MU Baker CTC pull test to Printed: 3/12/2002 10:14:00 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NABORS NABORS 3S Date From - To Hours Activity Code NPT Phase 3/5/2002 10:00 - 11 :40 1.67 STWHIP N WEXIT 11 :40 - 12:00 0.33 STWHIP N WEXIT 12:00 - 13:35 1.58 STWHIP N WEXIT 13:35 -14:00 0.42 STWHIP N WEXIT 14:00 - 16:30 2.50 STWHIP N WEXIT 16:30 - 17:00 0.50 STWHIP N WEXIT 17:00 - 18:00 1.00 STWHIP N WEXIT 18:00 - 18:30 0.50 STWHIP N WEXIT 18:30 - 19:00 0.50 STWHIP N WEXIT 19:00 - 20:50 1.83 STWHIP N WEXIT 20:50 - 21 :00 0.17 STWHIP N WEXIT 21 :00 - 21 :10 0.17 STWHIP N WEXIT 21:10 - 21:15 0.08 STWHIP N WEXIT 21:15 - 21:18 0.05 STWHIP N WEXIT 21:18 - 22:20 1.03 STWHIP N WEXIT 22:20 - 00:00 1.67 STWHIP N WEXIT 3/6/2002 00:00 - 00:45 0.75 STWHIP N DFAL WEXIT 00:45 - 02:00 1.25 STWHIP N DFAL WEXIT 02:00 - 03:14 1.23 STWHIP N DFAL WEXIT 03:14 - 06:15 3.02 STWHIP N DFAL WEXIT 06: 15 - 09:30 3.25 STWHIP N DFAL WEXIT 09:30 - 10:15 0.75 STWHIP N DFAL WEXIT 10:15 -12:00 1.75 STWHIP N DFAL WEXIT 12:00 - 13:30 1.50 STWHIP N DFAL WEXIT 13:30 - 15:30 2.00 STWHIP N DFAL WEXIT 15:30 - 17:45 2.25 STWHIP N DFAL WEXIT 17:45 - 19:30 1.75 STWHIP N DFAL WEXIT 19:30 - 21 :21 1.85 STWHIP N DFAL WEXIT 21:21 - 22:15 0.90 STWHIP N DFAL WEXIT Page 2 of4 Start: 3/3/2002 Rig Release: 3/2/2002 Rig Number: Spud Date: 3/3/2002 End: Description of Operations 45K PT to 3500. Continue p/u bha #2 Stab on to well. RIH w/ fishing BHA 114.58' Latch fish and jar starting at 10k over and progressing to 40 k over. On third lick at 40 over we came free moved up hole. POH with 2-3k drag. Lay down tool. No Fish. Wait on fishing tools. Crew change and PJSF for picking up fishing BHA. MU Fishing assembly BHA #3. RIH with BHA#3. Jar on fish 11 k to 14 k over string weight Break circulation 1.1@ 790 psi to 1.5 bpm@ 1420 psi. Jar on fish 16k over no go. Circulate while holding 21 k over pick up weight Jar on fish progessive increase over pull. Periodically circulating while hold strain on pipe. 1 bpm @ 700 psi, 1.2 bpm @ 925 psi, 1.6 bpm 1490 psi. Pull to pipe limit 90,000 46k over. Monitoring pipe life while jarring have set 20% pipe life as limit No positive indicators during jarring. Slack off to 8000. 17000 = slackoff weight. Circulate at 1.5 bpm @ 1425 psi. Note we can see pressure increase from 1490 psi to 3030 psi @1.5 bpm with BHA in compression. We believe we are pinching the flow path between the over shot and the upset on the fish. When be pick up to neutral weight the pressure drops back to 1400psi. However, there is no indication on the weight indicator of any pipe movement i.e. flicker. There is no indicating that we are circulating at the bit and no movement of the BHA. We believe to be stuck with cuttings. See Remarks Wait on crude oil while holding strain on pipe 30 over and circulating at 1.5 bpm. Circulate 10 bbl of crude to BHA spot 5 bbl at fish. Spot 5 bbl crude around fish. Hold 30 over. No results. Slack off and Hold. No results. Pressure backside to 500 psi and hold 36k over. Bleed off. Hold 21 k over while circulating at .3 bpm wait on HCL. Circulate 10 bbl of 15% HCL . Displace and spot 5 bbl out side fish. Bullhead .5 bbl every 15 minutes. Sit in compression. Bull head backside 700 psi .5 bbl every 15min. Pull to maximum (+/-93K). Pop free. POOH to check BHA. LD Fishing BHA #2. No recovery. Lost a 1/2" x 1" of spiral grapple. Set injector on back deck. Inspect same. Replace several broken chain bearings. MU undereaming assy with DB reamer with 6.250 blades. RIH with assembly Tag fish at 10044'. Correct depth to 10027' and flag pipe. POOH to 9957'. 43.5k# up wt. Begin reaming dn with 2.5 bpm, 1950 psi, 20 fph to start. Ream up 10,020' to 9,055'. POH to surface. Set injector back on deck. Printed: 3/12/2002 10:14:00 AM ) ') BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NABORS NABORS 3S Page 30f4 Start: 3/3/2002 Rig Release: 3/2/2002 Rig Number: Spud Date: 3/3/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 3/6/2002 22:15 - 00:00 1.75 STWHIP N DFAL WEXIT PU whipstock and rig up Eline. 3/7/2002 00:00 - 00: 15 0.25 STWHIP N DFAL WEXIT Complete rigging up wireline. 00:15 - 02:00 1.75 STWHIP N DFAL WEXIT RIH with whipstock 02:00 - 02:40 0.67 STWHlp. N DFAL WEXIT Tie in -3' correction. Didn't have sufficient distance between the fish and perferred setting depth of the whipstock to orient to the desired tool face. We had to move up one joint. Set whipstock with TOW 9950' RA 9960' with toolface 15L. 02:40 - 03:30 0.83 STWHIP N DFAL WEXIT POH 03:30 - 04:30 1.00 STWHIP N DFAL WEXIT Rig down Eline 04:30 - 05: 15 0.75 STWHIP N DFAL WEXIT MU milling assembly for second window. TOW at 9950'. 05: 15 - 06:45 1.50 STWHIP N DFAL WEXIT Tag whipstock at 9970 '. Correct to ELM depth of 9950'. Flag pipe at 9950 06:45 - 09:30 2.75 STWHIP N DFAL WEXIT Begin milling window at 9949.5. 1850 psi @ 2.5 bpm. 09:30 - 09:45 0.25 STWHIP N STUC WEXIT Mill to 9954'. 1650 psi FS @ 2.5 bpm. 400-600 dpsi. 300-1000# wob. Stall and try to PU. Stuck (stalled). Order crude and slick pill. 09:45 - 10:30 0.75 STWHIP N STUC WEXIT Work pipe & pump. Pull up to 95K#. Pipe appeared to stretch up to 10'. 10:30 - 11 :00 0.50 STWHIP N STUC WEXIT Pressure back side and coil to 2100 psi. Work pipe to max of 81 K#. Cycle pipe. No movement. Bleed pressure rapidly and pull. No movement. Pressure to 2500 psi. Repeat. Same. 11 :00 - 13:00 2.00 STWHIP N STUC WEXIT Wait on fluids. 13:00 - 14:45 1.75 STWHIP N STUC WEXIT Pump 15 bbls crude. Spot 5 bbls out of coil. Pressure annulus to 2000 psi to bull head away. Let soak. Work pipe to 90K#. No movement. Repeat 2 more times. 14:45 - 16:45 2.00 STWHIP N STUC WEXIT Pump 18 bbls new flopro with 3% lubtex & 3% flolube. Spot 5 bbls out coil. Bullhead same & pressure annulus to 2500 psi. Work pipe to 85K#. No movement. Repeat several times. No movement. 16:45 - 17:30 0.75 STWHIP N STUC WEXIT Wait on HCL acid from DS. 17:30 - 19:30 2.00 STWHIP N STUC WEXIT Spot 6 bbls 15% HCL around fish. Allow to soak. Work pipe and pressure annulus. No movement. 19:30 - 20:00 0.50 STWHIP N stuc WEXIT 20:00 - 21 :50 21:50 - 23:10 23:10 - 23:55 1.83 STWHIP N 1.33 STWHIP N 0.75 STWHIP N stuc WEXIT STUC WEXIT STUC WEXIT 3/8/2002 23:55 - 00:00 00:00 - 01 :00 01 :00 - 02:15 02:15 - 04:15 0.08 STWHIP N 1.00 STWHIP N 1.25 STWHIP N 2.00 STWHIP N STUC WEXIT STUC WEXIT stuc WEXIT stuc WEXIT Circ ball to disconnect from fish. On seat at +/- 40 bbls away. Sheared at 4300 psi. POOH Inspect pin and bearings on injector. Install coil connector. Pull test to 45000# and pressue test to 3500 psi. PU fishing BHA Make up BHA for fishing milling assembly form second window. RIH to 9872. Pick up 38,000# S020,OOO# Latch fish. Jarred down progressively increasing set down weight from 2000 to -27000. No movement. Jarred up progessively increasing up force from 56,000 to 92,000, Attempted jarring while pumping, while pressuring system and while pumping down the back side without success. Some movement +- 2' was seen at 51000# but we were unable to progess it. A total of 75 jar licks 22 dn 53 up were made. Ran out of coil live . Disconnected. POH. Printed: 3/12/2002 10:14:00 AM ) ) BP EXPLORATION Operations Summary Report Page 4 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-19 01-19 REENTER+COMPLETE NABORS NABORS 3S Start: 3/3/2002 Rig Release: 3/2/2002 Rig Number: Spud Date: 3/3/2002 End: Date From - To Hours Activity Code. NPT Phase Description of Operations 3/8/2002 02:15 - 04:15 2.00 STWHIP N stuc WEXIT With only 4' of window cut it appears we jumped out early. Hovever, the cementing records and the CBL all indicate that the cement job was good and contrary to jumping out early. 