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Home My WebLink About204-157 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d-Û 4: - 1 5 '1 Well History File Identifier D Two-sided III" 1/1111111/11/1 Organizing (done) D Rescan Needed 1111111111111111111 RES CAN ~olor Items: ~reYSCale Items: \ p~ D Poor Quality Originals: DIGITAL DATA ~iskettesJ No. , D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: Date II j {Lf/Ó(P Date [I ¡ '+/ {] ~ ~ x 30 = &tJ Datet I{ ¡ Y-/00 D Other:: BY: ~ /s/ YVvP IIIIIIIIIIII~ II1II Project Proofing BY: ~ /s/ mp BY: ~ + 17 = TOTAL PAGES 7 7 (Count does not include cover sheet) 11\ A f) /s/ r V W' Scanning Preparation ProducOonScanning Stage 1 Page Count from Scanned File: r¡ Z5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~YES ~ Date:'} (f~/00 If NO in stage 1, page(s) discrepancies were found: 111111111111111111I BY: /s/ NO Mf NO Stage 1 YES BY: Maria Date: /s/ 111/1111I111111111I Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • ~_ 3:. ~ -< ~,' i MICROFILMED 03/01/2008 a. ~- ~.~ sup, ~; ~, .._ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc • STATE OF ALASKA ,,..y, __ _ _. ALASKA OIL AND GAS CONSERVATION COM~SSION ~`°~`-' ~~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG CEP ~ ~ 2007 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b.` ~ ~ 2S OI15. _ OfhmlySlO ®Developrtas~~~~c~loratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/14/2007 12. Permit to Drill Number 204-157 - 307-206 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/24/2004 13. API Number 50-029-20448-02-00 ~ 4a. Location of Well (Governmental Section): Surface: 807' EW 4948' NSL T11 N S C 36 R 7. Date T.D. Reached 9/30/2004 14. Well Name and Number: PBU 02-166 , , 14E, UM _ L, E . , Top of Productive Horizon: 3311' NSL, 3976' WEL, SEC. 26, T11 N, R14E, UM 8. KB (ft above MSL): 58.76' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4967' NSL, 52' WEL, SEC. 27, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11307 8915 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687542 y- 5950868 Zone- ASP4 10. Total Depth (MD+TVD) 13685 - 8864 - 16. Property Designation: ADL 028308 TPI: x- 682667 y- 5954392 Zone- ASP4 Total Depth: x- 681270 y- 5956014 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR / ROP, MGR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD `SETTING DEPTH TVD HALE AMOUNT WT. PER FT. GRADE -TOP .BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 98' Surface 98' 32" 431 sx Permafrost 13-3/8" 72# N-80 Surface 3029' Surface 2676' 17-1/2" 2500 sx Fondu 400 sx PF'C' 9-5/8" 47# L-80 / S00 Surface 9450' Surface 7447' 12-1 /4" 1965 sx Class 'G' 300 sx PF 'C' 7-5/8" x 7" 29.7# / 29# NT-80 ! 13Cr 8454' 1 4' 6616' 8792' 9-518" X a-vz~~ 3$0 sx Class 'G' 3-112" x 33116" x 2-7J6" 8.6,# / 6.2# / 6.16# L-80 10790' 13628' 8671' 8872' 4-1 J6" x 33f4" 145 sx Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24:' TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, L-80 10922' 10766' MD TVD MD TVD ` , 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~~~~ ~~ ~ ~ 2~~7 v DEPTH INTERVAL MD AMOUNT $e KIND OF MATERIAL USED 11770' Set WFD CIBP (06/15!06) 11307' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED Z4-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ 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. c COMPLETION None ,~ ~~:: ~~!~ ~ ~ ~~J~~ ~D Form 10-407 Revised 02/2007 o D ~ r ~ ~ ~~TINUED ON REVERSE SIDE /~_ ~~ 1~ /~ ~. /~ 28. GEOLOGIC MARKERS LIST ALL FORMATIONS A KERB ENCOUNTERED: 29. FORMATION TESTS NAME MD TVD Well Teste ^ 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. Sag River 10359' 8285' None Shublik A 10402' 8324' Shublik B 10422' 8342' Shublik C 10428' 8347' Shublik D 10478' 8393' 45S6 10491' 8404' 42S6 10574' 8479' Top CGL 10648' 8545' Base CGL 10726' 8615' 23S6 10815' 8692' 22TS 10867' 8732' 21 TS 10947' 8787' Zone 1 B 11044' 8840' Formation at Total Depth (Name}: 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Q Si d ~ r~~ ~( gne Terrie Hubble Title Technical Assistant Date (~ PBU 02-16B 204-157 307-206 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4694 Permit No. / A royal No. INSTRUCTIONS Gewew~~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irene 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. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Irea- 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas (ejection, Shut-In, or Other (explain). IreM 27: 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. Irene 29: 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 02/2007 Submit Original Only Digital Well File ~ ~ Page 1 of 1 Well: 02-16 Well History Well Date Summary 02-16B 7!1412007 CTU #8 w/ 1.75" OD CT. Dummy WS drift. MIRU CTU #8. MU Baker dummy whipstock drift. Drift is 13.9' tong, 2.7" OD. Pump 100 bbls KCI to offset WHP. RIH with drift. Continued on WSR 07/15/07. 02-16B 7/15/2007 CTU #8 w/ 1.75" OD CT. Drift with dummy whipstock. Continued from WSR 07/14107. RIH to 11339' ctmd and set down. Work pipe down to 11370' ctmd. Tag consistently at this depth, unable to work past. PUH above liner top and pump 64 bbls water down backside. RBIH and work pipe through interval 11372' - 1 i 381' ctmd, after this interval able to RIH to objective depth with no weight bobbles. Pull up hole and repeat pass twice, able to RIH with no weight bobbles to 11450' ctmd. POOH. Freeze protect wellbore with 42 bbls 50/50 meth. Leave well SI. `**Job Complete*** 02-16B 7/18/2007 T/I/0=1350/100/0+ Temp=Sl Clean wellhead & eval possible leaking flanges. Starting C~ top of tree cap and all the way to the cellar cleaned residual fluid from spill of slickline on 4/18/07 as reported in operator notes. Oil was seen and cleaned on tree cap, swab valve, flowcross, master, wing, SSV, actuator, THA, A, B, C, section of Vetco-Gray wellhead, annulus valves & jewelry. No active leaking could be seen or heard. Floor grating is oil soaked and needs to be removed, steam cleaned, replaced. Gravel in cellar is still oil soaked. Operator notified me that SRT has been notified for some time. 02-168 7/1912007 TlllO= 1350!10010+. Temp= SI. Monitor WHP's (eval leaking wellhead /tree). A/L spool removed. Wellhead has no apparent leaks at this time. 02-16B 7/23/2007 T/I/0=1460/100/20 Temp=Sl. Monitor WHP's (Eva! oil on wellhead). A/L spool removed. No active leaks detected. Residue! oil between master valve, Tbg head adapter &Tbg hanger. Oily gravel in cellar. 3" integral flange on IA. 02-16B 7/28/2007 T/I/0= BPV/110/20. Temp= SI. Bleed WHP's to 0 psi (pre-GTD). Integral installed on fA. IA FL near surface. OA FL near surface. Bled IAP & OAP to slop trailer to 0 psi in 2 hours. Monitored for 30 minutes. No change in pressures. Final WHP's= BPV/0+/0+. 02-16B 7/28/2007 T/I/O=BPV/130/30. SI. Monitor (pre-CTD). AL spool dropped. {AP increased 30 psi and OAP increased 10 psi in 5 days. 02-16B 8/6/2007 TJI/0= 1800/50/0 Load and kill [Pre CTD] Pumped 5 bbls 60140 meth, 290 bbls 2% KCL, 40 bbls diesel FWHP's= 2001200!340 ***Annu{us casing valves tagged and left open, Master valve and SSV left closed"* 02-16B 818/2007 Til/0= VACI30/20. Temp= S1. Bleed WHP's to 0 psi (pre CTD). IA & OA FL near surface. Bled IAP from 30 psi to 0 psi in 43 mins, bled OAP from 20 psi to 0 psi in 25 mins. Shut-in bleed and monitored pressure for 30 mins, IAP and OAP unchanged. 2" integral installed on IA. Final WHP's= VAC/010. 02-168 8/9/2007 (Set BPV Pre Rig). Set 5" Gray BPV. No problems. Print Date: 9/10/2007 Page 1 of 1 http:J/digitalwellfile.bpweb.bp.comlWIInfa/ReportstReportViewer.aspx 9/10/2007 BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: 02-16 Common Well Name: 02-16 Spud Date: 7/7/1980 Event Name: REENTER+CO MPLETE Start: 8/12/2007 End: 8/30/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2007 Rig Name: NORDIC 1 Rig Number: N1 Date. ~ From - To li Hours ; Task ~I Code i NPT F~hase Description of Operations -- -------- ~----'--- -a__---- ----_ ----------------__---- 8/12/2007 12:30 - 19:45 7.25 MOB P PRE ~, Park rig on G pad, clean up location. CIO breaker in SCR room. Work on rig pits with welder. 19:45 - 20:00 0.25 MOB P PRE PRE-RIG MOVE SAFETY MEETING. Review procedure, f hazards and mitigation for rig move to DS 02-16C with .Security, Nordic and SWS personnel. 20:00 - 00:00 4.00 MOB P PRE i Move rig on West dock road to DS 02-16c. 8/13/2007 00:00 - 03:45 3.75 MOB P PRE I Move rig to DS 02-16C. 03:45 - 04:00 0.25 MOB P PRE ~ SAFETY MEETING. Review procedure, hazards and i mitigation for backing rig over well. 04:00 - 04.30 0.50 MOB P PRE ;Back rig over well and set down rig. Accept Rig 0430 8!13107 04:30 ".07:00 2.50 RIGU P ~ PRE 07:00 - 09:30 2.50 BOPSUFj P PRE 09:30 - 17:00 7.50 BOPSU~jI[ I P PRE i 17:00 - i8:00 1.00 BOPSU I I P PRE 18:00 - 18:45 0.75 BOPSU P PRE 18:45 - 19:00 0.25 BOPSU P PRE 19:00 - 20:30 1.50 BOPSUR P PRE 20:30 - 20:50 0.33 RIGU P PRE 20:50 - 21:30 0.67 RIGU P PRE 21:30 - 21:45 0.25 RIGU P PRE 21:45 - 22:45 1.00 RIGU P PRE 22:45 - 00:00 I 1.251 RIGU I P I I PRE 8114/2007 00:00 - 01:30 1.50 RIGU P PRE 01:30 - 02:00 0.50 WHIP P WEXIT 02:00-02:30 0.50 WHIP P WEXIT 02:30 - 02:45 0.25 WHIP P WEXIT 02:45 - 03:30 0.75 WHIP P WEXIT 03:30 - 06:30 3.00 WHIP P WEXIT 06:30 - 07;10. 0.671 WHIP I P I I WEXIT 07:10 - 07:25 I 0.251 WHIP I P l I WEXIT 07:25 - 07:40 I 0.251 WHIP I P I I W EXIT C J„ U/:4U- Rig up trailers and tanks. BJSM. Pick up 2" E-Coil off of Veco trailer. Prep E-coil reel to pull coil to injecter head. N/U BOPE. Pressure and function test BOPE. Test witness waived by AOGCC inspecter, Jeff Jones. Greased tree vavles and rig valves to get good tests. Rig up Tiger tank, berm and hardline. Press test hardline. Grease CT injecter. Wait on BPV crew. PJSM for pu lubricator. Testing lubricator. RU lubricator .Test 250 psi {ow 1000 psi hi. OK pull BPV. Well on vac. RD Lubricator. PJSM for stabbing coil. PU injector. RU to pull test grapple in a-coil. PuII test OK. Pull coif across PJSM for slack management. Stab onto well. Circulate coil to fill with KCL 43 bbl to fill. Cut 14' wire. Seal E line, Reverse circulate to manage slack. 