04:15 - 06:00 1.75 STWHIP N stuc WEXIT POH to 2000 and lay in freeze protection methanol. 06:00 - 06:15 0.25 STWHIP N stuc WEXIT Hold PJSM.crew change mtg. 06:15 - 07:00 0.75 STWHIP N stuc WEXIT LD fishing tools. 07:00 - 07:15 0.25 STWHIP N stuc WEXIT Hold safety mtg before beginning RD. 07:15 -14:00 6.75 RIGD N stuc COMP Rig down coil unit. Set BPV. Clean pits. ND BOPS. Release rig at 1400 hrs 3/8/02. CTU #4 off location at 1500 hrs. 14:00 - 20:00 6.00 RIGD P COMP Continue to prep for move to DS 3-34A Printed: 3/12/2002 10:14:00 AM ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ÁI13 fD7:s .3/ /'¥--.- 1. Type of Request: [J Abandon [J Alter Casing [J Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. [J Suspend [J Plugging [J Time Extension [J Perforate [J Repair Well [J Pull Tubing [J Variance [J Other II Operation Shutdown [J Re-Enter Suspended Well [J Stimulate 5. Type of well: II Development 0 Exploratory 0 Stratigraphic 0 Service 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 165' SNL, 462' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 2555' NSL, 2000' WEL, SEC. 06, T10N, R15E, UM At effective depth 2638' NSL, 2056' WEL, SEC. 06, T10N, R15E, UM At total depth 3219' NSL, 3024' WEL, SEC. 06, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical (Planned) Effective depth: measured true vertical 9950 feet 8782 feet 9950 feet 8782 feet 6. Datum Elevation (DF or KB) RKB = 70' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 01-19A 9. Permit Number 202-022 10. API Number 50- 029-20800-01 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool Plugs (measured) Set Baker Whipstock at 10080' (02/02) (TOW at 10089'); Set 2nd Baker Whipstock at 9950' (02/02) (TOW at 9950') Junk (measured) Window milling assemblies stuck and left in the hole for both windows. Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented 80' 20" 2590' 13-3/8" 9610' 9-5/8" 1195' 7" 1950# Poleset 2202 sx Fondu, 400 sx PF 'C' 500 sx Class 'G', 300 sx PF 'C' 385 sx Class 'G' Perforation depth: measured Sqzd & P&A'd: 10154' - 10254' MD TVD 80' 80' 2590' 2590' 9610' 8490' 9305' - 9950' 8223' - 8782' RECEIVED MAR 1 3 200Z true vertical Sqzd & P&A'd: 8957' - 9041' AI~sk~ Oil & Gas ConS. Commission Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9242'; 4-1/2", 12.6#, L-80 to '93"40 Anchorage Packers and SSSV (type and measured depth) BOT packer at 9231'; 5-1/2" Otis 'RQM' SSSV Nipple at 2168' 0 Detailed Operations Program 15. Status of well classifications as: II Oil 0 Gas 0 Suspended 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation March 8, 2002 16. If proposal was verbally approved Tom Maunder Name of approver Contact Engineer NameINumber: Ted Stagg, 564-4694 is true and correct to the best of my knowledge Title Technical Assistant 3/8/2002 Date Approved Service 0 BOP Sketch Prepared By NameINumber: Terrie Hubble, 564-4628 17. I hereby certify that Signed Terrie Hubble Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- \.\ö~ Original Signed By Ca,u",y!@~ I GIN A L Approved by order of the Commission Form 10-403 Rev. 06/15/88 Approval No.30;;'-Oc¡f Commissioner Date 3~ I Y. 0 .:l- Submit In Triplicate ) ) ~' Hubble, Terrie L From: Sent: To: Subject: Stagg, Ted 0 (ORBIS) Monday, March 11, 2002 1 :38 PM Hubble, Terrie L FW: DS1-19a and DS3-34b Card for Tom Maunder -----Orig i nal Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us) Sent: Friday, March 08, 2002 2:08 PM To: Stagg, Ted 0 (ORBIS) Subject Re: OS1-19a and OS3-34b Ted, With things plugged in the original wellbore and an exit having been made, the proper victim is 1-19A. Lets let 1-19 rest in peace. Have a good weekend. Tom "Stagg, Ted 0 (ORBIS)II wrote: > Tom, > > On 1-19a we milled the first window with 10 feet of formation penetration > when the mill stuck and was left there after unsuccessful fishing. A second > whipstock was set but only 4.5 ft milled before we got stuck. This second > effort probably made a hole in the 1-19 liner but not much more. If 10ft > of milling through the window is enough to call it a sidetrack then I guess > the 403 will have to be for 1-19a. > > OS 1-19a is being left with kill weight fluid, freeze protected and BPV in > place. The 1-19 perfs were abandoned by downsqueezing cement past the first > whipstock. > > Fortunately we have Terrie Hubble doing the paperwork so you should see the > Ops Shutdown Sundry soon. > > We will carryon with 3-34C, as permitted, unless educated otherwise. > > Ted > > -----Original Message----- > From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us) > Sent: Friday, March 08, 2002 12:44 PM > To: Stagg, Ted 0 (ORBIS) > Cc: Gantt, Lamar L; McCarty, Thomas M > Subject: Re: OS1-19a and OS3-34b > > Gentlemen, > I presume the 403 for operations shut down is being prepared. 1 Was there ') ) > ever ~. > any successful exit from 1-19?? Was the well P&Aed?? My reason for asking >is > that if you never got out of 1-19 then the 403 should be for that name. It > seems that you would still be doing work covered under the sundry. > Semantics...semantics. > On the permutations of 3-34...lt seems that the producing conduit will be > essentially continuous, although. there might be a section into the > non-productive Shublik. My assessment is the the C designation is likely > correct. I defer to Steve Davies and Crandall on the naming convention and >1 > can only presume that when the application came in that the correct > designation > was considered. I am open to discussing, but I'm not sure that C of BL 1 is > anything critical. > Tom > > "Stagg, Ted 0 (ORBISr wrote: > > > Tom, » > > N3S is shutting down operations on DS1-19a due to window milling trouble. > > Two mechanical whipstocks have beenset in DS1-19 and a milling assembly > has > > been stuck in each one. The cause of this trouble is not clear at this > > time. DS1-19 will be freeze protected and left shut in pending further > > analysis of the trouble encountered and available options. » > > N3S will move to DS3-34b for a coil sidetrack. Permit 202-050 was just > > issued for 3-34C. 3-34B is a horizontal Sag River only well that dipped > > into the Shublik near TD. The coil sidetrack will exit the existing > slotted > > liner just above the point at which 3-34B entered the Shublik. The > existing > > slotted liner in the Sag R will be retained and the new hole drilled in > the > > Sag R will be completed with a slotted liner. This completion plan > appears > > to me to suggest that the new sidetrack should be named 3-34BL 1 rather > than > > 3-34C. If you agree then what dol have to do to sort out the name > change? » > > Ted Stagg > > 564-4694 office > > 240-8074 cell 2 ) ;~~fÆ~E :'F !Æ~!Æ~~~fÆ TONY KNOWLES, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333W. ]'TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty . Ct Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: PBU 01-19A BP Exploration (Alaska) Inc. Permit No: 202-022 Sur Loc: 165' SNL, 462' EWL, Sec. 08, TI0N, RISE, UM Btmhole Loc. 3219' NSL, 3024' WEL, Sec. 06, TI0N, RI5E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for PBU 01- 19A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~1kJv~'~ Cammy &echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 8th day of February, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA ( STATE OF ALASKA )AND GAS CONSERVATION COMMI\ PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory D}3tratigraphic Test II Development Oil 0 Service 0 Development Gas [B'Single Zone At> 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 70' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028329 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 01-19A 9. Approximate spud date 02116/02 Amount $200,000.00 14. Number of acres in property 15. PrQPoseg;:iepth (MD and TVD) .,..2éa(r Z'X:f{ )$) ì(2..7"~' MD I 8934' TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 102 Maximum surface 2420 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 239~ 9330' 8175' ~ 8934' Î t¡LÌ~ f 1/2.7'-' 'þN vJG;A 1-/7/0 "2- ~ d./~ JMlt z( 'l!OÞ 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 165' SNL, 462' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 2555' NSL, 2000' WEL, SEC. 06, T10N, R15E, UM At total depth 3219' NSL, 3024' WEL, SEC. 06, T10N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028311, 1999' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10080' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weioht Grade Couplina 3-3/4" 3-1/2" x 3-3116" 8.81# /6.2# L-80 ST-L x 2-7/8' 6.2 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Casing Structural Conductor Surface Intermediate Production Li ner 1 0505 feet 9243 feet 1 0327 feet 9101 feet Length Quantitv of Cement v' (include staae data) 83 sx Class 'G' :a .5 W Plugs (measured) PBTD Tagged at 10327' (11/97) Ed £r ~1 ~ &- æ cW~ ~ ð i ~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Junk (measured) Size Cemented MD TVD 1950# Poleset 80' 80' 2202 sx Fondu, 400 sx PF 'C' 2590' 2590' 500 sx Class 'G', 300 sx PF 'C' 9610' 8490' 385 sx Class 'G' 9305' - 10500' 8223' - 9239' 80' 20" 2590' 13-3/8" 9610' 9-5/8" 1195' 7" true vertical Sqzd: 10154' - 10254' Sqzd: 8957' - 9041' Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas Mc~arty ~ ~~ ,llle' CT Drilling Engineer Commission Use Only Approved By Form 10-401 Rev. 12-01-85 Permit Number API Number 20 Z- ~ 0 Z '2..--50- 029-20800-01 Conditions of Approval: Samples Required 0 Yes ~o Hydrogen Sulfide Measures li('Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: 'Test- BQ PE to ~çoo p~. Original Signed By Commissioner Canny~. ~1 t U See cover letter for other requirements Mud Log Required 0 Yes ~o Directional Survey Required ~es 0 No D4K D5K D10K D15K 0 3.5K psi for CTU VJGA- - by order of the commission Date Approval Date jr~}1r\JAj Submit In Triplicate ) ) BP 01-19a Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for well 01-19a. The coil sidetrack, will exit the 7" liner in Zone 2 and target Zone 2/Zone 1. 01-19a will be completed with a combination solid cemented 3 ¥2" x 3 3/16" x 2 7/8" liner. The existing perforations will be isolated with cement pumped past a thru-tubing mechanical whipstock. çhase 1: Prep work. Planned for Feb. 07, 2002. 1. Drift tubing and liner with dummy whipstock. 2. Run casing caliper over whipstock interval. 3. Dummy off all GLM's and perform integrity test on inner annulus to 2500 psi. ~ 4. Use E-line to set a mechanical whipstock at approx. 10,080'MD (8824s;V31 deg inclination). ~...~~ 5. Use service coil to cement squeeze perfs below whipstock with 36 bbls cement (liner volume + 40% excess). . 6. Mill XN nipple and window to 3.8" with service coil if time permits. \. Phase 2: Drill and Complete sidetrack: Planned for Feb. 16, 2002. Drilling coil will be used to mill the window (if it cannot be milled with service coil due to time constraints) then drill and complete the 3.75" directional hole as per attached plan. Maximum planned hole angle is 103 degrees. The production liner will be a 3 Y2" X 33/16" x 2 7/8" solid cemented liner. Mud Program: . Phase 1: Seawater/biozan / . Phase 2: Mill with seawaterlbiozan, drill with Flo-Pro (8.6 - 8.7 ppg) 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: / The production liner will be a 3 ¥2" ST -L x 3 3/16" TC II x 2 7/8" ST -L cemented liner from TO to approx. 9330'MD (8175'tvdss). The X-O between 3 3/16" x 2 7/8" will be at approx. 10110' MD. Only the top 30' joint will be 3 Y2". Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 103 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray I Resistivity log will be run in the open hole section. . A memory CNL will be run inside the cemented liner. Hazards .1/ . The max recorded H2S on this drillsite was 146ppm on well 01-07 (4/25/2001). Reservoir Pressure Res. press. is estimated to b;ß300 psi at 8800'ss (7.2ppg emw). Max. surface pressure with gas (0.1 psi/ft) to surface is 2420psi. ) --_? FMC .AXB..SÖN 70 -;; TREE = WELLHEAD= A Cfl..lA. TOR;" .. K8. ELEV == . è F. ELEV == KOP=-' ,..", ,. ."m ,i\1ax Ang~-=--. Datum MD = ~~-"..,.... Datum TVD= 3000 40 @ 6800 10053 8800 SS 13-3/8"CSG, 72#, L-80, 10=12.347 l---i 2590' r-J Minimum ID = 3.725"@9328 4-1/2"Otis XN Landing Nipple 5-1/2" TBG-PC, 17#, L80, .0232bpf, 10=4.892 H 9242' I TOP OF 4-1/2" TOO-Fe H 9242' I TOP OF 7' LNR H 9305' 4-1/2"TBG-PC, 12.6#, L80, .0152bpf, D=3.958 1---1 9340' I 9-518" CSG, 47#, L-80, 10=8.6811---i 961 0' ~ PERFORATION SUIVtv1ARY REF LOG: BHCS on 9/7/1982 ANGLE AT TOP ÆRF: 31 @ 9755 I'bte: Refer to A'oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8 6 10154-10184 S 1/5/1989 3-318 4 10178-10183 S 9/14/1995 3-3/8 3 10194-10204 S 811311989 3-3/8 3 10204-10216 S 811311989 Nt.. 2 10214-10218 S 10/1/1993 7" Lf\R, 29#, L-80, .0371 bpf, 10=6.184 H 10500' ~ 10505' I Oð.TE 09111/82 09111/82 11/9/2000 02108101 02115/01 COMrvENTS REV BY SIS-LG SIS-MD TP ORIGINAL OOMJLEfION LAST WORKOVER 00 NVERTEDTO CANVAS ANAL OORRECTIONS 01-19 ) I 'SAFETY NOTES: IAXDA COMM 2168' H 5-1/2" OTIS RQM SSSV NIFf>LE, 10= 4.562 1 (I GAS LIFT MANDRELS STA rvÐ TVD DEV lYÆ MAN LATŒi 1 2915 2913 9 RL5524 T-2 ~ 2 4948 4750 36 RL5524 RA 3 6561 6000 40 RL5524 T-2 4 7729 6904 38 RL5524 RA 5 8352 7407 35 RL5524 RA L 6 8429 7471 34 RL5524 RA 7 8778 7764 31 RL5524 RA 8 8854 7830 30 RL5524 RA 9 9116 8057 29 RL5524 T-2 10 9188 8120 28 RL5524 RA 9210' H 5-1/2" BOT PBR ASSY 1 :8: ~ '/'1 9231' H 9-5/8" X 5-112" BOT PACKER I \ I 9242' H X05-1/2"X 4-1/2" 1 .. . ,/ I I 9328' H 4-1/'Z' OTIS XN LANDING NIP, ID=3.725 I I I ~ ~ 9340' - 4-1I'Z' TUBING TAIL I 9338' - ELMD- TT-LOGGED 1/20/88 I FRLDHOE SA Y UNT WELL: 01-19 PERMIT No: 82-125 API No: 50-029-20800-00 SB: 6 T10N R15E 2233.27 FEI.. 2387.66 FNL BP Exploration (Alas ka) TREE = _? WELLHEAD= FMC .ACTÜÃTOR;w......