2.8 bpm C 2424 psi. POP off well.Cut 40' coil. Install Kindal connector and pull test. OK. Head up E-coil. Tested at 52 ohms, P7 to'4000 psi. PU whipstock install pip tags, Circulate across the top of well. 16 bbl to fill. PJSM with crew for PU of W S. PU Whipstock. MU Baker eline tools. RIH with WS. Circ. out fluid in tubing to Tiger tank. Log GR tie-in to PDC log RA tag at 10,960', of 02-166. -17' correction. Tied-in depth is corrected to top of whipstock tray. RIH to 11,306' top of whipstock. Orient TF to 90LOHS. Stop 1 ft high to allow for piston effect when setting whipstock with 3500 psi. _ Top of Whipstock at 11,307', Circ 20 bbl at 2 bpm. Close EDC. Press up slow. Sheared at 3100 psi and set whipstock, Set down 3K on whipstock. OK. Clean pick up off whipstock at 29K, circ at 2 bpm, 2000 psi wniie circ at 2 bpm, 1 yUO psi, gas m returns, sen returns to tiger tank. Circ 100 bbls to tiger tank. Keep returns and circ at 1 bpm Printed: 9710!2007 2;51'45 PM ~2EE = GRAY GEN 2 _ WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 58'8' DRLG DRAFT BF. ELEV = KOP = 10949 Max Angle = 95 @ 12866 ' 20" CONDUCTOR 98' Datum MD = 11093 Datum TVD = 8800' SS 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 29' 13-3/8" CSG, 72#, N-80, ID = 12.347" 3029' TOP OF 7-5/8" LNR-TIEBACK ~-~ 54' 7-5/8" LNR-TBK, 29.7#, NT-80, .0459 bpf, ID = 6.875" 9299' TOP OF 7" LNR 9299' TOP OF CEMENT 9306' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9450' Minimum ID =1.995" @ 10,849' 2-3/8" LINER 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" 10840' 4-1/2" TBG, 12.6#, L-80..0152 bpf, ID = 3.958" 10922' 10949' 2ND MECH WHIPSTOCK w /RA TAG MILLOUT WINDOW 1995d'. 10983' 7" LNR. 2~J#. NT-80, ID = 6.184" - 71305' / _ it PERFORATION SUMMARY REF LOG: SWS MCNL/GR LOG OF 08/28/07 ANGLEATTOPPERF:93 Deg @ 11,750' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 11750 - 11950 Opn 08/30/07 1.56" 6 12250 - 12730 Opn 08/30/07 1.56" 6 12840 - 13120 Opn 08/30/07 1.56" 6 11192 - 11197 Partial sqz 08/27/07 2" 6 11190 - 11210 Partial sqz 08/27/07 2" 6 11310 - 11350 Partial sqz 08/27/07 PBTD 2-718" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" SHOWN. ORIGINAL WELBORE NOT 29' ~-I5-1/2" X 4-1/2" XO 4-1/2" CAM TRDP-4A SSSV NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3597 3056 48 TGPD DMY RK 0 08/12/05 2 6941 5444 39 TGPD DMY RK 0 08/12/05 3 9100 7148 33 TMPDX DMY BK 0 10/03/04 4 9205 7237 32 TMPDX DMY BK 0 10/03!04 9270' ~-~ 4-1 /2" BAKER PBR 10754' --j 4-1/2" PARKER SWS NIP, ID = 3.812" 10766' 7" BAKER SABL-3 PKR 10790' 3-1/2" BKR DEPLOY SLV, ID = 3.00" 10790 EST TOP OF CEMENT 10810' 3-112" HES X NIP, ID = 2.813" 10840' 3-1/2" X 3-3/16" XO, ID = 2.786" 10909' 4-112" PARKER SWS NIP, ID = 3.812" (BEHIND PIPE) 109- 2~ 4-1/2" TBG TAIL WLEG (B@iIND PIPE) 3 3116" MILLOUT WINDOW 11,30T-11,312' 10842' Top of 2-3/8" Liner 10842' Top of Cement? 2-318" crr['ed and perfed 133 CIBP -~ 13169' ( TD -L 11307' Mech Packer WS w R/A tags 11733' 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID=2.8" 11733' 3-3/16" X 2-7/8" XO JOINT, ID = 2.440" 11770' WFD CIBP (06/15/06) DATE REV BY COMMEMS DATE REV BY COMMENTS 06/80 ORIGINAL COMPLETION 05/17/06 JD/PJC MIN ID CORRECTION 10/31193 SIDETRACK (02-16A) 05/30/06 DTM WELLHEAD CORRECTIONS 10/03104 BMcMITLH CTD SDTRCK (02-16B) 06!15/06 SCS/PJC SET CIBP @ 11770' OSI30/OS JRA/TLH 20" CSG ADDED 10/03/06 GJB/PAG PERF 09/10/05 BMcM/TLH FINAL DRLG CORRECTIONS 05/09/07 RDW/PJC WANER SFTY NOTE DELETED 01/10/06 EZUPJC WANERSFTY NOTE(12/05) 08/30/07 G. S. CTD HORIZONTAL SIDETRACK 02-16C CTD Sidetrack u PRUDHOE BAY UNIT WELL: 02-16C PERMIT No: 2070870 API No: 50-029-20448-03 SEC 36, T11 N, R14E, 4589.95' FEL & 1417.31' FNL BP Exploration (Alaska) . ~1rL%1rŒ (ID~ L%~L%~fßL% . AI,ASIi&. OIL A1Q) GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~bLt- 157 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-16B Sundry Number: 307 -206 Dear Mr. McLaughlin: sCANNED JUN 2 6 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ay of June, 2007 Enc!. · sTATEOFALASKA01l'-J5;¡¡jj. ~ ALASKA Oil AND GAS CONSERVATION COM_ION { RE C E IVE D APPLICATION ~~~~2~.~8~RY APPROVAL f%(¡,b\ .JUN 1 9 2007 1. Type of Request: ~ Abandon o Suspend o Operation Shutdown o Perforate o Tim~IAA~;lsró" & Gas Cons. Comm o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspen~~age o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 204-157 - 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20448-02-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: P8U 02-168 - Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028308- 58.76' ./ Prudhoe Bay Field / Prudhoe Bay Pool - 12.> > > .. ....... > 1, IJ\. 'I'IIUI 11\,)1'11 Sf ..... ............/ <> ../:<·iY.//>i<>Y Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13685 r 8864 r 11770 8925 11770 None Casina Lenath Size MD TVD Burst Collanse Structural Cnndu~tnr 98' 20" 98' 98' 1530 520 Surface 3029' 13-318" 3029' 2676' 5380 2670 Intermediate 9450' 9-5/8" 9450' 7447' 6870 4760 Production Liner 1655' 7" 9299' - 10954' 7316' - 8792' 8160 7020 Liner Tieback 845' 7-518" 8454' - 9299' 6616' - 7316' 6890 4790 Liner 2838' 3-1/2" x 3-3/16" x 2-7/8" 10790' - 13628 8671' - 8872' 10160 10530 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11190' - 13300' 8891' - 8894' 4-1/2",12.6# L-80 10922' Packers and SSSV Type: 7" Baker SABL Packer I Packers and SSSV MD (ft): 10766' 4-1/2" CAM TRDP-4A SSSV (Nipple) 2103' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencinq Operations: July 15, 2007 DOil DGas D Plugged 181 Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4694 Printed Name..,$ean McLaughlin Title CT Drilling Engineer Iv~ 11 A l¿~ Ii Prepared By Name/Number: Signature Phone 564-4694 Date 6/ t'LP , Sondra Stewman, 564-4750 ... v Commission Use On Iv I ~ Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~07· cfJ.Olß D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other:~ct\\c:.o~\fè~\\>M£.f'+ ~<t, ðð þ..~<-~S-,~~ Subsequent Form Required:l(), .. ..ztOMMISSIONER APPROVED BY tlr'ð~ Approved Bv: - I THE COMMISSION Date Form 10-403 Revised 06/2006 '-"'" -V '-.---- Submit In Duplicate sSlon ORIGINAL RBDMS BFl JUN 2 6 2007 ,é ttØ~? . . From: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission Sean McLaughlin CTD Engineer June 18, 2007 02-16B sundry request Obp To: Date: Re: Sundry approval is requested for Prudhoe well 02-l6B. We1l2-16B was a ZlA1Z1B CTD sidetrack drilled in October 2004. Following the CTD sidetrack, a PGSL plug was installed in the 3-3/16" liner top while an IA valve was replaced. The plug became stuck and required many milling and fishing attempts. The plug was finally retrieved in March 2005 and the well began production. The GOR steadily increased over the first 4 months of production and the well was SI in late June 2005 at marginal GOR after 4 months of production. The initial cycle after a 7 month SI did not indicate any healing. A STP and MCNL log was run in April 2006 to identify potential wellwork options. The CNL log indicated a GOC at the top of ZlB with a 46' NLOC. The STP log indicated the major fluid and gas entry at 12200' - 12300'. This interval is likely fractured as evidenced by erratic toolface changes near this depth during the drilling operations and it appears to be at the intersection of two faults. ACT-conveyed CIBP was set at 11770' in June 2006 for gas shutoff. After setting the CIBP, the remaining 205' ofZ1A perforations did not flow. In October 2006,20' of ZlB was perforated in the heel. After the perforations, the well produced 75,000 scf/bbl making the well uncompetitive. 02-l6B was waivered for an IAxOA leak in December 2005 based on competent surface casing and production tubing. The well recently passed a MIT-IA to 3000 psi and a MIT-OA to 3000 psi in May 2007 demonstrating the well will be operable under the new Well Integrity Policy that is effective June 1,2007. The caliper log indicates the tubing is in fair condition with minimal change in corrosion since the last caliper in August 2004. REASON FOR SIDETRACK: 02-l6B currently produces at 70,000 - 85,000 scf/bbl GOR and shows no healing; therefore, the well provides minimal value to the field. Due to the low remaining value of this well and the lack of wellwork options, the well has been selected for a through tubing sidetrack. A coiled tubing sidetrack is planned on or around August 101\ 2007. The sidetrack, 02-16C, will exit the existing 3-3/16" liner from a whipstock and will target the Zone lA sand. 1he, existing perforations will be isolated by the liner cement job. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: 1. 0 MIT -lA, and OA. (Done on 4/18/07) 2. S Run caliper log (Done on 4/15/07) 3. C Dummy WS (15' x 2.625") drift to 11,400' 4. 0 Set BPV 5. 0 AC-LDS; AC-PPPOT -IC, T 6. 0 Test MV, SV, WV 7. 0 Bleed gas lift and production flowlines down to zero and blind flange 8. 0 Remove wellhouse, level pad l""~~~\ The pre CTD work is slated to begin on July 15th, 2007. Rig Work: 1. MIRV and test BOPE to 250 psi low and 3500 psi high, Pull BPV 2. Set 3-3/16"monobore packer whipstock @ 11,300. 3. Mill 2.74" window at 11,300' and 10' of openhole. Swap the well to Flo-Pro. 4. Drill Build: 3" OR, 350' (40 deg/100 planned) 5. Drill Lateral: 3" OR, 1,900' horizontal (12 deg/100 planned) - include resistivity 6. Run 2 3/8" solid liner leaving TOL at 11,100. 7. Pump primary cement job to T! 10 bbl of 15.8 ppg em! planned . 