äWÃxêCsO¡;:r 'KS:'êLST;ww"" ..w.w.~mwwm,ww70 """""""""......'...wN.'^vw.W.....w.'~.~W^,".w.w~..........~.,'~m,,.,.......y.W.....W.'.,...",,".......".....W.W.W....."....,- BF. ELEV = ? ',<Op';'."w""w,w, ..- - ow... '~3ÕÖÕ ^~~.~~:~~~~,::§'.::'::::':~w~:~':~~'Ö"~: Datum MD = 10053 'ì5ãtüm'T\Tì5;~mw~w.w'88ÕÔ"SS ) 01-19A Proposed CTD ST \ SAFElY NOTES: IAXDA COMM 13-3/8"CSG, 72#, L-80, ID=12.347 l-l 2590' Minimum 10 = 3.725"@9328 4-1/2"Otis XN Landing Nipple 5-1/2" TBG-PC, 17#, L80, .0232bpf, ID=4.892 l-l 9242' TOPOF 4-1/2" TBG-PC l-l 9242' TOPOF 7" LNR l-l 9305' ITOP OF 3-1/2" liner l-l 9330' 4-1/2" TBG-PC, 12,6#, L80, .0152bpf, ID=3.958 l-l 9340' 1 9-5/8" CSG, 47#, L-80, ID=8.681 l-l 9610' 1- ~ ,/ 1 Cement Top 1-l9800'1- ÆRFORA TION SUMMARY REF LOG: BHCS on 9/7/1982 ANGLEATTOPÆRF: 31 @ 9755 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 10154-10184 S 1/5/1989 3-3/8 4 10178-10183 S 9/14/1995 3-318 3 10194-10204 S 8/13/1989 3-318 3 10204-10216 S 8/13/1989 NA 2 10214-10218 S 10/1/1993 8 r-J L , ~ ~ 2168' l-l 5-1/2" OTIS RQM SSSV NIPPLE, ID= 4.562 I GAS LIFT MANDRELS STA MD 1VD DEV TYÆ MAN LATCH 1 2915 2913 9 RL5524 T-2 2 4948 4750 36 RL5524 RA 3 6561 6000 40 RL5524 T-2 4 7729 6904 38 RL5524 RA 5 8352 7407 35 RL5524 RA 6 8429 7471 34 RL5524 RA 7 8778 7764 31 RL5524 RA 8 8854 7830 30 RL5524 RA 9 9116 8057 29 RL5524 T-2 10 9188 8120 28 RL5524 RA :g ~ 9210' l-l 5-1/2" BOT PBRASSY I 9231' l-l 9-5/8" X 5-1/2" BOT PACKER 1 9242' l-l XO 5-1/2" X 4-1/2" I 9328' l-l 4-1/2" OTIS XN LANDING NIP, ID=3.725 I 9340' l-l 4-1/2" TUBING TAIL I 9338' l-l ELMD- TT-LOGGED 1/20/88 I ~ ~ 10080' HTop of rrech. Whipstock (Zone 2 KOp) I ~..//) 1~!10'1 I 3-3/16"x2-7/B"XO I ./ 2 718" P&A CeMent:f»a~tIWhipstock 12-7/8" L-80 Liner, Perforated / l-i 11276'1 I PBTD (tagged fill) l-l 10270' I 7" LNR, 29#, L-80, .0371 bpf, ID=6.184 l-l 10500' I ~-l 10505' I DATE 09/11/82 09/11/82 11/912000 02/08/01 02/15/01 COMMENTS REV BY SIS-LG SIS-MD TP ORIGINAL COMPLEllON LAST WORKOVER CONVERTED TO CANVAS FINAL CORRECTIONS I 1/ I 1 \ I .. I .. - ~ ..- (\') 00 0 ° 000 °0 °0 00 .°0 ~ PRUDHOE BAY UNIT Wa.L: 01-19 ÆRMIT No: 82-125 API No: 50-029-20800-00 SEe 6 T10N R15E 2233.27 Fa. 2387.66 FNL BP Exploration (Alaska) B~'AmQCo. : Ptüèih¥~ .PBPS01 . 01:';19,. Plah#3~01~19A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level PB DS 01 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft . ço~paøy: . , Fiêld: Site:; . . . . Wèll: . . W~~path:.. Field: Site: ) .J118 IIUGIIIS ----~_...-- . INTEQ ) BP Amoco Baker Hughes INTEQ Planning Report '. oaie;':1128,2ÒÒ2'. . .~~.. .Q9i24:24., .." . ~ågé; . .1 ..C~r~~~Nf:)~~(e,ie~~e: .;. WEil~::01':1~¡Ttl,l~~Orth . -Y'~t:~(1X~n~!t~~,~~: .." "'$y~,!~ro,:~~"ß~'J-~~~l.'.. ,. .' ,~!I (VS)~~fèr,.e; .. ... . W~It.(9.t~{n~~9'6QE.~.OO~il . SVrveY:Qlle.tic».'IM~hód; .' MitiimumGuM1!ure . Db; .Oracle Map Zone: Coordinate Svstem: Geomagnetic "Model: Alaska, Zone 4 Well Centre BGGM2001 5941932.14 ft Latitude: 697237.60 ft Longitude: North Reference: Grid Convergence: 70 14 43.905 N 148 24 24.004 W True 1.50 deg Well: 01-19 01-19 Well Position: 19 70 14 31.987 N 148 24 9.225 W Slot Name: +N/-S -1211.74 ft Northing: 5940734.19 ft Latitude: +E/-W 508.35 ft Easting: 697777.46 ft Longitude: Position Uncertainty: 0.00 ft Well path: Plan#301-19A 500292080001 Current Datum: 31 : 198/24/198200:00 Magnetic Data: 1/16/2002 Field Strength: 57513 nT Vertical Section: Depth From (TVD) ft 0.00 Plan: Principal: Yes Targets Annotation Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 01-19 10080.00 ft Mean Sea Level 26.58 deg 80.80 deg Direction deg 292.00 1/16/2002 1 From: Definitive Path Height 70.00 ft +N/-S ft 0.00 Plan #3 Date Composed: Version: Tied-to: Name J>~eripti9n -Map.. ~~e .4 ,'LàÜ"".,+>. .~I..öngit"'de,~ TVJ) . +N/:.;S. +El.;W ..' :NortJlJ-g. .,~"g. øeg'MJ~:.~. 'j)~g~i~'$~ . ft It ft. . ft" : ft. 8977.00 3143.45 -2766.30 5943803.81 694929.79 70 15 2.898 N 148 25 29.679 W 8965.00 3308.56 -3341.21 5943953.77 694350.78 70 15 4.520 N 148 25 46.401 W 8947.00 3333.20 -3441.60 5943975.76 694249.78 70 15 4.761 N 148 25 49.321 W 0.00 3635.77 -3840.85 5944267.74 693842.76 70 15 7.735 N 148 26 0.937 W 0.00 3635.77 -3840.85 5944267.74 693842.76 70 15 7.735 N 148 26 0.937 W 0.00 3019.29 -3831.98 5943651.74 693867.80 70 15 1.672 N 148 26 0.670 W 0.00 2821.42 -2540.64 5943487.83 695163.82 70 14 59.732 N 148 2523.112 W 0.00 3346.76 -2583.91 5944011.82 695106.78 70 15 4.898 N 148 25 24.376 W 01-19A T3.1 01-19A T3.2 01-19A T3.3 01-19A Polygon3.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 10000.00 10080.00 10406.20 10906.20 11096.20 11216.20 11276.20 8754.87 8823.59 8977 .00 8969.50 8962.52 8947.01 -70.00 TIP KOP 1 2 3 4 TD (;O~paßY:. ',BPArnocó; . 'fi,ld: . ei'tJQ~,~¡¡Y . Site: . pe D$ 01 . .. Well: . 01;;'19. '. . "WeN,at..::' Plan#3.Q1,.:19A. Plan Section Information MD "ft 10000.00 10080.00 1 0406.20 1 0906.20 11096.20 11216.20 11276.20 Survey MD ft 10000.00 10025.00 10050.00 10075.00 10080.00 {Del d~9, 30.50 31.10 90.00 91.56 92.60 102.23 102.23 IItel dßQ 30.50 30.69 30.87 31.06 31.10 AzÎm' deg 326.00 325.20 325.20 265.21 288.00 298.82 306.18 AZi.in .d,eg 326.00 325.75 325.50 325.25 325.20 ) BP Amoco Baker Hughes INTEQ Planning Report ) TVU. ft 8754.87 8823.59 8977.00 8969.50 8962.52 8947.01 8934.28 SSTVO ft 8754.87 8776.39 8797.87 8819.31 8823.59 "1 ' . .i¥Nì~S :, ;ft: 2824.98 2858.77 3081.88 3285.24 3306.94 3353.98 3385.46 , ,N:lS. , . ft ..., 2824.98 2835.51 2846.07 2856.65 2858.77 ---_.----~- INTEQ 'Då.: '~~;,:.~4~QP2(; ,:,.,,~;..'.f)9...~..4;2"'.:' ,.... ...' .;... '... .'. :~; ., .. 'Co;,Ði'd', N~).(~~;". .., W~IÞQ.1719óTr~NQt1h:' ,..,. ',Y~,..,,~).~#.~~~~i:':; .;/;~.;,fiJ1~~:$~(~~Y.~I:.... ~"~~~fer~.-eë;.'..'.' ... ... ,\V~II(~.99f'l~O,..pQ9;,~,09AZi).. . ... ' . S~e,ç"~".tit)1t ~~~ÖcI~. . Miri¡mum'çurvatur~t . .. "Ob: Oracle .+tMw ft' . -2543.01 -2566.15 -2721.22 -3153.14 -3340.51 -3449.47 -3498.88 EIW . ,ft. -2543.01 -2550.14 -2557.37 -2564.68 -2566.15 ,~=~9Of!A"~.~¡i04ft ' 0.00 0.00 0.00 0.91 0.75 -1.00 18.06 18.06 0.00 12.00 0.31 -12.00 12.00 0.55 12.00 12.00 8.02 9.01 12.00 0.01 12.28 ')'FØ: '1'.rg~ .. deS).,... 0.00 325.33 0.00 -88.20 87.00 47.50 89.19 .MapN ft. 5943491.32 5943501.66 5943512.02 5943522.41 5943524.49 .; M.a,t . ft" . 695161.36 695153.94 695146.45 695138.86 695137.33 nu.. , dØ9/1QOft 0.00 0.91 0.91 0.91 0.91 ,vs', .1 3416.09 3426.65 3437.31 3448.05 3450.21 10100.00 34.71 325.20 8840.38 2867.69 -2572.35 5943533.25 695130.90 18.06 3459.30 10125.00 39.23 325.20 8860.35 2880.04 -2580.93 5943545.36 695122.00 18.06 3471.87 10150.00 43.74 325.20 8879.07 2893.63 -2590.38 5943558.70 695112.20 18.06 3485.73 10175.00 48.25 325.20 8896.43 2908.39 -2600.64 5943573.19 695101.56 18.06 3500.77 10200.00 52.77 325.20 8912.33 2924.23 -2611.64 5943588.73 695090.14 18.06 3516.91 2 .TFO.' . Tool , .. q~g 0.00 TIP 325.33 MWD 325.55 MWD 325.77 MWD 325.98 KOP 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 10225.00 57.28 325.20 8926.66 2941.05 -2623.33 5943605.24 695078.02 18.06 3534.05 0.00 MWD 10250.00 61.80 325.20 8939.33 2958.74 -2635.63 5943622.60 695065.26 18.06 3552.07 0.00 MWD 10267.11 64.88 325.20 8947.00 2971.29 -2644.35 5943634.92 695056.21 18.06 3564.87 360.00 01-19A 10275.00 66.31 325.20 8950.26 2977.19 -2648.45 5943640.71 695051.96 18.06 3570.88 0.00 MWD 10300.00 70.82 325.20 8959.39 2996.30 -2661.73 5943659.46 695038.18 18.06 3590.35 0.00 MWD 10318.65 74.19 325.20 8965.00 3010.90 -2671.88 5943673.79 695027.65 18.06 3605.23 0.00 01-19A 10325.00 75.34 325.20 8966.67 3015.93 -2675.38 5943678.73 695024.03 18.06 3610.36 360.00 MWD 10350.00 79.85 325.20 8972.04 3035.98 -2689.31 5943698.40 695009.57 18.06 3630.78 0.00 MWD 10375.00 84.37 325.20 8975.47 3056.31 -2703.44 5943718.35 694994.92 18.06 3651.50 0.00 MWD 10400.00 88.88 325.20 8976.94 3076.79 -2717.68 5943738.45 694980.15 18.06 3672.37 0.00 MWD 10406.20 90.00 325.20 8977.00 3081.88 -2721.22 5943743.45 694976.48 18.06 3677.56 0.00 1 10425.00 90.07 322.94 8976.99 3097.11 -2732.25 5943758.38 694965.05 12.00 3693.49 271.80 MWD 10450.00 90.16 319.95 8976.94 3116.66 -2747.83 5943777.51 694948.96 12.00 3715.26 271.80 MWD 10475.00 90.26 316.95 8976.84 3135.36 -2764.41 5943795.77 694931.90 12.00 3737.64 271.79 MWD 10500.00 90.35 313.95 8976.71 3153.17 -2781.94 5943813.12 694913.90 12.00 3760.57 271.78 MWD 10525.00 90.44 310.95 8976.54 3170.05 -2800.39 5943829.50 694895.02 12.00 3783.99 271.77 MWD 10550.00 90.53 307.95 8976.32 3185.93 -2819.69 5943844.87 694875.31 12.00 3807.84 271.74 MWD 10575.00 90.62 304.95 8976.07 3200.78 -2839.80 5943859.19 694854.83 12.00 3832.05 271.72 MWD 10600.00 90.71 301.95 8975.78 3214.56 -2860.65 5943872.41 694833.62 12.00 3856.54 271.69 MWD 10625.00 90.80 298.96 8975.45 3227.23 -2882.20 5943884.51 694811.75 12.00 3881.27 271.65 MWD 10650.00 90.88 295.96 8975.09 3238.75 -2904.38 5943895.45 694789.27 12.00 3906.15 271.61 MWD 10675.00 90.96 292.96 8974.69 3249.10 -2927.13 5943905.19 694766.26 12.00 3931.12 271.57 MWD 10700.00 91.04 289.96 8974.25 3258.24 -2950.39 5943913.72 694742.77 12.00 3956.11 271.52 MWD 10725.00 91.11 286.96 8973.78 3266.15 -2974.10 5943921.01 694718.86 12.00 3981.06 271.47 MWD 10750.00 91.19 283.96 8973.28 3272.82 -2998.18 5943927.04 694694.61 12.00 4005.89 271.41 MWD 10775.00 91.26 280.96 8972.74 3278.21 -3022.59 5943931.79 694670.08 12.00 4030.53 271.35 MWD 10800.00 91.32 277.96 8972.18 3282.31 -3047.24 5943935.24 694645.33 12.00 4054.93 271.29 MWD 10825.00 91.38 274.96 8971.59 3285.12 -3072.07 5943937.40 694620.43 12.00 4079.00 271.22 MWD 10850.00 91.44 271.96 8970.97 3286.63 -3097.01 5943938.25 694595.46 12.00 4102.69 271.15 MWD 10875.00 91.50 268.96 8970.33 3286.83 -3122.00 5943937.80 694570.47 12.00 4125.94 271.08 MWD 10900.00 91.55 265.96 8969.67 3285.72 -3146.96 5943936.03 694545.55 12.00 4148.67 271.00 MWD 10906.20 91.56 265.21 8969.50 3285.24 -3153.14 5943935.40 694539.39 12.00 4154.22 270.92 2 10925.00 91.68 267.47 8968.97 3284.05 -3171.90 5943933.70 694520.67 12.00 4171.16 87.00 MWD BP Amoco Baker Hughes INTEQ Planning Report ) ~) ... -_. ...,.....11. INTR.Q" ' cø.....y;:'{)'Affløçø '. . . . Fiêtdf .,. ." P~~y . Sité: . . PBDS:01 '" ' WeU( ..;o;1:~19'<:. " " . . W~'Îj.jlt~ :. PI~ri#$.b1.;.1$A. Survey .' . .I!".I~:. .".. . :3. , . " , , .:OnïClêi 12.00 11000.00 92.11 276.46 8966.49 3286.61 -3246.73 5943934.30 694445.80 12.00 4241.51 87.25 MWD 11025.00 92.25 279.46 8965.53 3290.07 -3271.47 5943937.11 694420.98 12.00 4265.74 87.36 MWD 11050.00 92.38 282.46 8964.52 3294.82 -3295.99 5943941.22 694396.34 12.00 4290.25 87.48 MWD 11075.00 92.50 285.46 8963.46 3300.84 -3320.23 5943946.60 694371.96 12.00 4314.98 87.60 MWD 11096.20 92.60 288.00 8962.52 3306.94 -3340.51 5943952.16 694351.53 12.00 4336.07 87.72 3 11100.00 92.91 288.34 8962.33 3308.12 -3344.12 5943953.25 694347.89 12.00 4339.86 47.50 MWD 11125.00 94.93 290.56 8960.62 3316.43 -3367.63 5943960.94 694324.16 12.00 4364.77 47.52 MWD 11150.00 96.95 292.79 8958.04 3325.61 -3390.74 5943969.51 694300.83 12.00 4389.63 47.67 MWD 11175.00 98.95 295.05 8954.58 3335.65 -3413.37 5943978.95 694277.94 12.00 4414.38 47.90 MWD 11200.00 100.94 297.33 8950.26 3346.51 -3435.46 5943989.23 694255.57 12.00 4438.93 48.21 MWD 11216.20 102.23 298.82 8947.01 3353.98 -3449.47 5943996.33 694241.38 12.00 4454.71 48.60 4 11225.00 102.24 299.90 8945.14 3358.19 -3456.96 5944000.35 694233.77 12.00 4463.24 89.19 MWD 11250.00 102.25 302.97 8939.84 3370.93 -3477.81 5944012.53 694212.61 12.00 4487.34 89.41 MWD 11275.00 102.23 306.04 8934.54 3384.77 -3497.94 5944025.84 694192.12 12.00 4511.19 90.07 MWD 11276.20 102.23 306.18 8934.28 3385.46 -3498.88 5944026.50 694191.16 12.00 4512.32 90.72 TD BP Amoco P_tw._"" Tie OIl ., WIIu..ATH DIITAlLI 'IIna OHM _2_f Of-fl fOOlO.OO II. lief. 118"'.... S1.1811M'111e:1 00.00 70.- v.-..:=: ~ = J::"'~ 282.00- 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate ~IE! Reference: Wen Centre: 01-19. Tl\Je North v~;~ (Vg ~:~;::: ~r:~9 ~~g~~eI Measured Depth Reference: 31 : 198/241196200:00 10.00 Ca/aJlation Method: MI..rmm Curvature ucnON DÐ'AfL8 tee MD ,"C Ad 1VD +H14 +8J.W DLeI TP~ Y8ec T8fPt , '. ".80 -..00 """'87 -.... 4_'" 0.00 0.00 ,.- . f .00 11.11 Jao.ao ..81.. ._.77 4_.fl 0." aun I4IOJOf ¡ i ~ e¡ E iSi¡ æi! fliff iiE is iiE! , ;::::::: ::UI 11.1: :=:= III:::: ::=::: :~= :::n ::r-an A_AnONI TVD .-- IT- 10000.0o np _.. 1!M!!-!!! KelP =:l1¡¡¡¡;:¡¡ : _.11 1- a _.Of 11111.10 4 .10.00 111- TD (lHMf31 01-1&\ T31 01.1~T33 Ot.1W\.Po:~31 1\V ftl!.S .uw Sfwpo 897100 3143."~ -7166JO PoinI ~IX) 330M6 -J3..tt2'f PoVt £:94700 ~2i) -Mot1S) PM 000 3e55 17 ..3ß4(Uj/j ~ 8400' 8450. _8550- c: i 86oo'~ 1!!.8650- ~. i 8700=- ca. - .. : a 8750- . ø 8800-: ! : .. 885O-~ > :' .. 8900'- i! - ... 8950- 9000 9100 9150 I I I I II I I I i ì ~ I I ì i I I ì II Ii ¡ ¡ ~ í I 3200 3250 3300 3350 3400 bp _.11 ... T ^M é LEGEND - gt~!~¡ - 05-06A (05-06A) - 05-08 (05-08) 05-41 (05-41) - Plan#301-19A -- Plan #3 Azimuths to True North Plan: Plan #3 (01.19JPlan#3 01-19A) Magnetic North: 26.58. Created By: Brij Potois Date: 1128/2002 Stre~:~~~~~fÅ~~ Contact Information: Dip Angle: 80.80. Oirect: (907) 261.6613 MJ~~e~ó'J~gg1 Baker Hughes I~Trw~: ?~Mo2~o/!Jg~q.com INT~Q 2800 - 2700 ~. : ~. . !: :: ! .' : . ¡. ¡ ¡.'. ¡ ¡.. ¡ , ... :. i. :. . ! .',: . ¡ .. .1. .. . i... j -11111111[111111111111111"1111"1111111111111111111111111111111I ill 11111 ill "111 III 11111 1 1IIIIIf 1"1"1 1"" Iii lillll 11111"11111 -4300 -4200 -41 00 -4000-3900 -3800 -3700 -3600-3500 -3400 -3300 -3200 -31 00 -3000 -2900 -2800-2700-2600 -2500 -2400 -2300 -2200 -2100-2000-1900 -1800 -1700 West(-)/East(+) [100ft/ln] . ...' '. :,.. .1.[1'. I . ..i . ¡i. ,I,: ~i.. i!,,-~,: ¡, i ì ¡ 1I111 i I i II 1 i i I I 11111 i 1111I11 1111111111 i Ii I ì Iii I Ii I i I i III í 11I1 ì III i III Ii i i ì Iii I ¡Iii 11I1I1 ì ill i i i i III 3850 395040004050 4100 4150 4200 4250430043504400 4450 4500 4550 4600 4650 4700 47504800 4850 Vertical Section at 292.00. [50ft/in] 1/28/2002 9:22 AM ,--" ~ Well # 01-19A) ') Date 1-30-200¿ All Measurements are from top of Riser 1/30/2002 24.7' from top of floor to rig mats 21.8' of room under floor to rig mats s- (I) en .- a:: Flanae to Flange Heiahts top of bag 7" otis x-a .70' BAG 2.80' bttm of bag Blind/Shears / ...........,............ middle of slips I I TOTs 1.90' 2-3/8" pipe/slips / ~/"'''''''''''''''' middle of pipes --, r--' Mud Cross Mud Cross 1.70' middle of flow cross --- '-- 3-1/2" pipe/slips .l ...,.....,.,........,. middle of blind/shears TOTs 1.90' 2-3/8 X 3.5 Var. pipe '/ _.........-",./-- middle of pipe/slips middle of master .. Tubing spool adapter ... Lock down screws Tubing Spool Rig mats ,'. '>-'-"'.. ) ) 204436 DATE 01/17/02 CHECK NO. 00204436 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 111602 CK011602C PYMT ~OMMENTS: HANDLING INST: 100.00 100.00 H Per~it to Drill 7ee S/H - Terrie HubJle X4628 01. \ 0, A- RECEIVED FEB 0 .~ 2002 Alaska Oil & Gis Corè. ('~--' . Anchorape \NIn~lOn "-TTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND ANAFFIUATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 204436 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 412 00204436 JAY ONE HUNDRED ~-( 00/100************************************* US DOLLAR DATE 01/17/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 ¡Q '~\. . .. ~? 4.lþ.il . ~-~ 6.~; < ~# I ~.' Æ. /\A~ --~ III 2 0 ~ ~ ~ b III I: 0 ~ . 2 0 ~ a g 5 I: 00 a ~ I. . g III ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVEL.O[MENT /.PMENT ' REDRILL V ' EXPLORA TION INJECTION WELL INJECTION WELL REDRILL WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) Pll..,OT HOLE (PH) ANNULAR DISPOSAL . <--J.NO V ANNULAR DISPOSAL L-> YES ANNULAR DISPOSAL THIS WELL. (l]t,{ () /~ /9 /1- "CLUE" Tbe permit is for a new wellbore segment of existing well ~ Permit No, ,API No. . '. Production should continue to be reported as a function of tbe original API number stated above. ' In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be dearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (na,me on permit). , Annular disposal bas not been requested... Annular Disposal of drilling wastes will not be approved. .. Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated. .. . ANNULUS L-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. Tbe permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to tbe spacing exception tbat may occur. WELL PERMIT CHECKLIST COMPANY ~-P)(. WELL NAME PAt( ò/.., /9/l FIELD & POOL 6t/0/t:.e:;{) INITCLASS ~J /Olt- ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. ., . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . y, N 11. Permit can be issued without conservation order. . . . . . . . N AP~ DATE. V 12. Permit ca~ be issued without administrativ~ approval.. . . . . N ß Y 1,.. -[ .[") 13. Can permIt be approved before 15-day walt.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥--N-/IlI1\ L~ J . 15. Surface casing protects all known USDWs. . . . . . . . . . . AlÆ ¥-N ~;r;I( t ,~/$-.h'k.s ~f- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . -Y N Ai/A 17. CMT vol adequate to tie-in long string to surf csg. . . . . . ..¥-N- '6 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N kkqc.ül--'b 1J..LC.pI.;.Ç. ce"K.~. 19. Casing designs adequate for C, T, B & permafrost. . . . . . . æ N 1J 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . VN C-TDt.L 21. If a re-drill, has a 10-403 for abandonment been approved. . . Ð N 3 V 2.. - 0 £/-'6 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ¥--'"fr MIA 23. If diverter required, does it meet regulations. . . . . . . . . . -¥--N-"" 24. Drilling fluid program schema~ic & equip list adequate. . . . . ~ N 25. BOPEs, do they meet regulatIon. . . . . . . . . . . . . . . . fj} N . 26. BOPE press rating appropriate; test to 3500 psig. Y N. M"A-5P =: l4'U/ pY¿ . ~TU f~$, fë~ t. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . {[(N 28. Work will occur without operation shutdown. . . . . . . . . . . (f2 N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . f!) N Çæ.. I'J..efo-{.U..:t 30. Permit can be issuedwlo hydrogen sulfide measures. . . . . y(1t) /S/~~~ ~S A../4-<) ~~J ~ ðl'-c~7 31. Data presented on potential overpressure zones. . . . . . . Y ß v (/ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. . rA ~ N Aft. P. DATE 33. Seabed condltton survey (If off-shore). . . . . . . . . . . . ~ Y N - Z .7. ØZ- 34. Contact namelphone for weekly progress reports [explopdÓry only] Y N c ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: TEM &~ ~ WGA }¡.JtiÆ APf~ DA 1E W"?'\ l.J7{¿, L t;1Wt ~/,.ð' GEOLOGY APPR DATE Y N Y N RPC- SFD- COT DTS ;Ll~ JMH IN \-t 2l3/02- G:\geology\templates\checklist.doc PROGRAM: Exp - Dev ~ Redrll ~~erv - Wellbore seg - Ann. disposal para req - GEOL AREA 7!, c¡ D UNIT# () I / ~.Ç{) ON/OFF SHORE Dn '-"'- ~/~ ) ¡Jo CìM.lUcta-v J1s/z.vS~( v-p~Ç.-:RJ. Comments/Instructions: ) ') Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting 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 APPEN.DIX. No special effort has been made to chronologically. . organize this category of information. ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 01 11:34:01 2003 Reel Header Service name............ .LISTPE Date.....................03/04/01 Origin...................STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Narne.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date. . . . . . . . . . . . . . . .. . . . . 031 041 01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: IAIri ting Library. ) Scientific Technical Services Writing Library. Scientific Technical Services MWD RUN 1 AK-MW-22177 M. ALLEN EGBEJIMBA MWD RUN 4 AK-MW-22I77 M. ALLEN EGBEJIMBA MSL 0) 1-19A 500292080001 BP Exploration Sperry Sun 01-APR-03 MWD RUN 2 AK-MW-22177 M. ALLEN EGBEJIMBA MWD RUN 5 AK-MW-22I77 M. ALLEN EGBEJIMBA 8 ION 15E 165 462 70.00 .00 .00 (Alaska) Inc. MWD RUN 3 AK-MW-22177 M. ALLEN EGBEJIMBA OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9384.0 aoa-õ~ ~ I/(Phl ') 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 OFF OF .r::... WHIPSTOCK, THE TOP OF WHICH WAS AT ABOUT 9830'MD 1 8609'TVDSS IN THE 1-19 WELLBORE. 4. MWD RUNS 1- 2 COMPRISED DIRECTIONAL viJITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE TIE-IN DATA (SGRC) ARE INCLUDED IN RUN 1. 5. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. LOG AND MERGED DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER WIRELINE GAMMA RAY LOG ACQUIRED IN THE 1-19A WELLBORE ON 06 NOVEMBER 2002. LOG HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. THESE DATA WERE PROVIDED BY D. SCHNORR, BP EXPLORATION (ALASKA), INC., ON 02/06/03. 7. MWD RUNS 1 - 5 REPRESENT WELL 1-19A WITH API#: 50-029-20800-01. THIS WELL REACHED A TOTAL DEPTH ('I'D) OF 11584'MD 1 8940'TVDSS. SROP = SGRC = SEXP = SESP = SEMP = SEDP = SFXE = $ SMOOTHED SMOOTHED SMOOTHED SMOOTHED SMOOTHED SMOOTHED SMOOTHED RATE OF PENETRATION WHILE DRILLING. GAMMA RAY COMBINED. PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISTIVITY PHASE SHIFT DERIVED RESISTIVITY FORMATION EXPOSURE TIME (EXTRA SHALLOW SPACING) (SHALLOW SPACING) (MEDIUM SPACING) (DEEP SPACING) File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/04/01 Haximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUHBER: EDITED HERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SU)V[JV!ARY PBU TOOL CODE GR ROP FET RPD RPH RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 9752.5 9844.5 10064.5 10064.5 10064.5 10064.5 10064.5 STOP DEPTH 11539.0 11583.5 11552.5 11552.5 11552.5 11552.5 11552.