8. Run CO assembly 9. Run MCNLlGRJCCL log 10. Test liner lap to 2000 psi. 11. Perforate, planned 1000ft. 12. Ifneeded, set LTP at 10,740 13. Freeze protect well, Set BPV, RDMO Post-Hi!! Work 1. Pull BPV 2. Install well house. Hook up flow line. Sean McLaughlin CTD Drilling Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = GRAY GEN2 WELLHEAD = GRAY ~OTES' O""NAL WB.BORENOT ACTUA TOR = AXELSON 02-168 SHOWN. KB. ELE:\! = 58.8' BF. ELE:\! = l,A KOP= 10949 29' H 5-1/2" X 4-1/2" XO I Max Angle = 102 @ 13618 120" CONDUCTOR I l- I Datum MD = 11093' 98' Datum TVD = 8800' SS / 2103' ~4-1I2" CAM TRDP-4A SSSV NIP, ID = 3.812" I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I 29' r . GAS LIFT MANDRELS ~ ~ ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 113-3/8" CSG, 72#, N-80, ID = 12.347" I 3029' 1 3597 3056 48 TGPD DMY RK 0 08/12/05 L 2 6941 5444 39 TGPD DMY RK 0 08/12/05 3 9100 7148 33 TMPDX DMY BK 0 10/03/04 4 9205 7237 32 TMPDX DMY BK 0 10/03/04 TOPOF7-5/8" LNR-TIEBACK I 8454' 1-. JI JI) 9270' ~4-1/2" BAKER PBR I 17-5/8" LNR-TBK, 29.7#, NT-80, .0459 bpf, ID = 6.875" H 9299' I TOPOF 7" LNR I 9299' II í I TOP OF CEMENT H 9306' I-~ ~ 19-5/8" CSG, 47#, L-80, ID = 8.681" I ) 9450' I-~ ~ 10754' ~4-1/2" PARKER SWS NIP, ID = 3.812" I Minimum ID = 2.440" @ 11733' I I ---t 10766' ~ 7" BAKER SABL-3 PKR I 3-3/16" X 2-7/8" SUB XO JOINT I ...........1 10790' H3-1/2" BKRDEA..OY SLV,ID=3.00" I - 1 0790' ~ EST TOP OF CEMENT I I 10810' -13-1/2"HESXNIP,ID=2.813" I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" I 10840' f-- 10840' ..., 3-1/2" X 3-3/16" XO, ID = 2.786" I - 10909' ...., 4-1/2" PARKER SWS NIP, ID = 3.812" (BBilND PIPE) 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10922' ¡-- 10922' -14-1/2" TBG TAIL WLEG (88-11ND PIPE) I S I MILLOUT WINDOW 10954' -10962· I )( 1 10949' I 2ND MECH WHIPSTOCK w /RA TAG T; 3-3/16" X 2-7/8" XO JOINT, ID = 2.440" 11770' H WFD CIBP (06/15/06) I 17" LNR, 29#, NT-80, ID = 6.184" I 11305' \,r ~ ÆRFORA TION SUMMARY ~I"'I¡~ REF LOG: CNL LOG ON 10/02/04 ANGLEAT TOP ÆRF: 71 @ 11190' Note: Refer to Production DB for historical perf data ~ 1~-3/16" LNR, 6.2#, L-80, 1-1 11733' I _~ SIZE SPF INTERV AL Opn/Sqz DATE "lS .0076 bpf. ID ~ 2.80" t-, 2" 6 11190 -11210 0 10/03/06 2" 6 11310 - 11350 0 10/02/04 IPBTD H 13593' I / 2" 6 11370 -11535 0 10/02/04 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I 13628' 2" 6 11920 - 12320 C 10/02/04 2" 6 12560 - 12735 C 10/02/04 @J 13685' I 2" 6 12950 - 13200 C 10/02/04 2" 6 13270 - 13300 C 10/02/04 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/80 ORIGINAL COMPLETION 05/17/06 JDlPJC MIN ID CORRECTION WELL: 02-16B 10/31/93 SIDETRACK (02-16A) 05/30/06 DTM WELLHEAD CORRECTIONS ÆRMIT No: '2041570 10/03/04 BMcM/TLH CTD SDTRCK (02-168) 06/15/06 SCS/PJC SET CIBP @ 11770' API No: 50-029-20448-02 08/30/05 JRA/TLH 20" CSG ADDED 10/03/06 GJB/PA G ÆRF SEC 36, T11N, R14E, 4589.95' FEL & 1417.31' FNL 09/10/05 BMcM'TLH FINAL DRLG CORRECTIONS 05/09/07 RDW/PJC WArvER SFTY NOTE DELETED 01/10/06 EZLlPJC WArvERSFTY NOTE (12/18/05) BP Exploration (Alaska) 10/03/04 29.7#, NT-SO, Minimum ID == 2.440" 11733' 3..3/16" X 2-7/8" SUB XO JOINT 2" 2u 2~f 2" 2" LNR, BP . . Review of Sundry Application 307-206 BP Exploration (Alaska) Inc. Well Prudhoe Bay Unit 02-16B Prudhoe Bay Field, Prudhoe Oil Pool AOGCC Permit 204-157 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to plug the existing well to prepare it for sidetracking. Recommendation: I recommend approval of BPXA's proposed actions Discussion: Well 02-16B was originally drilled and completed, as a coiled tubing sidetrack of the existing well 02-16 in 2004. The well has always produced at a high GOR and therefore had to compete for space in the processing facilities and, after an initial extended period of production, has not flowed for more than 11 days in a month since June 2005. When the well is flowing it generally produces in the neighborhood of200 to 500 BOPD, with a GOR around 70,000 scf/stb. Conclusion: Since the well is producing at a high GOR and is not competitive with other wells for processing facility space )ltcan only produce for a few days a month and therefore is of limited value. Abandoning the existing wellbore and sidetracking the well again in an effort to find a lower GOR production so that the well can be produced on a more consistent basis is a prudent decision. D.S. Roby #ý Reservoir Engineer June 22, 2007 02-16 (PTD #2041570) Internal Waiver Cancellation - Normal Well ùZ,-l~ ß · . (,ò 101 All, 02--1(..6 An internal waiver was issued for IAxOA communication on well ~ (PTD #2041570) on 12/15/05. The well passed an MITIA on 04/18/07 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well ~ will be Operable. 02.--, '" IS The well is reclassified as a Normal well. Please remove all waivered well signs and the lamintaed copy of the waiver from the wellhouse. Thank you - Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 5'CANNED MAY 1 6 2007 I of I 5/10/2007 10:55 AM J lIJe v ~}o DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041570 Well Name/No. PRUDHOE BAY UNIT 02-16B Operator BP EXPLORATION (ALASKA) INC MD 13685'/ TVD 8864 /" Completion Date 1 0/3/2004 - Current Status 1-01L Completion Status 1-01L s (I~~ .Â'II s..,J- ~ \0 API No. 50-029-20448-02-00 UIC N REQUIRED INFORMATION Mud Log No Samples No '-~ DATA INFORMATION Types Electric or Other Logs Run: MWD GR / ROP, MGR / CCL / CNL Well Log Information: - Directional Survey Yes -~--~.- (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset TypjV- Med/Frmt Number Name ~D Asc Directional Survey I~ Directional Survey ß' 0 12819 Gamma Ray yPt 12819 LIS Verification ~ Neutron ~c Lis 13597 Induction/Resistivity Neutron ~C Pds 13996 Neutron 156' C Lis 13996 Induction/Resistivity ~g Production Log Log Scale Media Run No Interval OH / Start Stop CH 10947 13685 10947 13685 10939 13662 Open 10939 13662 Open 10235 13511 1 0972 13685 Open 10597 13405 Case 2 Blu 2 Blu Received 11/9/2004 11/9/2004 11/9/2004 11/9/2004 2/3/2005 2/22/2006 7/25/2006 10597 13405 Case 7/25/2006 0 0 Open 7/25/2006 25 Blu 10931 13405 Case 8/10/2006 I Well Cores/Samples Information: . Comments IIFR IIFR GRlROP/MWD GR/ROP/MWD/DSN 12819 cnl/mam gr/ccl ROP DGR plus Graphics Mem CNL, Lee GR, CCL 25-Apr-2006 Mem CNL, Lee GR, CCL 25-Apr-2006 DEPT, NCNT, CCL w/Graphics Mem PPL, GR, LEE, CCL, Pres, TEMP, SPIN 25-Apr- 2006 . Name Interval Start Stop Sample Set Number Comments Sent Received DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permitto Drill 2041570 Well Name/No. PRUDHOE BAY UNIT 02-16B Operator BP EXPLORATION (ALASKA) INC MD 13685 TVD 8864 Completion Date 10/3/2004 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION y(;i) Chips Received? ~ Well Cored? Daily History Received? &tN 'D/N Formation Tops Analysis Received? .:t..LJj Comments: Compliance Reviewed By: '~ Date: API No. 50-029-20448-02-00 UIC N en Moú tÂ~<n . . iVED I STATE OF ALASKA I ALAS' OIL AND GAS CONSERVATION COM . SION REPORT OF SUNDRY WELL OPERATIQN$:m 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program 0 2. Operator Name: 3. Address: Repair WellŒ Pull TubingO Operation ShutdownO Plug PerforationsD Perforate New PoolD Perforate ŒJ 4. Current Well Class: Development [!] StratigraphicD 9. Well Name and Number: 02-168 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 58.76 8. Property Designation: ADL-0028308 11. Present Well Condition Summary: OCT 2 7 2006 Stimulate 0 WaiverD Cùmm¡~~:in 1 f\¡¡¡;B\«~"l:I ExploratoryD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 204-1570 6. API Number 50-029-20448-02-00 ServiceD 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 13685 feet true vertical 8864.0 feet Plugs (measured) WFD CIBP Set @ 11770 (06115/2006) Effective Depth measured 11770 feet Junk (measured) None true vertical 8925.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 20" 94# H·40 30 98 30.0 98.0 1530 520 SURFACE 3001 13-318" 72# N-80 28 - 3029 28.0 - 2675.0 4930 2670 PRODUCTION I 9423 9-5/8" 47# L-80 27 27.0 6870 4760 PRODUCTION 9-5/8" 47# SOO-95 9450 7447.0 8150 5080 LNR TIEBACK 1103 7-5/8" 29.7# NT-80 8454 - 9299 6615.0 - 7316.0 6890 4790 LINER 1655 7" 29# 13Cr80 9299 - 10954 7316.0 - 8792.0 8160 7020 LINER 50 3-1/2" 8.81# L-80 10790 - 10840 8671.0 - 8712.0 10160 10530 LINER 893 3-3116" 6.2# L-80 10840 - 11733 8712.0 - 8926.0 8520 7660 LINER 1895 2-7/8" 6.16" L-80 11733 - 13628 8926.0 - 8872.0 13450 13890 Perforation depth: Measured depth: 11190-11210,11310-11350,11370-11535, 11920-12320, 12560-12735, 12950-13200, 13270-13300 True vertical depth: 8891-8897,8915-8918,8918-8922,8917-8908, 8909-8907, 8894-8887, 8892-8894 Tubing ( size, grade, and measured depth): @ 24 @ 29 5·1/2" 17# L-80 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 4-1/2" Baker packer 7" Baker SABL-3 Packer 4-1/2" CAM TRDP-4A SSSV Nipple @ @ @ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 29 10922 9270 10766 2103 RBDMS 8Ft 3 2006 Prior to well operation: Subsequent to operation: Oil·Bbl 431 447 29891 31750 Representative Dailv AveraQe Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 12 12 Tubing Pressure 918 601 14. Attachments: 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Copies of Logs and Surveys run _ Daily Report of Well Operations _ 2Ç 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature ~z~~y~ Form 10-404 Revised 4/2004 Title Phone DevelopmentŒ ServiceD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. lSUndry Number or N/A if C.O. Exempt: N/A Petroleum Engineer 564-5174 10/26/06 Date . . 02-168 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AWGRS 06/07/2006 *** WELL SHUT IN ON ARRIVAL *** { PRE CIBP} DRIFTED WI 2.70 CENT, SAMPLE BAILER TO 11,235' WLM, STOPPED DUE TO DEVIATION (77 DEG.) (NO SAMPLE RECOVERED) ****WELL LEFT SHUT IN & RETURNED TO DSO**** AWGRS 06/14/2006 MIRU CTU #5. MU Baker CTC and PDS memory logging tools wI 2.60" JSN. RIH. Tag 33/16" x 27/8" x-over @ 11755' CTM & log up to 10900', POOH Retrieved good data...- 26' correction @ flag on CT. AWGRS 06/15/2006 RIH w 27/8" CIBP and set @ 11,770' corrected depth. POOH. Attempt to flow well. Call out N2 to lift well. While rigging up N2 unit well kicked off. Stable at 400 psi. RDMO. *** Job Complete*** AWGRS 08/14/2006 ***WELL S/I ON ARRIVAL*** UNABLE TO DRIFT THROUGH TRSSSV (CLOSED WIDP TRAPPED BELOW VALVE). FLUID LEVEL IN TBG @ - 1350. PUMP TRUCK NOT AVAILABLE. *** WELL LEFT SHUT IN AN TURNED OVER TO DSO *** AWGRS 08/14/2006 T/I/O=470/380/0. Temp=SI. IA FL for Slick line. IA FL @ 2418' AWGRS 08/18/2006 T10=550/250 1100 MIT IA PASSED 3000 psi (Waiver compliance)(Shut in) Bleed Gas off IA pumped 19.8 bbls of 55* crude down IA to reach 3000 psi for MIT IA 1st test 1st 15 min lost 180 psi 2nd 15 min lost 40 psi for a total of 220 psi in 30 min bleed IA psi bleed back 10 bbls Final Whp's=550/175/1 00 AWGRS 09/20/2006 ***WELL SHUT IN ON ARRIVAL*** RAN FLAPPER CHECKER, BACK INDICATING PARTIALLY CLOSED FLAPPER. AWGRS 09/20/2006 T/I/O=600/675/40 Open SSSV - Pumped 25 bbls. crude down tubing, Final WHP's 900/750/40 AWGRS 09/2112006 DRIFT DOWN TO 11230' MD WITH 2.10" DUMMY GUN, 1 7/8" ROLLER SKATE, 2.20 WHEELS, RIG DOWN TURN WELL BACK TO DSO. ***JOB COMPLETE*** AWGRS 10/02/2006 WELL SHUT IN ON ARRIVAL. SSV CLOSED. INITIAL T/I/O=2200/1300/0. DOWN HOLE VALVE CLOSED ON ARRIVAL. RUN 2" POWERJET OMEGA HSDS. TOTAL TOOLSTRING LENGTH=38.8'. MAX OD=2.2" AT THE ROLLER WHEELS. DID NOT PASS THROUGH DEPLOYMENT SLEEVE WITH 2.2 WHEELS. ADDED 2.5" WHEELS AND TAPERED NOSE BELOW AND MADE IT DOWN TO 11261' ELM. NEW TOOLSTRING LENGTH 41.2' WITH MAX 00 2.5". PERFORATED FROM 11190' - 11210'. WELL SHUT IN ON DEPARTURE. SSV CLOSED. SSSV LEFT OPEN. FINAL T/I/O=2200/1300/0. ***JOB COMPLETE*** AWGRS 10/13/2006 T/I/O=2280/500/100, Temp=SI, A/LP @ 1210 psi, shut-in @ casing valve. Perform TIFL. IA FL Near surface, did not TIFL. TestEvent 10/17/2006 BOPD: 447 BWPD: 12 MCFPD: 31,750 AL Rate: Page 1 . . 02-168 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 3 Diesel --- PT Surface Equipment 211 1 % KCL Water 198 Crude 412 TOTAL Page 2 TREE = WELLHEAD = ACTUA TOR = .~B. ELEV '" BF. ELEV = KOP = 10949 rv1axm-Angle; '1b27~ 13618 Datum MD = 11093' Datum TVD = 8800' SS 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 GRAY GEN2 GRAY AXELSON 58.8' . 120" CSG H 98' 29' 113-3/8" CSG, 72#, N-80, ID = 12.347" - 3029' TOPOF7-5/8" LNR-TIEBACK - 8454' 17-5/8" LNR-TBK, 29.7#, NT-80, .0459 bpf, ID = 6.875" 1-1 9299' I TOP OF 7" LNR l-f 9299' I TOP OF CEMENT - 9306' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" - 9450' Minimum ID = 2.440" @ 11733' 3-3/16" X 2-7/8" SUB XO JOINT 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" - 10840' 14-112" TBG, 12.6#, L-80, .0152 bpf. ID = 3.958" - 10922' 1 10949' -f2NDMECHWHIPSTOCKw/RA TAG I 1 7" LNR, 29#, NT-80, ID = 6.184" - 11305' ÆRFORA TION SUMfv1ARY REF LOG: CNL LOG ON 10/02/04 ANGLEATTOPÆRF: 71 @ 11190' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11190 - 11210 0 10/03/06 2" 6 11310 - 11350 0 10/02/04 2" 6 11370 - 11535 0 10/02/04 2" 6 11920 - 12320 C 10/02/04 2" 6 12560 - 12735 C 10/02/04 2" 6 12950 - 13200 C 10/02/04 2" 6 13270 - 13300 C 10/02/04 DATE · 06/80 10/31/93 10/03/04 08/30/05 09/10/05 01/10/06 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (02-16A) BMcMITLH CTD SDTRCK (02-16B) JRA/TLH 20" CSG ADDED BMcrvvTLH FINAL DRLG CORRECTIONS EZLlPJC WANER SFTY NOTE (12/18/05) DATE 05/17/06 05/30/06 06/15/06 10/03/06 02-168 ) l ~ r, II I ~ ~ ST MD TVD 1 3597 3056 2 6941 5444 3 9100 7148 4 9205 7237 . L I J¿ ;;... . \:V: .. I. ~ ~NOTE5: ORIGINAL WELBORE NOT SH..***IAxOA COMM. OPER LIMITS: MAX lAP & OAP = 1000 PSI (12/18/05 WAlVER)*** 29' 1-15-1/2" X 4-1/2" XO I 2103' 1~4-1/2" CAMTRDP-4A SSSV NIP, ID=3.812" GAS LIFT fv1ANDRELS DEV TYÆ VLV LATCH 48 TGPD DMY RK 39 TGPD DMY RK 33 TMPDX DMY BK 32 TMPDX DMY BK PORT DATE o 08/12/05 o 08/12/05 o 10/03/04 o 10/03/04 9270' 1-14-1/2" BAKER PBR I 10754' -f4-1/2" PARKER SWS NIP, ID = 3.812" I 10766' 1-17" BAKER SABL-3 PKR I 10790' 1-f3-1/2"BKRDEA..OYSLV.ID=3.00" I 1 0790' - EST TOP OF CEMENT I 10810' -3-1/2"HESXNIP,ID=2.813" I 1 0840' - 3-1/2" X 3-3/16" XO, ID = 2.786" I 10909' 1-14-1/2" PARKER SWS NIP, ID = 3.812" (BB-IIND PIPE) 10922' -4-1/2" TBG TAIL WLEG (BB-IIND PIPE) I I MILLOUT WINDOW 10954' -10962' -f 3-3/16" X 2-7/8" XO JOINT, ID = 2.440" 11770' -WFDCIBP(06/15/06) I , 13-3/16" LNR, 62#, L-80, o .0076 bpf, ID = 2.80" 1-1 11733' I I PBTD H 13593' 2-718"LNR,6.16#,L-80,.0058bpf,ID=2.441" H 13628' I @J-f 13685' REV BY JD/PJC DTM SCS/PJC GJB/PAG COMMENTS MIN ID CORRECTION WELLHEAD CORRECTIONS SET CIBP @ 11770' ÆRF PRUDHOE BA Y UNrr WELL: 02-16B ÆRMrr No: "2041570 API No: 50-029-20448-02 SEC36, T11N, R14E, 4589.95' FEL & 1417.31' FNL BP Exploration (Alaska) Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Well 02-168 16-21 16-01 16-01 D.S 11-08 D.S. 02-26C 09-09 18-33A X-07 A D-03A D-03A Z-19 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 11209601 11221558 1105228 10980601 11223100 11223117 11211484 11258719 11217272 11243918 11217271 11217273 RECEIVED AUG 1 0 2006 4,laska Oil & Gas Cons, Commission Anchorage f}oL(- 151- Log Description MEM PROD PROFILE TEMPêRATURESURVEY INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE LDL PROD PROFILE W/DEFT LDL US IT SCMT USIT USIT Date 04/25/06 04/03/06 07/21/05 08/15/05 02/27106 05/16/06 04/28/06 06/08/06 08/05/06 06/02/06 08/04/06 08/06/06 NO. 3907 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 CD Color Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/08/06 . . 07/19/06 Sc~.~erger NO. 3880 Alaska Data & Consulting Services /)DLf - 15"1- Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage. AK 99503-2838 Attn: Christine Mahnken A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 15·12A 11211420 RST GRAVEL PACK 06/25/06 1 . 17 -OS 11211509 INJECTION PROFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-o6A 11217266 INJECTION PROFILE 07/12/06 1 P2-o1 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-oS 11217256 PROD PROFILE W/GHOST & DEFT 06/06106 1 ~ 16-o4A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06 1 '> 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 US IT 06/27/06 1 1.1-51 11212873 USIT 06/28/06 1 04-31 11217264 US IT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-168 11209601 MCNL 04/25/06 1 1 L2-18A 11217234 MCNL 04/06/06 1 1 L5-o9 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 . 12-01 11072866 RST 07/06/05 1 1 E-11A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 ¿)D4~ 151 /350,7 RE: MWD Formation Evaluation Logs 02-16B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 02-16B: LAS Data & Digital Log Images: 50-029-20448-02 1 CD Rom d~QUh ')-IIJ-~ f CJG Re: FW: 02-l6B (PTD #2041570) Classified as Problem Well- D... ~ e e 105' Thanks for the clarification. Jim Regg NSU, ADW Well Integrity Engineer wrote: Hi Jim, I'm following up on your question to Harry & Steve yesterday about the status of well 02-16D (PTD# 2041570). The attached TIO plot shows the well had TxIAxOA communication from 07/22/05 to 08/13/05 when running DGLVs repaired the TxIA communication. Because our new waiver policy will not allow TxIAxOA communication, a successful effort was made to restore tubing integrity by dummying gas lift valves on 08/13/05. An MITIA passed to 3000 psi that verified tubing integrity has been restored. But because the well still has slow IAxOA communication an IAxOA waiver is being processed. Please contact me with any additional questions. Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907-659-5102 907-659-5100 #1154 pgr -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Friday, August 12, 2005 8:16 PM To: James Regg¡ NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: RE: 02-16B (PTD #2041570) Classified as Problem Well Jim, Attached, please find a TIO plot for well 02-16 for the past 3 months. Good question about the waiver. ..our standard practice is to repair rather than waiver. A waiver is usually pursued only after non-rig wellwork options have been exhausted. Feel free to contact me with any additional questions. Thanks Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: 1-907-659-5525 Pager: 1-907-659-5100 x1923 Email: r~bert.mielke@bp.com -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Wednesday, August 10, 2005 4:11 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Re: 02-16B (PTD #2041570) Classified as Problem Well 10f2 9/14/20059:02 AM Re: FW: 02-16B (PTD #2041570) Classified as Problem Well- U... e - e Please send a TIO plot for this well (last 90 days). Why not a waiver for TxIAxOA communication? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: All, Well 02-16B (PTD #2041570) has been found to have sustained casing pressure on the OA and has been classified as a problem well. The TIO's on 08/08/05 were 2400/1740/1210. The well is a natural flow producer that passes TIFLs but exhibits slow IA & OA repressurization. The plan forward for this well is as follows: 1. SL: Run DGLVs in sta# 1 & 2 2. DHD: TIFL 3. WAV: Write IAxOA waiver A wellbore schematic has been included for reference. Please call if you have any questions. «02-16B.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr 20f2 9/14/20059:02 AM RE: 02-16B (PTD #2041570) Classified as p,m Well Jim, Attached, please find a TIO plot for well 02-16 for the past 3 months. Good question about the waiver. . .our standard practice is to repair rather than waiver. A waiver is usually pursued only after non-rig wellwork options have been exhausted. Feel free to contact me with any additional questions. Thanks Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: 1-907-659-5525 Pager: 1-907-659-5100 x1923 Email: robert.mielke@bp.com -----Original Message----- From: James Regg [~?ilto:jim regg@admin.s~ate.ak. Sent: Wednesday, August 10, 2005 4:11 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Re: 02-16B (PTD #2041570) Classified as Problem Well Please send a TIO plot for this well (last 90 days). Why not a waiver for TxIAxOA communication? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: All, Well 02-16B (PTD #2041570) has been found to have sustained casing pressure on the OA and has been classified as a problem well. The TIO's on 08/08/05 were 2400/1740/1210. The well is a natural flow producer that passes TIFLs but exhibits slow IA & OA repressurization. The plan forward for this well is as follows: 1. SL: Run DGLVs in sta# 1 & 2 2. DHD: TIFL 3. WAV: Write IAxOA waiver A wellbore schematic has been included for reference. Please call if you have any questions. «02-16B.