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 9752.5 9754.5 9759.0 9765.5 9768.5 9771.0 9779.0 9781.5 9826.0 9830.5 DEPTH GR 9752.5 9754.5 9758.5 9764.5 9767.5 9770.5 9777.0 9780.5 9824.5 9828.0 ') 9832.0 9835.5 9841.5 9843.0 9846.0 9850.5 9855.5 9858.5 9864.0 9866.0 9868.5 9871.0 9876.0 9883.5 9898.0 9902.0 9904.5 9907.5 9913.5 9928.5 9934.0 9936.5 9939.5 9944.5 9950.5 9965.5 9968.0 9974.5 9983.5 9985.0 9988.5 9994.0 9996.0 10005.0 10028.5 10035.0 10039.0 10056.0 10058.0 10062.5 10066.5 10069.0 10071.0 10074.5 10078.0 10081.0 10105.0 10107.0 10121. 0 10127.0 10139.0 10140.5 10153.5 10160.0 10162.0 10164.5 10168.5 10171.5 10174.0 10177.0 10181.0 10184.5 10187.5 10190.0 10198.0 10202.5 10204.5 10207.0 10208.5 10214.0 10219.5 10224.0 10227.5 10231.5 10236.0 9830.5 9834.0 9839.5 9842.0 9844.5 9848.0 9853.0 9856.5 9862.5 9864.5 9868.0 9870.0 9874.5 9881. 5 9896.0 9899.5 9903.0 9906.0 9912.0 9927.5 9933.0 9935.5 9938.0 9942.5 9949.0 9965.5 9968.5 9975.0 9984.5 9986.0 9989.5 9995.5 9998.0 10007.5 10030.5 10035.5 10039.5 10055.5 10058.5 10063.0 10066.0 10068.0 10070.5 10074.0 10076.5 10080.0 10104.0 10105.5 10119.0 10125.5 10137.5 10139.5 10152.5 10157.5 10159.5 10164.0 10167.5 10170.5 10172.5 10174.5 10178.5 10182.5 10186.0 10188.0 10196.5 10200.5 10202.5 10204.5 10206.0 10211. 5 10217.5 10222.0 10225.5 10229.5 10235.0 10240.0 10242.0 10247.5 10250.0 10253.0 10254.0 10257.5 10261. 5 10264.0 10266.5 10274.0 10277.0 10280.5 10281.5 10285.5 10288.5 10292.0 10295.0 10299.5 10303.0 10305.0 10311. 5 10313.5 10315.0 10316.0 10317.0 10321. 0 10325.5 10329.5 10333.5 10337.5 10339.0 10344.0 10346.0 10347.0 10350.0 10352.5 10357.0 10359.0 10366.0 10368.5 10377.0 10379.0 10382.5 10384.5 10389.5 10397.0 10400.0 10404.0 10408.5 10416.0 10421. 5 10432.5 10434.0 10437.5 10443.0 10447.0 10453.0 10458.5 10464.0 10465.5 10467.5 10469.5 10472.0 10473.0 10476.0 10477.0 10478.0 10482.0 10487.0 10493.0 10495.5 10499.5 10508.0 10509.5 ') ) 10238.5 10240.0 10244.5 10247.5 10251. 0 10252.5 10255.0 10258.5 10261.5 10264.5 10271.5 10273.5 10277.5 10279.5 10283.0 10285.0 10289.0 10292.0 10298.0 10301. 0 10302.5 10309.0 10310.5 10311.5 10313.5 10314.5 10318.5 10323.0 10327 . 0 10330.5 10333.5 10336.0 10340.5 10342.5 10343.5 10346.5 10350.0 10353.5 10356.5 10362.5 10364.0 10373.0 10375.5 10378.5 10381.5 10387.5 10396.0 10399.5 10403.5 10407.0 10414.5 10420.0 10430.0 10432.0 10435.5 10440.5 10444.5 10450.5 10455.5 10460.5 10463.0 10464.5 10467.0 10469.5 10472.0 10474.5 10475.5 10476.5 10481.5 10486.5 10491.5 10494.5 10498.0 10507.5 10508.5 10510.5 10515.5 10518.5 10522.0 10524.5 10532.0 10538.5 10541. 5 10543.5 10547.5 10554.0 10555.5 10565.5 10581.0 10596.0 10601.5 10604.5 10610.0 10623.0 10630.5 10635.5 10639.5 10646.0 10647.0 10655.5 10658.0 10663.5 10671.5 10674.0 10678.0 10681.5 10719.5 10724.0 10728.5 10738.5 10748.5 10749.5 10763.5 10765.0 10766.5 10768.5 10773.0 10778.0 10780.5 10782.0 10785.0 10787.5 10793.5 10794.5 10806.0 10841.0 10845.5 10867.0 10870.5 10876.5 10888.0 10905.0 10921.0 10923.0 10937.0 10940.5 10943.5 10946.0 10947.5 10959.0 10964.0 10979.0 10983.5 10996.0 11005.5 11011.5 11015.0 11020.0 11026.5 11033.0 ') ) 10510.5 10517 . 0 10519.5 10523.0 10525.0 10533.0 10540.0 10543.0 10544.5 10548.5 10555.0 10557.5 10567.0 10583.0 10595.5 10600.0 10603.5 10608.0 10620.5 10629.0 10633.5 10636.5 10643.0 10644.5 10653.0 10655.5 10660.5 10668.0 10670.5 10675.0 10678.0 10714.5 10720.0 10725.5 10734.5 10744.0 10746.0 10759.0 10760.5 10762.5 10764.0 10769.0 10773.5 10776.0 10777.5 10779.5 10781.5 10787.5 10790.0 10801.0 10836.0 10840.5 10864.0 10867.0 10874.0 10886.5 10903.5 10919.5 10921. 0 10935.0 10939.5 10941. 5 10944.5 10946.0 10955.0 10960.5 10975.5 10980.0 10992.5 11002.0 11008.5 11011. 0 11015.5 11022.0 11029.0 11042.0 11047.5 11053.5 11059.5 11068.0 11071.5 11074.5 11083.0 11086.5 11092.5 11096.5 11105.5 11108.0 11109.5 11114.5 11120.0 11126.0 11129.0 11135.0 11146.5 11152.5 11154.0 11163.0 11182.0 11191. 5 11199.0 11203.0 11207.0 11213.5 11221.5 11227.0 11231.5 11244.0 11245.5 11250.5 11253.0 11263.0 11267.0 11268.0 11270.0 11274.5 11283.5 11287.5 11290.5 11304.0 11306.5 11309.0 11313.0 11320.5 11332.0 11339.5 11356.5 11392.0 11397.5 11401.5 11407.5 11420.5 11446.5 11452.0 11494.0 11505.0 11516.0 11523.5 11584.0 $ # MERGED PBU MWD MWD MWD HWD l'1'JilD $ DATA SOURCE TOOL CODE it "') 11038.0 11043.5 11048.5 11054.0 11063.0 11065.5 11069.0 11077.5 11081.5 11089.0 11092.5 11101.5 11102.5 11104.0 11110.0 11115.5 11121.0 11125.0 11131. 0 11142.5 11149.5 11151.5 11160.5 11180.0 11188.5 11195.5 11199.5 11204.5 11211.0 11219.0 11224.5 11230.0 11242.0 11244.0 11249.5 11251.5 11262.0 11265.5 11266.5 11268.0 11273.5 11285.0 11289.5 11293.0 11306.0 11309.0 11311.5 11314.5 11323.0 11335.5 11342.0 11358.0 11388.0 11393.5 11398.0 11405.0 11419.0 11443.5 11448.5 11491.5 11502.0 11513.0 11523.0 11583.5 BIT RUN NO 1 2 3 4 5 MERGE TOP 9752.5 9964.5 10051. 0 10474.5 10956.0 ) MERGE BASE 9993.0 10094.5 10519.0 11001. 0 11583.5 ') ) RElv1ARKS : MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................50 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units........... . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 58 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMl'1 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9752.5 11583.5 10668 3663 9752.5 11583.5 ROP MWD FT/H 0.04 2385.26 94.0842 3479 9844.5 11583.5 GR MWD API 17.69 213.12 35.5893 3494 9752.5 11539 RPX MWD OHMM 3.3 78.74 17.3598 2977 10064.5 11552.5 RPS MWD OHMM 3.42 90.8 19.45 2977 10064.5 11552.5 RPIvl H1iiD OHMM 3.42 85.57 19.7883 2977 10064.5 11552.5 RPD MWD OHMM 3.71 63.23 18.6919 2977 10064.5 11552.5 FET MWD HOUR 0.19 8.24 1.21601 2977 10064.5 11552.5 First Reading For Entire File..........9752.5 Last Reading For Entire File...........11583.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/04/01 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.......03/04/01 Haximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE. HE.ADE.R FILE NUMBER: RAW NWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE. SUMMl\RY VENDOR TOOL CODE START DEPTH 2 1 .5000 STOP DEPTH ') GR ROP $ 9752.5 9844.5 9964.0 9993.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPH): HOLE INCLINATION (DEG HINIHUM }\NGLE: :MAXIMUH ANGLE: # TOOL STRING (TOP TO BOTTOH) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPH): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEHPERATURE (DEGF) MUD AT MEASURED TEHPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT HT: MUD CAKE AT Jv1T: # NEUTRON TOOL :MATRIX: :MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # RE:MARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 03-NOV-02 Insite 4.3 Hemory 9992.0 9752.0 9992.0 27.8 37.0 TOOL NUMBER 82758 3.750 9384.0 Flo Pro 8.70 65.0 9.0 24000 6.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWDOIO API 4 1 68 8 3 ) .0 127.