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr 02-16 TIO Data.ZIP Content-Description: 02-16 no Data.ZIP 10f2 8/22/2005 4: 10 PM U2-1013 W1D #2041570) Classified as Problem Well All, Well 02-168 (PTD #2041570) has been found to have sustained casing pressure on the OA and has been classified as a problem well. The TIO's on 08/08/05 were 2400/1740/1210. The well is a natural flow producer that passes TIFLs but exhibits slow IA & OA repressurization. The plan forward for this well is as follows: 1. SL: Run DGLVs in sta# 1 & 2 2. DHD: TIFL 3. WAY: Write IAxOA waiver A wellbore schematic has been included for reference. Please call if you have any questions. «02-168.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907 -659-5102 907-659-5100 #1923 pgr Content-Description: 02-16B.pdf Content- Type: application/octet-stream Content-Encoding: base64 scP AAtP ~~p ,- -::J-j'J. 114D~ 6 t¿ "Vp«;J ) "Z..5, '3¿~G' (JA l Zt0P'=>; 53$Ops; 22.5"% òt: CtJ 4-tì z. per pre-SSW< -f0~-S SR~? q11/~ 1 of 1 8110120053:43 PM TREE" GRAY GEN 2 WElLHEAD" FMC ~~~~ ACTUA TOR = AXElSON KB. ElEV = BF. ELEV = KOP = 10949 . , . .~>~.. ~~,~~~~" ~~M~~~~,~^~>~.""M"",~ Max Angle = 102 ~..1~62~ Datum MO == 11077' Datü~m Ntj ~ -'880ii'ss e ! 5-1/2" T8G, 17#, L-80, .0232 bpf, 10" 4.892" H 113-3/8" CSG, 72#, N-80, 10= 12.347" H [Minimum ID = 2.377" @ 11733' I 3-3/16" X 2-7/8" SUB XO JOINT TOPOF 7-5/8" LNR-TIEBACK H !7-5/8" LNR-TBK, 29.7#, NT-80, .0459 bpf, 10 =: 6.875" H I TOP OF 7" LNR H r TOP OF CEMENT H 19-5/8" CSG, 47#, L-80, 10 = 8.681" -i ST MO NO ~ 1 3597 3056 2 6941 5444 3 9100 7148 4 9205 7237 02-168 ) 29' . 3029' ~ l 8454' r-w L 9299' I l 9299' --¡-1ì 9306' ~ 9450' ~ . J~ 2 -~ 10754' 10766' 10790' 10790' 10810' 10840' 10909' 10922' 13-112" LNR, 8.81#, L-80, .0087 bpi, ID = 2.990" H 10840' 14-112" TBG. 12.6#, L-80, .0152 bpf. 10 = 3.958" H 10922' I 10949' -i2NOMECHWHIPSTOCKw/RA TAG I TOPOF 3-1/2" LNR- CT -i 11178' 13-1/2" LNR-CT, 9.3#, L-80, 10 = 2.992" H 11186' I 7" LNR, 29#, NT-80, 10 = 6.184" H 11305' 14-1/2" TBG, 12.6#, 13-CR-80, 10=: 3.958" H 11347' l2-7Iß"LNR-PORTED,6.5#,L-80,ID=2.441" 1-1 11520' ÆRFORA TION SUMMARY REF LOG: MCNLlCCL/GR ON 10/02/04 ANGLE AT TOP ÆRF: 85 @ 11310' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11310 - 11350 0 10102/04 2" 6 11370 - 11535 0 10/02/04 2" 6 11920 - 12320 0 10/02/04 2" 6 12560 - 12735 0 10/02/04 2" 6 12950 - 13200 0 10/02/04 2" 6 13270 - 13300 0 10/02/04 DATE 06/80 10/31/93 10/03/04 10/21/04 01/03/05 03/01/05 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK (02-16A) JLMITLH CTD SDTRCK (02-168) ITLH GL V C/O BMcLITlH PGLS PRONG PULLED /TLH PGLS PULLED 81 ." eSAFETY NOTES: ORIGINAL WELLBORE I NOT SHOWN ON THIS DIAGRAM 29' 1-15-1/2" X 4-112" XO I r 2103' 1-14-1/2" CAM TRDP-4A SSSV NIP, ID'-' 3.812" GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 48 TGPD DOME RK 16 10/21/04 39 TGPD SO RK 20 10f21104 33 TMPDX OMY BK 10/03/04 32 TMPDX DMY BK 10/03/04 9270' -i4-1/2" BAKER A3R I I MILLOUT WINDOW 10954' - 10962' 1-14-112" PARKER SWS NIP, 10'-' 3.812" H 7" BAKER SABL-3 PKR I H3-1/2" BKRDEA..OY SLV, ID= 3.00" I H EST TOP OF CEMENT H3-1/2" HES X NIP, ID = 2.813" I 1-13-1/2"X3-3/16"XO,ID=2.786" 1-{4-1í2" PARKERSWS NIP, 10 = 3.812" (BEHIND PIPE) 1-14-112" TBG TAIL WLEG (BEHIND PIPE) I !-i3-3f16" X 2-718" XO JOINT, 10 = 2.377" I ... 13-3/16" LNR, 6.2#, L-80, 1-1 11733' .0076 bpf, 10 == 2.80" IPBTD H 13593' I 2-7/8"LNR,6.16#,L-80..0058bpf,10=2.441" -i 13628' I ~-I 13685' DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 02-16B ÆRMITNo: 2041570 API No: 50-029-20448-02 SEC 36, T11N, R14E, 4589.95' FEl & 1417.31' FNL BP Exploration (Alaska) . STATE OF ALASKA _ RECEIVED ALASK L AND GAS CONSERVATION COM~ION MAR 1 2005 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 0 Re~P Qi~~ .cBf1AhG9mm\t\\2Pn Anc~nr~ 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-157 13. API Number 50- 029-20448-02-00 14. Well Name and Number: No. of Completions 1 a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4948' NSL, 807' EWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 3311' NSL, 3976' WEL, SEC. 26, T11N, R14E, UM Total Depth: 4967' NSL, 52' WEL, SEC. 27, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- __~~542 y- 5950868 _ Zone- ASP4 TPI: x- 682667 y- 5954392 Zone- ASP4 Total Depth: x- 681270 y- 5956014 Zone- ASP4 ~---~--~~-~--------- -------~--------- --~----------- 18. Directional Survey IBI Yes 0 No 21. Logs Run: MWD GR / ROP, MGR / CCL 1 CNL 22. One Other 5. Date Camp., Susp., or Aband. 10/3/2004 6. Date Spudded 9/24/2004 7. Date T.D. Reached 9/30/2004 8. KB Elevation (ft): 58.76' 9. Plug Back Depth (MD+ TVD) 13593 + 8879 10. Total Depth (MD+ TVD) 13685 + 8864 11. Depth where SSSV set (Nipple) 2103 MD 19. Water depth, if offshore N/ A MSL PBU 02-16B 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028308 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" 13-3/8" 9-5/8" 7-5/8" x 7" 3-1/2' x 3-3116' x 2-7/8" WT. PER Fr. 94# 72# 47# 29.7# / 29# 8.81# 16.2# 16.16# CASING, liNER AND CEMENTING RECORD SeTTING DePTH MD SETTING DePTHTVD HoL.E GRADe lOP BoTTOM lOP BoTTOM SIZg H-40 Surface 98' Surface 98' 32" 431 sx Permafrost N-80 Surface 3029' Surface 2676' 17-1/2"2500 sx Fondu, 400 sx PF 'C' L-80 1 SOO-95 Surface 9450' Surface 7447' 12-1/4" 1965 sx Class 'G', 300 sx PF 'C' NT-80 / 13Cr 8454' 10954' 6616' 8792' 9-518' x 8-112' 380 sx Class 'G' L-80 10790' 13628' 8671' 8872' 4-1/8'x3-3I4' 145 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 11310'·11350' 8915' - 8918' 11370' - 11535' 8918' - 8922' 11920' . 12320' 8917' . 8908' 12560' - 12735' 8909'·8907' 12950' - 13200' 8894' - 8887' 13270' - 13300' 8892' - 8894' 26. Date First Production: February 28, 2005 Date of Test Hours Tested PRODUCTION FOR 3/9/2005 6.1 TEST PeRIOD + Flow Tubing Casing Pressure CALCULATED + Press. 437 750 24-HouR RATE OIL-BBL 1,344 24. SIZE 4-1/2", 12.6#, L-80 25. DEPTH INTERVAL (MD) 2500' DEPTH SET (MD) 1 0922' PACKER SET (MD) 10766' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE GAs-McF 4,718 GAs-McF 18,561 WATER-BBL 4 WATER-BBL 16 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL -BBL 342 CHOKE SIZE I GAS-OIL RATIO 55 13,810 OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8FL MAR 1 4 lOO~ G,Ý -, GEOLOGIC MARKER. aRMATION TESTS 28. 29. Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10359' 8285' None Shublik A 10402' 8324' Shublik B 10422' 8342' Shublik C 10428' 8347' Shublik D 10478' 8393' 45SB 10491' 8404' 42SB 10574' 8479' Top CGL 10648' 8545' Base CGL 10726' 8615' 23SB 10815' 8692' 22TS 10867' 8732' 21TS 10947' 8787' Zone 1 B 11044' 8840' Zone 1A/TDF 11102' 8862' Base Sadlerochit 11535' 8922' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. , hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ . ~ Title Technical Assistant Date 02>"/0'" 05 PBU 02-16B 204-157 Prepared By NameINumber: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4694 Permit No.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a 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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . 02-16B Prudhoe Bay Unit 50-029-20448-01-00 204-157 Accept: Spud: Release: Ri: POST RIG WORK 10/19/04 RIG UP. START RIH WI 3.87" DRIFT. 1 0/20/04 SET PGSL AT 10776' SLM. TEST W/ LITTLE RED TO 1000# GOOD TEST, BLED DOWN TBG, lA, C/O IA VALVE. PULLED EQUALIZING PRONG FROM PGSL AT 10776' SLM. SET WHIDDON C-SUB AT 10772' SLM. 10/21/04 PULLED DGLV FROM ST#1 3597' SLM & ST#2 6932' SLM. SET GENERIC 1500# TRO WI 1/4" PORT AT 3586' SLM. SET DUAL CHECK O-GLV W/ 5/16" PORT AT 6932' SLM. PULLED WHIDDON C-SUB AT 10,766' SLM. COULD NOT PULL PGSL. RDMO. 10/25/04 ATTEMPTING TO SHEAR / PULL PGSL FROM 10,761' SLM. 10/26/04 JAR UP ON PGSL AT 10,761' SLM FOR-2 HRS W/ WELL FLOWING & AL OPEN. NO MOVEMENT. SET PRONG BACK IN PGSL & TEST TO 2500 PSI, HELD. JAR DOWN ON PGSL FOR 1 HR WI 2500 PSI ON TOP OF PLUG. PULL PRONG FROM PGSL. ATTEMPT TO PULL PGSL. IN PROGRESS. 10/27/04 ATTEMPT TO PULL PGSL FROM 10,761' SLM. SWAP TO BRAIDED LINE. 10/28/04 RECOVERED LOST TOOL STRING. CONTINUED BEATING UP ON PGSL AT 6000 # LBS. CUT 80' LINE REHEAD. 10/29/04 ATTEMPTED TO PULL PGSL. 10/30/04 RIH WI BAKER 3-118" FISHING TOOLS (4" HYD GS, UP/DOWN JARS, WT BAR, AND ACCELERATOR). LATCH FISH AT 10752' (DOWN). JAR BOTH UP AND DOWN ON FISH. NO MOVEMENT. POOH. 10/31/04 RIH W/ NEW SET OF BOWEN 3-118" UP/DOWN JARS AND TWO 3-5/8" WT BARS. CONTINUE JARRING ON FISH AT 10752' CTM. JAR 10K OVER (3 TIMES), 15K OVER (4 TIMES), 20K OVER (2 TIMES). JARS FAILED ON THIRD ATTEMPT AT 20K. UNABLE TO RESET / FUNCTION JARS EITHER UP OR DOWN. DECISION MADE TO POOH AND RDMO. PGSL FISH STILL IN HOLE> 4" G-FISHNECK, 52" OAL. 11/06/04 CONTINUE RU DS CTU #4. PERFORM BOP TEST. MU AND RIH WITH BAKER FISHING TOOLS W/4" HYD. GS SPEAR. SITTING DOWN ON ICE / HYDRATES. POOH AND PU 2.5" JSN. RIH TO 3800' AND JET TUBING W/ 60/40 MEOH BACK UP TO SURFACE. RBIH WI BAKER FISHING TOOLS W/ 4" GS SPEAR. SIT DOWN AND LATCH PLUG AT 10766' CTMD. BEGIN JARRING UP AT 30K OVER. WORK UP TO 40 K# OVER. JARRED 85 CYCLES TOTAL (75 UP LICKS, 10 DOWN LICKS). NO MOVEMENT OF FISH NOTED. RELEASE, POOH TO CUT PIPE AND CHANGE OUT JARS. .. 02-16B Post Rig Work summaaiShing Operations Page 2 . 11/07/04 CUT OFF 100' OF COIL. MU AND RIH WITH BHA #1, SAME AS RUN #1 (3.125" CTC, 3.125" CHECKS, 3.125" ACCELERATOR, 2 - 3.625" WEIGHT BARS, 3.125" BOWEN UPIDOWN JARS, 3.375" HYD. DISC., 3.125" RUPTURE DISC, 3.50" (4") HYD GS SPEAR). JARRED 75 CYCLES TOTAL AT 42,000# OVER STRING WEIGHT. MADE STRAIGHT PULL TO 50,000# OVER STRING WEIGHT, CHAINS STARTED TO SLIP. PUMP OFF PLUG AND POOH. PUMP 5 BBL 60/40 MEOH CAP ON WELL. DSO WILL ATTEMPT TO POP THE WELL AND FLOW THROUGH THE EQUALIZATION PORT IN THE PLUG BODY. WERE ABLE TO PUMP INTO THE WELL AT 1.2 BPM, 900 PSI WHP. RDMO. UNABLE TO RECOVER P-GSL PLUG BODY. 11/17/04 UNABLE TO LATCH PGSL AT 10755' SLM WI 4.5 GR. MAKE SEVERAL RUNS WITH 3" PUMP BAILER. MAKE SEVERAL RUNS WITH 2.25 BAILER. RAN 2.75 LIB MARKS OF FISHING NECK, MADE THREE 2.25 BAILER RUNS. RIH WI 4.5 GR TO 10761' SLM LATCH AND JARRED DOWN SEVERAL TIMES. RIH WITH KINLEY POWER JARS TO 10761' SLM. 11/18/04 RUN #1 FOR KINLEY POWER JAR. LATCH PGSL WI 4.5 GR AND BEAT FOR 25 MIN. RUN #2 KINLEY POWER JAR. INDICATIONS POWER JAR DID NOT GET A GOOD HIT DOWN. RUN 2.25 DRIVE DOWN BAILER. RETURNED A FEW CHUCKS OF MUD IN BAILER. RAN 4.5 GS LATCHED AT 10,756' SLM, BEAT ONE HOUR DID NOT MOVE. RUN #3 KINLEY POWER JAR TO 10757' SLM. JAR LOOKS LIKE IT HIT HARD. RIH WI 4.5 GS. 11/19/04 RAN 4.5 GS LATCHED PGSL AT 10757' SLM. JARRED 10 MINUTES NO MOVEMENT. PGSL STILL IN LINER TOP. 12/28/04 RIH WI VENTURI. VENTURI ON TOP OF PLUG. POH CIRCULATING HOLE TO FLUID. RIH WITH 4" GS. LATCH PLUG, HIT WITH 11 UPIDN LICKS-PLUG APPEARED TO COME FREE. WHP DROPPED F/300 TO 125, IA REMAINED AT 1225, CT DROPPED TO O. SET BACK DOWN TO VERIFY PLUG FREE. IT APPEARS GS SLIPPED OUT OF FN. CONTINUE JARRING UPIDN FOR TOTAL 50 JAR LICKS. RELEASE FROM PLUG AND POH. LD FISHING TOOLS, PU-DJN RIH TO ACIDIZE. JET 10BBLS 15% HCL ACID ON PLUG, LET SOAK 30 MIN. POH I FP TO 2600'. RIH WITH FISHING ASSEMBLY. LATCH FISH AND BEGIN JARRING AT 5K OVER. WORK UP TO 19K OVER. 12/29/04 CYCLE OUT PIPE. POH. MU 4" GS W/3 WT BAR AND RIH. ENGAGE FISH AND MAKE A TOTAL OF 50 JAR LICKS (20 UPIDN, 30 UP ONLY). ALL JAR LICKS MADE WI -21 K OVER. JARRED ON FISH WNARYING WELL HEAD PRESSURES. FISH DID NOT COME FREE. FP TUBING WHILE POOH. CUT 150' OF PIPE. RIH WIMILL & MOTOR. 12/30/04 IH WITH CUSTOM MADE MILUMOTOR. PUMP 10 BBL FLO PRO, CHASE OUT AT 80%. POOH TO CHECK CONDITION OF MILL. SEVERAL BUTTONS BROKEN OFF THE FINGER MILL, LOOKS LIKE THERE ARE APPROX 1/2" INCH OF THREADS LEFT TO BE MILLED ON BAIT SUB. MU 2 5/8" VENTURI AND RIH. TAG FISH AT 10781' CTMD. MAKE SEVERAL UPIDN PASSES TO THIS DEPTH WHILE VENTURING. POOH. MU PDM W/3.625" OD RE-DRESSED MILL AND RIH. TAG FISH AT 10779' CTMD. START MILLING. PUMP 10 BBLS FLO PRO AND CHASE OUT AT 80 %. FREEZE PROTECT TUBING TO 3000'. SURFACE CHECK MILL. RECOVERED BAIT SUB. 12/31/04 RECOVERED BAIT SUB. CHANGE OUT PACKOFFS AND PERFORM CHAIN INSPECTION. WELL IS FREEZE PROTECTED TO 3000' WITH 60/40 METHANOL. RD. 01/03/05 PULLED 41/2" PGSL TOP SUB AND ASSEMBLY LATCH PGSL CORE WI 2.7" GRAPPLE AND 41/2" BAIT SUB. , " 02-16B Post Rig Work SUmmaeiShin9 Operations Page 3 . 01/04/05 ATTEMPT TO PULL PGSL. 01/05/05 ATTEMPT TO PULL PGSL PRONG, GRAPPLE AND BAIT SUB LATCHED IN TO PGSL PRONG. 01/20/05 ATTEMPTED TO FISH OUT REMAINING PGSL (RECOVERED BAIT SUB AND OVERSHOT WI GRAPPLE) RETURNED WELL TO PAD OP. 01/31/05 RIH WITH BAKER MOTOR I WASHOVER SHOE. SAT DOWN ON P-GSL AT 10783' CTMD. MILLED ON P-GSL FOR 3.5 HOURS. DID NOT SEE ANY CONSISTENT MOTOR WORK. POH TO INSPECT TOOLS. FOUND VISIBLE WEAR ON OUTSIDE OF BURNOVER SHOE TO 11.5", 1ST TATTLE-TAIL AT 6" GONE, 2ND TATTLE- TAIL AT l' 6" STILL THERE, SOME MINOR WEAR ON LEADING EDGE OF SHOE NOTED. EVALUATE OPTIONS, AMBIENT TEMP CONTINUES TO DROP (-39 DEG F). 02102105 RIH WTIH BAKER FISHING TOOLS (BHA #2). STARTED SEEING INCONSISTENT PIPE WEIGHTS. PUH AND FOUND PIPE UNABLE TO MOVE. SUSPECT POSSIBLE HYDRATES AT 6941' (GLM #2). STARTED PUMPING DOWN IA AND PIPE CAME FREE. PUH TO 4000' AND CIRCULATE IN METHANOL WHILE LOADINGIA WITH HOT CRUDE. RBIH WI FISHING TOOLS. 02103/05 RIH WITH BAKER FISHING TOOLS (BHA #2). SAT DOWN AT 11,777' CTMD. ATTEMPT SEVERAL TIMES TO LATCH FISH WITH NO SUCCESS. POOH. MARKS ON TOOL INDICATE THAT THEY WERE SETTING DOWN ON THE TOP OF THE DEPLOYMENT SLEEVE. RE-CONFIGURE FISHING TOOL STRING. RIH WITH BAKER FISHING TOOLS (BHA #3). SAT DOWN AT 11,775' CTMD. ATTEMPT SEVERAL TIMES TO LATCH FISH WITH NO SUCCESS. POOH. MARKS ON TOOL INDICATE THAT THE TOOL IS STILL SETTING DOWN ON THE TOP OF THE DEPLOYMENT SLEEVE. 02127/05 PLANTED BAKER OVERSHOT ON PGSL AT 10,763' SLM. ATTEMPTED TO PULL PGSL CORE WI .125" WIRE WITH NO SUCCESS. RIG DOWN SIL, RIG UP BRAIDED LINE. JARRED FOR 1 HR AT 3500 #, NO MOVEMENT. 02128/05 ATTEMPT TO PULL PGSL WI BRAIDED LINE. FLOW WELL TO LIFT HYDROSTATIC HEAD OFF. (WELL FLOWING 800 BPD, 11 MMSCFD) PAD OPERATOR ROUTE TO LP AND WILL PLACE BACK INTO TEST SEP. AT 0100 HRS BEFORE ATTEMPTING FISH. WELL TEMP IS STILL INCREASING AT MIDNIGHT. 03/01/05 FLOWED WELL FOR TOTAL OF 8 HRS, WELL WAS IN TEST MAKING - 2700 BBLS A DAY. SHUT IN WELL. RECOVERED PGSL CORE AT 10,726' BLM. GAVE WELL BACK TO DSO TO POP. . . ¿20V-/57 !2..c¡'¡9 WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 03, 2004 RE: MWD Formation Evaluation Logs: 02-16B, AK-MW-3297732 1 LDWG formatted Disc with verification listing. ~I#: 50~29-20448-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE AITENTION OF: Speny-Sun 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 1#/ " I STATE OF ALASKA .. ALASKA L AND GAS CONSERVATION COMM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, LINER AND CEMENTING RECORD SETTINGDEP1'HMD .SSTTING.·DI:PTH'rVD' BÓTIóM +OP Bo~OM 98' Surface 98' 3029' Surface 2676' 9450' Surface 7447' 10954' 6616' 8792' 13628' 8671' 8872' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4948' NSL, 807' EWL, SEC. 36, T11 N, R14E, UM Top of Productive Horizon: 3311' NSL, 3976' WEL, SEC. 26, T11 N, R14E, UM Total Depth: 4967' NSL, 52' WEL, SEC. 27, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 687542 y- 5950868 Zone- ASP4 TPI: x- 682667 y- 5954392 Zone- ASP4 Total Depth: x- 681270 y- 5956014 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD GR / Rap, MGR I CCL I CNL 22. 20" 13-3/8" 9-5/8" 7-5/8" x 7" 94# 72# 47# 29.7# 129# H-40 Surface N-80 Surface L-80 I SOO-95 Surface NT-80 I 13Cr 8454' L-80 10790' 3-1/2" x 3-3/16" x 2-7/8" 8.81# / 6.2# / 6.16# 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 11310' - 11350' 8915' - 8918' 11370' - 11535' 8918' - 8922' 11920' -12320' 8911' - 8908' 12560' - 12735' 8909' - 8901' 12950' - 13200' 8894' - 8881' 13270' - 13300' 8892' - 8894' One Other 5. Date Camp., Susp., or Aband. 10/3/2004 6. Date Spudded 9/24/2004 7. Date ToO. Reached 9/30/2004 8. KB Elevation (ft): 58.76' 9. Plug Back Depth (MD+ TVD) 13593 + 8879 10. Total Depth (MD+ TVD) 13685 + 8864 11. Depth where SSSV set (Nipple) 2103 MD 19. Water depth, if offshore N/A MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-157 13. API Number 50- 029-20448-02-00 14. Well Name and Number: PBU 02-16B 15. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028308 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 32" 431 sx Permafrost 17-1/2" 2500 sx Fondu, 400 sx PF 'C' 12-1/4" 1965 sx Class 'G', 300 sx PF 'C' 9-518" x 8-1/2" 380 sx Class 'G' 4-1/8" x 3-3/4" 145 sx Class 'G' 24. SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 10922' PACKER SET (MD) 10766' DEPTH INTERVAL (MD) 2500' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA all -BSl GAs-McF W A TER-BSl GAs-McF W A TER-BSl 26. Date First Production: Not on Production Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED -.a.. Press. 24-HoUR RATE"""" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Oll-Bsl '1 None 1. "øY'rJ . ~f:D t ,. _._. ,< ·,1 Form 10-407 Revised 12/2003 DUPLICATE CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-all RATIO all GRAVITY-API (CORR) RBDMS BFL NOV - 9 2DM l1i~ 2~. e 29. "RMATION TESTS GEOLOGIC MARKERS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10359' 8285' None Shublik A 10402' 8324' Shublik B 10422' 8342' Shublik C 10428' 834 7' Shublik D 10478' 8393' 45SB 10491' 8404' 42SB 10574' 8479' Top CGL 10648' 8545' Base CGL 10726' 8615' 23SB 10815' 8692' 22TS 10867' 8732' 21TS 10947' 8787' Zone 1 B 11044' 8840' Zone 1A 1 TDF 11102' 8862' Base Sadlerochit 11535' 8922' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~r\.(=( ~ Title Technical Assistant Date ll- 03....0 l.( PBU 02-16B 204-157 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4694 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a 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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e ,e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/19/2004 01 :00 - 02:30 1.50 MOB P PRE SAFETY MEETING. Held pre-rig move meeting with security, CPS, Nordic, Schlumberger and BP. Reviewed rig move procedure, hazards and mitigation for rig move. 02:30 - 11 :15 8.75 MOB P PRE Moved rig from S pad to the Frontier corner on the spine road, when a 1" hydraulic hose to the rigs front right hydraulic drive gear failed at 11: 15 AM and 20 gallons of hydraulic oil was spilled on the spine road. The crew immediately stopped the rig and source of the hydraulic power. The spill was immediately contained on the spine road and security and spill response was notified. 11 :15 - 13:00 1.75 MOB N RREP PRE Rig crew cleaned up spill with absorbent as good as possible. Replaced 1" hydraulic hose to drive system and backed rig away from spill area. The spill was cleaned up further and absorbent was laid over the spill area. The rig pulled forward and ACS came in behind the rig and spread absorbent material over the spill area and swept it up. The spill was reported as a 20 gal reportable spill. An incident report will be written. 13:00 - 22:30 9.50 MOB P PRE Moved rig from Frontier corner to DS 02-16B. 22:30 - 22:45 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitgation for backing rig over well. Well is dead and all valves are closed. 22:45 - 23:00 0.25 MOB P PRE Backed rig over well and sat rig down. ACCEPT NORDIC 1 ON DS 02-16B AT 2300 HRS, 09/19/2004. 23:00 - 00:00 1.00 BOPSUPP PRE Nipple up BOPE. Spot trailers and cuttings tank. Installed dikes in rig cellar. 9/20/2004 00:00 - 01 :30 1.50 BOPSUP P PRE Nipple up BOPE. Spot equipment. General rig up. 01 :30 - 05:00 3.50 BOPSUF P PRE Pressure I function test BOPE. Send test report to AOGCC. Fill rig pits with 2% KCL with 2# Biozan. 