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9752.5 9993 9872.75 482 9752.5 9993 ROP MWD010 FT/H 0.04 2385.26 139.415 298 9844.5 9993 GR MiiiID010 API 22.65 213.12 46.5321 345 9752.5 9964 ) First Reading For Entire File..........9752.5 Last Reading For Entire File...........9993 File Trailer Service name... ..........STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/04/01 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...........l.O.O Date of Generation.......03/04/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 9964.5 9992.5 STOP DEPTH 10067.0 10094.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OH~~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT ~~ CIRCULATING TERMPERATURE: 03-NOV-02 Insite 4.3 Memory 10095.0 9992.0 10095.0 31.0 39.1 TOOL NUMBER 82758 3.750 9384.0 FIo Pro 8.70 65.0 9.0 24000 6.2 .000 .000 .0 137.9 ) ) MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .0 .0 # NEUTRON TOOL NATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1. FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9964.5 10094.5 10029.5 261 9964.5 10094.5 ROP MWD020 FT/H 2.73 352.39 35.5424 205 9992.5 10094.5 GR MWD020 API 19.63 118.61 33.0156 206 9964.5 10067 First Reading For Entire File..........9964.5 Last Reading For Entire File...........l0094.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/04/01 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.......03/04/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW ¡"fwD Curves and log BIT RUN NUMBER: DEPTH INCRE!v1ENT: # FILE SUMMARY 4 header data for each bit run in separate files. 3 .5000 ) VENDOR GR RPS FET RPD RPX RPM ROP $ START DEPTH 10051.0 10064.5 10064.5 10064.5 10064.5 10064.5 10095.0 STOP DEPTH 10474.0 10487.5 10487.5 10487.5 10487.5 10487.5 10519.0 TOOL CODE # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMU}1 ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: HUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MTì: MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined ,Zlbsent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O -) 04-NOV-02 Insite 4.3 Memory 10519.0 10095.0 10519.0 48.3 93.9 TOOL NUMBER 69706 125631 3.750 9384.0 Flo Pro 8.80 65.0 8.8 24000 5.8 .060 .030 .140 .120 72.0 134.4 72.0 72.0 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 .") GR MWD030 API 4 1 68 8 ~ RPX MWD030 OHt1M 4 1 68 12 ) ) RPS JvIWD030 RPM JvIWD030 RPD JvIWD030 FET JvIWD030 OHMM OHMM OHMM HOUR 4 4 4 4 1 68 1 68 1 68 1 68 16 20 24 28 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10051 10519 10285 937 10051 10519 ROP JvIWD030 FT/H 0.54 2165.49 72.4095 849 10095 10519 GR MlliJDO 3 0 API 18.13 194 45.3409 847 10051 10474 RPX MWD030 OHMM 3.3 78.74 21. 9974 847 10064.5 10487.5 RPS MWD030 OHMM 3.42 90.8 25.8039 847 10064.5 10487.5 RPM MWD030 OHMM 3.42 85.57 26.3896 847 10064.5 10487.5 RPD MWD030 OHMM 3.71 63..23 24.1184 847 10064.5 10487.5 FET MWD030 HOUR 0.3 8.24 1.33387 847 10064.5 10487.5 First Reading For Entire File..-.-_.._.l00S1 Last Reading For Entire File...........l0519 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...... -... .1.0.0 Date of Generation.......03/04/01 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.......03/04/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DE PTH INCREMEN'l': # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM FET RPD ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10474.5 10488.0 10488.0 10488.0 10488.0 10488.0 10519.5 STOP DEPTH 10955.5 10969.5 10969.5 10969.5 10969.5 10969.5 11001.0 # LOG HEADER DATA DATE LOGGED: SOFTí^lARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 04-NOV-02 Insite 4.3 Memory 1000.0 10519.0 11000.0 ') MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TY PE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (.8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT ME.ASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORREC'rION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REJv1ARKS : $ # Data Format Specification Record Dat.a Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units........ . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 86.9 94.7 TOOL NUMBER 69706 125631 3.750 9384.0 Flo Pro 8.70 65.0 9.0 24000 9.6 .130 .070 .140 .120 Name Service Order Units Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit DE PT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR Min 10474.5 2.17 19.32 3.41 3.7 3.88 4.65 0.26 Max 11001 1206.96 89.71 20.91 19.64 21 20.74 6.82 First Reading For Entire File..........10474.5 Last Reading For Entire File...........11001 Mean 10737.8 89.2989 30.4371 7.49226 8.63615 9.20202 9.7514 1.1117 9 Nsam 1054 964 963 964 964 964 964 964 ) 75.0 138.2 75.0 75.0 First Reading 10474.5 10519.5 10474.5 10488 10488 10488 10488 10488 Last Reading 11001 11001 10955.5 10969.5 10969.5 10969.5 10969.5 10969.5 ') File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number... . . . . . . . .1. 0.0 Date of Generation.......03/04/01 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............. STSLIB. 006 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .03/04/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 6 ') header data for each bit run in separate files. 5 .5000 START DEPTH 10956.0 10969.0 10969.0 10969.0 10969.0 10969.0 11001.5 # LOG HEADER Dl\TA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ STOP DEPTH 11538.5 11552.0 11552.0 11552.0 11552.0 11552.0 11583.5 05-NOV-02 Insite 4.3 Memory 11584.0 11000.0 11584.0 84.1 101. 2 BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 69706 125631 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT 3.750 9384.0 Flo Pro 8.80 65.0 8.5 24000 7.6 TEMPERATURE (DEGF) ) ) MUD AT MEASURED TEMPERATURE (lVIT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .080 .040 .250 .180 72.0 144.9 72.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REJ'.1ARKS : $ # Data Format Specification Record Data Record TY'Pe.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .lIN lVIax frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP tvIWD050 FT/H 4 1 68 4 2 GR lVIWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM lVIWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET lVIWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10956 11583.5 11269.8 1256 10956 11583.5 ROP MWD050 FT/H 0.56 2297.63 112.537 1165 11001.5 11583.5 GR HWD050 API 17.69 82.58 29.8956 1166 10956 11538.5 RPX HWD050 OHMM 5.94 62.09 22.2299 1167 10969 11552 RPS lVIWD050 OHMM 6.57 58.33 23.8443 1167 10969 11552 RPH lVIWD050 OHMM 6.76 51. 89 23.7956 1167 10969 11552 RPD MWD050 OHMM 7.66 38.17 22.1669 1167 10969 11552 FET lVIWD050 HOUR 0.19 6.36 1. 25561 1167 10969 11552 First Reading For Entire File..........10956 Last Reading For Entire File...........11583.5 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/04/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...._......STSLIB.007 Physical EOF Tape Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol ) ') Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service narne.............LISTPE Date.....................03/04/01 Origin...................STS Reel Narne................UNKNOWN Continuation Nun~er......Ol Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOr Physical EOF End Of LIS File