05:00 - 07:00 2.00 STWHIP P WEXIT M/U Baker CTC. Pull test. C/O pack-off. 07:00 - 08:30 1.50 STWHIP P WEXIT MU BHA. Fill coil with 2# Biozan KCL water. 08:30 - 10:45 2.25 STWHIP P WEXIT RIH 10:45 - 18:00 7.25 STWHIP P WEXIT Mill window. 2.4 bpm @ 2100 psi. FS=1900 psi 50 K Up Wt, !3K On Wt. Mill from 10,985 to 10,997'. Exit poiint of window not clear. No stalls milling window. 18:00 - 19:30 1.50 STWHIP P WEXIT Mill formation, Slow ROP, stacking wt, 2.5/2.5 bpm, 1950- 2400 psi. 6K WOB, Milled to 10,998'. Back ream window, 48K up wt. No motor work up thru window. Ream to bottom with no motor work. Tag bottom at 10,997.5 ft. 19:30 - 21 :30 2.00 STWHIP P WEXIT Milling formation, Slow ROP. Swap to FloPro. Mill down to 11,000'. 2.5/2.5 bpm, 2680 - 3000 psi, 1.5 fph. Backream window at 1 fpm. 44K up wt with FloPro. Window clean, no motor work. 21 :30 - 22:30 1.00 STWHIP P WEXIT Ream down clean to TO of 10,999'. Backream. RIH clean with no pump. Window is clean. 22:30 - 00:00 1.50 STWHIP P WEXIT POH. circ at 2.4 bpm, 2500 psi. Circ. while POH to surface. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 7/7/1980 End: 9/19/2004 1 0/3/2004 N1 POH with milling BHA. Circ to surface. UO milling BHA. Recover 100% of BHA. Mill was worn across the face. M/U SWS CTC. Pull test and press test CTC. SAFETY MEETING. Pre-Spud meeting with crew. Review well plane and hazards. PJSM for M/U MWD BHA. Review procedure, hazards and mitigation for M/U MWD BHA. M/U MWD Build BHA #2. 4.125" HC Bi-center bit, 2.29 deg motor and Sperry MWD. OAL = 65.32 ft. RIH with build MWD BHA. SHT tools, OK. Got 2 for 2 clicks with orienter. RIH. Stop at flag, correct -31 ft CTD. Orient TF to 50L. Trouble getting clicks. TF readings may not be correct. Log GR tie-in in 7" to confirm depths. Added 28 ft to CTD. Whipstock appears to have been set about 30 ft deep when it was set on coil. RIH and tag TO at 11,026 ft. Top of whipstock should be at 11,007 ft. Top of window at 11,012 ft. Drill build section, stall at 11,026 ft. Time drill 11 028. Start to drill off 3550 psi @ 2.54 bpm, 3400 psi FS. Pick up seeing overpulls and motor work at 11022'. Orienter failed. POH for failed orienter. C/O orienter and MWD probe. Bit was trashed, graded at 8,8,1/8". It was drilling on and beside metal. M/U 3.80" HC diamond window mill and string reamer to dress window. Checked scribe offset, OK. RIH with 3.80" HC Diamond window mill, string reamer and 2.29 deg motor. BHA #3. OAL = 66.27 ft. SHT tools OK, 2 for 2 clicks with orienter. RIH. Orient TF to 54L. one for one on clicks. Log tie-in with GR inside 7" liner. [-9 ft CTD]. Ream window. Tag TO at 11,028.5 ft. Clean hole to TD. No stalls or motor work in window track. Mill forward, 2.5 / 2.5 bpm, 3400 - 3800 psi, 43L TF, 4-6K WOB, Milled to 11,030 ft. DPRB WEXIT Mill window, very slow progress, 2.6/2.6 bpm, 3200 - 3850 psi, 43L TF, 5-6K WOB, Milled to 11,030.9 ft. Back ream to get free spin of 3450 psi, dwn wt of 14.5K, Tag at 11,031'. Continue milling with 45L TF, 2.5/2.5bpm 3450/4040psi, 3-5k WOB. Mill to 11033'. Mill to 11033.3' with 49L 2.5/2.5bpm 3450/4040psi, 4-5k WOB. Stacking wt. P/U & establish freespin @ 2.5bpm/3500psi. Up Wt = 34.5k. S/O wt = 15k. Ease back into milling. Mill to 11035' with 54L 2.5/2.5bpm 3450/4040psi, 5-6k WOB. Mill to 11036' with 54L 2.5/2.5bpm 3450/4040psi, 6-7k WOB. Mill to 11037' with 54L 2.5/2.5bpm 3450/4040psi, 6-7k WOB. Stall @ 11037.2'. P/U & establish freespin @ 2.5bpm/3400psi. Up Wt = 34.5k. S/O wt = 14k. Ease back into milling. Drill into 9/21/2004 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 01:15 0.75 STWHIP P WEXIT 01:15 - 01:30 0.25 STWHIP P WEXIT 01 :30 - 02:30 1.00 STWHIP P WEXIT 02:30 - 04:30 2.00 STWHIP P WEXIT 04:30 - 05:30 1.00 STWHIP P WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 07:00 0.50 STWHIP P WEXIT 07:00 - 10:40 3.67 STWHIP N DPRB WEXIT 10:40 - 12:30 1.83 STWHIP N DPRB WEXIT 12:30 - 13:30 1.00 STWHIP N DPRB WEXIT 13:30 - 15:30 2.00 STWHIP N DPRB WEXIT 15:30 - 15:40 0.17 STWHIP N DPRB WEXIT 15:40 - 16:00 0.33 STWHIP N DPRB WEXIT 16:00 - 17:30 1.50 STWHIP N DPRB WEXIT 17:30 - 18:30 1.00 STWHIP N 18:30-19:15 0.75 STWHIP N DPRB WEXIT 19:15-19:30 0.25 STWHIP N DPRB WEXIT 19:30 - 20:15 0.75 STWHIP N DPRB WEXIT 20: 15 - 20:35 0.33 STWHIP N DPRB WEXIT 20:35 - 22:30 1.92 STWHIP N DPRB WEXIT Printed: 10/4/2004 7:32:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 7/7/1980 End: 9/19/2004 10/3/2004 N1 9/21/2004 20:35 - 22:30 1.92 STWHIP N DPRB WEXIT 22:30 - 00:00 1.50 STWHIP N DPRB WEXIT 9/22/2004 00:00 - 00:40 0.67 STWHIP N DPRB WEXIT 00:40 - 01 :30 0.83 STWHIP N DPRB WEXIT 01 :30 - 01 :40 0.17 CLEAN N DPRB WEXIT 01 :40 - 01 :50 0.17 CLEAN N DPRB WEXIT 01 :50 - 02:45 0.92 CLEAN N DPRB WEXIT 02:45 - 04:25 1.67 CLEAN N DPRB WEXIT 04:25 - 04:35 0.17 CLEAN N DPRB WEXIT 04:35 - 04:45 0.17 CLEAN N DPRB WEXIT 04:45 - 07:30 2.75 CLEAN N DPRB WEXIT 07:30 - 08:20 0.83 CLEAN N DPRB WEXIT 08:20 - 10:20 2.00 CLEAN N DPRB WEXIT 10:20 - 10:50 0.50 WHIP N DPRB WEXIT 10:50 - 12:00 1.17 WHIP N DPRB WEXIT 12:00 - 14:30 2.50 WHIP N DPRB WEXIT 14:30 - 15:45 1.25 WHIP N DPRB WEXIT 15:45 - 16:20 0.58 WHIP N DPRB WEXIT hard spot (suspect CIBP) @ 11038'. Let mill burn for 30m ins @ 11038.3' - no progress. Check btm samples - > 99% cmt & steel. Decide to pull for an underreamer. Paint EOP Flag @ 10800' & POOH milling BHA. Continue POOH milling BHA. OOH. PJSM. SIB injector & UD milling BHA #2. Observe very loose lower motor bearing. No major marks on mills. Held PJSM & HNHM for reheading CT & M/U under-reaming BHA#3. Cut 5.5' CT & install Baker slip CTC. Pull test to 35k & PT to 3500psi - OK. M/U under-reaming BHA #3 with 3-5/8" DB under-reamer, Baker Xtreme motor, 2 jts of 2-3/8" PH6 tbg & MHA (OAL - 85.57'). Stab injector on well. RIH with under-reaming BHA #3 without pumping. Correct CTD -12' @ the flag. RIH BHA #3 below TT to 10940'. Up wt check = 44k, Down Wt = 17k. Bring on pumps & establish freespin @ 2.2bpm/2580psi. Under-ream down in the 7" from 10940' to 11010' with flopro mud @ 2.22/2.22bpm, 2580psi. Observe no motor work. PUH to 10940'. Under-ream 7" up/down 4x from 10930' to 11010' @ 2.2/2.2bpm, 2550psi & 4fpm. Meanwhile W.O vac trucks to swap the well back to KCL for setting the next WS. No motor work seen. Liner should be clean from 10930 - 11010'. Drop 3/4" steel ball to open circ sub. Ball on seat at 50 bbls. Swap to KCL water. POH chasing FloPro to surface with KCL water. 3.1 bpm, 1500 psi. Flag CT at 10,800' EOP. POH. SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. Review procedure for M/U whipstock and running tools. UO BKR Underreamer BHA. M/U BKR 7" Gen II whipstock with FAIV, Sperry MWD, Orienter and MHA. Insert 2 RA PIP tags in whipstock, 10 ft from top of whipstock. RIH with Baker 7" Gen II whipstock, FAIV and Sperry MWD. SHT at 1400'. Circ. at 1.6 bpm, good data and tested orienter OK. RIH. Correct to EOP flag at 10,800'. Added 4 ft CTD. Log GR tie-in at 10945'. Log down in 7" liner. Subtract 4 ft CTD. 40K up wt. Circ. at 0.6 bpm to get Sperry data. Orient Whipstock TF to 9L of high side. Top of whipstock at 10950' per Anc. Eng. Increase pump to 2.1 bpm, 2.3, 2.6, 2.9, 3.0 bpm, FAIV Armed. Stop pump, pump 0.2 bpm, FAIV sheared and set whipstock at 2900 psi. Final Whipstock TF was 8R, got a final click when dropped pump to set whipstock. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/22/2004 15:45 - 16:20 0.58 WHIP N DPRB WEXIT Whipstock set with top at 10,950'. Tray TF at 8R of high side. RA tag at 10,960' 16:20 - 18:00 1.67 WHIP N DPRB WEXIT POH with whipstock running tools. 18:00 - 18:30 0.50 WHIP N DPRB WEXIT UO whipstock setting tools with FAIV, Sperry MWD, Oríenter and MHA 18:30 - 20:30 2.00 WHIP N DPRB WEXIT M/U Cementing BHA with 3.0" big hole nozzle, 6' x 2-3/8" PH6 pup, XO & CTC (OAL - 7.89') 20:30 - 21 :00 0.50 WHIP N DPRB WEXIT RIH with cementing BHA. Wt chk @ 10900' - Up = 40k, Run-in = 21 k. Lightly tag WS pinch pt 2x @ 10972'. Correct CTD to 10954.6'. Set down 2k on WIS. P/U with 2k O/pull. PUH to 10940' & flag pipe. Meanwhile R/U SLB Cementers & prime up. 21 :00 - 21 :15 0.25 WHIP N DPRB WEXIT SI well & confirm Obpm injectivity @ 1000psi - saw slight pressure bleeding-off. 21 :15 - 21 :30 0.25 WHIP N DPRB WEXIT PJSM with all personnel concerning cementing operations. 21 :30 - 22:45 1.25 WHIP N DPRB WEXIT Flush/PT lines to 4k. Mix & pump 5bbls 15.8ppg class 'G' cmt slurry & 5bbls of water behind @ 2.0/2.0bpm & 1070psi. Chase with KCL water @ 2.5/2.5bpm & 2000psi. Pump 1 bbl of cmt out of nozzle. POOH laying in remaining cmt @ 1: 1. Observe pin-hole in CT on the reel @ +/-10780'. Continue POOH to 10000'. TOC - +/-10650'. 22:45 - 23:15 0.50 WHIP N DPRB WEXIT Circulate down bio-KCL to nozzle @ 1.4bpml700psi with mist oozing out of pin-hole. 23:15 - 00:00 0.75 WHIP N DPRB WEXIT RBIH to 10760' (below SWS nipple) contaminating cmt @ 1.0bpm/500psi. Swap well to bio-KCL milling fluid. 9/23/2004 00:00 - 02:40 2.67 WHIP N DPRB WEXIT POOH chasing cmt contaminated fluid OOH & jetting across nipples. 02:40 - 02:50 0.17 WHIP N DPRB WEXIT OOH. UD cmt nozzle BHA 02:50 - 03:00 0.17 WHIP N DPRB WEXIT M/U swizzle stick & jet BOP stack. Flush choke manifold lines. 03:00 - 03:10 0.17 WHIP N SFAL WEXIT PJSM for B/D CT with N2. 03: 10 - 03:45 0.58 WHIP N SFAL WEXIT PfTest N2 lines - OK. B/D CT with N2 & bleed off. SIB injector & UD swizzle stick. 03:45 - 04:00 0.25 WHIP N SFAL WEXIT PJSM for stripping off & pulling back CT to the reel. 04:00 - 04:45 0.75 WHIP N SFAL WEXIT Slip connector into CT & pull test. Strip-off CT from injector & spool back to reel. 04:45 - 05:15 0.50 WHIP N SFAL WEXIT Secure CT & prep reel for shipment. 05:15 - 08:15 3.00 WHIP N SFAL WEXIT RD hardline to reel. ETA for new CT reel - 06:30hrs & ETA for Peak crane - 07:00hrs. 08:15 - 08:30 0.25 WHIP N SFAL WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for picking reel with Peak crane and setting in new reel of coil. 08:30 - 12:00 3.50 WHIP N SFAL WEXIT Pick reel with crane. Remove reel bushings and install new reel bushing. Pick replacement reel of coil and set in reel stands. Insert reel bushings into reel. 12:00 - 13:30 1.50 WHIP N SFAL WEXIT Pull coiled tubing to injecter head and stab into chains. MIU Baker CTC and pull test. RIU hardline inside reel. 13:30 - 14:00 0.50 WHIP N SFAL WEXIT Fill coil with Biozan, 2.8 bpm, 1200 psi. 14:00 - 15:00 1.00 STWHIP N DPRB WEXIT M/U window milling BHA with 3.80" HC diamond window mill, string reamer, straight motor, 2 jts PH6 and MHA. OAL = 84.7 ft. 15:00 - 17:00 2.00 STWHIP N DPRB WEXIT RIH with window milling BHA. BHA #5. Tag firm cement at 10,766'. SWS UCA cement sample at 2500 psi. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/23/2004 17:00 - 18:30 1.50 STWHIP N DPRB WEXIT Mill firm cement, 2.6 bpm, 2000 psi, 70 fph, Stall at 10,795'. Soft cement below this depth, Mill soft cement at 110 fph. 300 psi motor work. 2K WOB. Milled soft cement to 10,900 ft. Pick up WI = 44K, Down WI = 15k. 18:30-19:15 0.75 STWHIP N DPRB WEXIT Milling soft cement at 110 fph, 2.6 bpm, 1650-2100 psi, 2K WOB. Stall @ WS/Lnr pinch pt - 10956'. Flag pipe & correct depth to 10954.6'. Up WI = 44.5k. S/O WI = 14k. Freespin = 2.55bpm/1570psi. 19:15-19:45 0.50 STWHIP N DPRB WEXIT Start milling window with 2.55/2.55bpm 1570/1670psi, 1-2k WOB. Mill to 10955'. 19:45 - 20:45 1.00 STWHIP N DPRB WEXIT Mill to 10956' with 2.55/2.55bpm 1570/1950psi, 2k WOB. 20:45 - 21 :35 0.83 STWHIP N DPRB WEXIT Mill to 10957' with 2.55/2.55bpm 1570/2050psi, 3k WOB. 21 :35 - 22:45 1.17 STWHIP N DPRB WEXIT Mill to 10958' with 2.55/2.55bpm 1570/2050psi, 4k WOB. 22:45 - 00:00 1.25 STWHIP N DPRB WEXIT Mill to 10959.5' with 2.55/2.55bpm 1570/2050psi, 5k WOB. 9/24/2004 00:00 - 00:20 0.33 STWHIP N DPRB WEXIT Mill to 10960' with 2.55/2.55bpm 1570/2050psi, 6k WOB. Mill should be @ window mid point. 00:20 - 03:00 2.67 STWHIP N DPRB WEXIT Control mill to 10962' with 2.55/2.55bpm 1570/2250psi, 4k WOB. Stall @ 10962.5'. P/U & establish freespin @ 2.55bpm/2000psi. Ease back into milling & exit Inr. 03:00 - 03:40 0.67 STWHIP N DPRB WEXIT Mill formation to 10972' with 2.55/2.55bpm 2000/2450psi, 3k WOB & 25fph ave ROP. Geo seeing formation in BU samples. 03:40 - 05:00 1.33 STWHIP N DPRB WEXIT Swap well bore to reconditioned flopro mud. Meanwhile backream & dress window/rat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWS = 10950', TOW = 10954.6', BOW = 10962.5', RA PIP Tag = 10960'. 05:00 - 07:45 2.75 STWHIP N DPRB WEXIT Paint EOP flag @ 10800' & POOH window milling BHA. POH. Circ to surface. 07:45 - 08:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U MWD BHA. 08:00 - 09:15 1.25 DRILL P PROD1 M/U Build / Turn MWD BHA # 8 with HC Bi-center bit, 1.69 deg motor, MWD, orienter and MHA. OAL = 09:15-11:15 2.00 DRILL P PROD1 RIH with BHA #8. SHT tools at 1400 ft. All tested OK. RIH. Correct -13 ft CTD to EOP flag at 10,800'. 11:15-11:40 0.42 DRILL P PROD1 Orient TF to 50L. 11 :40 - 11 :50 0.17 DRILL P PROD1 RIH thru window. Clean window. Tag TO at 10,971 ft. 11 :50 - 13:30 1.67 DRILL P PROD1 Drilling 22 Build / turn section, 2.6/2.6 bpm, 3230 - 3900 psi, 50L TF, 62 deg incl, 50 fph, Drilled to 11047' 13:30 - 13:45 0.25 DRILL P PROD1 Orient TF to 66L. 13:45 - 14:15 0.50 DRILL P PROD1 Log GR tie-in with GR in original open hole. Subtract 1 ft CTD. TOWhipstock at 10,949', TOWindowat 10,954', RA tag at 10,959'. 14:15 - 15:45 1.50 DRILL P PROD1 Drilling 22 Build / turn section, 2.6/2.6 bpm, 3230 - 3900 psi, 66L TF, 67 deg incl, 50 fph, Drilled to 11,086' 15:45 - 17:30 1.75 DRILL P PROD1 Drilling 22 Build / turn section, 2.6/2.6 bpm, 3230 - 3900 psi, 78L TF, 70 deg incl, 40 fph, Drilled to 11,128' 17:30 - 17:50 0.33 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 17:50 - 18:45 0.92 DRILL P PROD1 Drilling 22 Build / turn section, 2.6/2.6 bpm, 3230 - 3900 psi, 72L TF, 71 deg incl, Stacking weight. Drill thru shale @ 11150'. 18:45 - 19:10 0.42 DRILL P PROD1 Drill to 11181' with 90L TF, 2.6/2.6bpm 3250/3600psi, 3k WOB & 85fph ave ROP. 19:10-19:20 0.17 DRILL P PROD1 Orient 1 click & drill to 11190' with 80L TF, 2.6/2.6bpm Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/24/2004 19:10 - 19:20 0.17 DRILL P PROD1 3250/3600psi, 4k WOB & 45fph ave ROP. 19:20 - 19:55 0.58 DRILL P PROD1 Orient 1 click & drill to 11209' with 55L TF, 2.6/2.6bpm 3250/3600psi, 6k WOB & 35fph ave ROP. Stacking wt. 19:55 - 20:05 0.17 DRILL P PROD1 Orient TF to 30L. Up wt = 43k. Run-in wt = 11 k. 20:05-21:10 1.08 DRILL P PROD1 Drill to 11250' with 30L TF, 2.6/2.6bpm 3250/3600psi, 4k WOB & 35fph ave ROP. Very ratty drilling with heavy PIUs. 21:10 - 21:30 0.33 DRILL P PROD1 Wiper trip clean to window. RBIH. 21 :30 - 22:50 1.33 DRILL P PROD1 Drill to 11296' with 30L TF, 2.6/2.6bpm 3250/3600psi, 4k WOB & 35fph ave ROP. Very ratty drilling with heavy PIUs. 22:50 - 23:05 0.25 DRILL P PROD1 Orient TF around to 85L. 23:05 - 23:35 0.50 DRILL P PROD1 Drill to 11312' with 90L TF, 2.6/2.6bpm 3560/4000psi, 5k WOB & 35fph ave ROP. 23:35 - 23:55 0.33 DRILL P PROD1 Orient 2 clicks & drill to 11321' with 70L TF, 2.6/2.6bpm 3560/4000psi, 4k WOB & 30fph ave ROP. 23:55 - 00:00 0.08 DRILL P PROD1 Orient TF to 15A. 9/25/2004 00:00 - 00:15 0.25 DRILL P PROD1 Drill to 11329' with 35R TF, 2.6/2.6bpm 3560/4000psi, 5k WOB & 35fph ave ROP. 00:15 - 00:50 0.58 DRILL P PROD1 Orient 2 clicks & drill to 11346' with 45R TF, 2.6/2.6bpm 3560/4000psi, 7k WOB & 35fph ave ROP. Wt stacking. 00:50 - 02:30 1.67 DRILL P PROD1 Orient 2 clicks & drill to 11393' with 90R TF, 2.6/2.6bpm 3560/4000psi, 7k WOB & 30fph ave ROP. Land well @ 11366". 02:30 - 03:25 0.92 DRILL P PROD1 Orient 2 clicks & drill to 11421' with 115R TF, 2.6/2.6bpm 3560/4000psi, 6k WOB & 30fph ave ROP. 03:25 - 04:40 1.25 DRILL P PROD1 Short wiper trip to 11300'. RBIH. Meanwhile swap the well to (50% reconditioned / 50% new) flopro mud. 04:40 - 05:40 1.00 DRILL P PROD1 POOH for lateral BHA & tractor. 05:40 - 06:00 0.33 DRILL P PROD1 OOH. PJSM. SIB injector. Flush BHA. 06:00 - 07:00 1.00 DRILL P PROD1 C/O to lateral BHA with new HC bi-center bit, adjust motor to 1.37 deg, C/O Sperry Probe. M/U Welltec tractor above MWD tools. 07:00 - 08:00 1.00 DRILL P PROD1 Test Welltec tractor at surface with injecter head raised as high as possible above rig floor. Upper 4 sets of wheels exposed, 1 set of lower wheels were inside lubricator. Each set has 4 wheels for a total of 20 drive wheels. Test tractor 3 times, opening wheels at 2.2 bpm, operating at 2.5 bpm, closing wheels at 1.5 bpm. Tractor tested OK. 08:00 - 08:15 0.25 DRILL P PROD1 M/U orienter and MHA above tractor, M/U injector head. OAL = 93.2 ft. 08:15 - 10:25 2.17 DRILL P PROD1 RIH with Lateral MWD / Tractor BHA #9 with 1.37 deg motor and 4.125' HC bi-center bit. SHT MWD tools and orienter - OK. RIH. 10:25 - 10:45 0.33 DRILL P PROD1 Run thru window clean to 11050'. Test tractor to see if drive wheels are opening and working at 2.5 bpm. Good test. 10:45 - 11 :00 0.25 DRILL P PROD1 Log GR tie-in with RA tag. -13 ft CTD. 11 :00 - 11 :20 0.33 DRILL P PROD1 RIH clean to TO. Circ. at 1.5 bpm. Tag at 11,428'. 11 :20 - 11 :40 0.33 DRILL P PROD1 Orient TF to 80A. 11 :40 - 13:00 1.33 DRILL P PROD1 Drilling lateral with Tractor. 2.6 / 2.6 bpm, 3500-4100 psi, 95R TF, 90 deg incl, 60 fph, Stacking wt, several stalls. Drilled to 11460'. 13:00 - 15:30 2.50 DRILL P PROD1 Drilling lateral with Tractor. 2.6 / 2.6 bpm, 3500-4100 psi, 95R TF. 89 deg incl, 40 fph, Stacking wt, several stalls. Slow average ROP. Drilled to 11,494'. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 9/19/2004 1 0/3/2004 N1 Spud Date: 7/7/1980 End: 9/25/2004 15:30·16:10 0.67 DRILL P PROD1 Drilling lateral with Tractor. 2.6/2.6 bpm, 3500-4100 psi, 95R TF, 89 deg incl, 40 fph, Stacking wt, several stalls. Slow average ROP. Drilled to 11,499'. 16:10·16:45 0.58 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 16:45 - 18:20 1.58 DRILL P I PROD1 Drilling lateral with Tractor. 2.5/2.5 bpm, 3300·4100 psi, 120R TF, 88 deg incl, Steady drilling at 35 fph with less stalls. i Drilling with 2.5 bpm to get better ROP. Control drill. Drilled to 11,520'. 18:20 . 18:30 0.17 DRILL P PROD1 Orient TF to 100L. Up wt = 33k. Run·in wt = 13.5k. 18:30 - 19:30 1.00 DRILL P PROD1 Drill to 11559' with 100L TF, 2.6/2.6bpm 3450/3750psi, 2k WOB & 35fph ave ROP. Getting more consistent ROP with less stacking or stalling by control drilling with tractor & backing off on WOB as diff pressure comes to let tractor pull us in. 19:30 - 19:40 0.17 DRILL P PROD1 Orient TF to 60L. 19:40 - 20:45 1.08 DRILL P PROD1 Drill to 11585' with 70L TF, 2.6/2.6bpm 3550/3800psi, 5k WOB & 35fph ave ROP. Stall. P/U & drill to 11595' with 65L. Angle dropping @ 65L. 20:45 - 21:15 0.50 DRILL P PROD1 Orient 2 clicks & drill to 11605' with 10L TF, 2.6/2.6bpm 3600/3950psi, 1k WOB & 50fph ave ROP. 21:15·21:35 0.33 DRILL P PROD1 Orient 1 click & drill to 11623' with 1 OR TF, 2.6/2.6bpm 3600/3950psi, 3k WOB & 50fph ave ROP. 21 :35 - 22:30 0.92 DRILL P PROD1 Orient 2 clicks & drill to 11650' with 60-90R TF, 2.6/2.6bpm 3650/4000psi, 4k WOB & 55fph ave ROP. 22:30 - 23:25 0.92 DRILL P PROD1 Wiper trip clean to window. RBIH. 23:25 - 00:00 0.58 DRILL P PROD1 Orient & drill to 11670' with 90·105R TF, 2.6/2.6bpm 3600/3950psi, 3k WOB & 50fph ave ROP. 9/26/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drill to 11682' with 105R TF, 2.6/2.6bpm 3600/3950psi, 3k WOB & 60fph ave ROP. 00:30 - 00:50 0.33 DRILL P PROD1 Orient TF around to 45R. 00:50 - 02:00 1.17 DRILL P PROD1 Drill to 11702' with 40R TF, 2.6/2.6bpm 3600/3950psi, 3k WOB & 35fph ave ROP. Observe erratic TFs from 11685' to 11695'. Fault zone was prognosed @ 11700'. 02:00 - 03:15 1.25 DRILL P PROD1 Orient & drill to 11735' with 75R TF, 2.6/2.6bpm 3450/3750psi, 3k WOB & 35fph ave ROP. Observe lithology change @ 11720'. 03:15 - 04:15 1.00 DRILL P PROD1 Orient & drill to 11761' with 120-130R TF, 2.6/2.6bpm 3450/3750psi, 3k WOB & 35fph ave ROP. 04:15 - 04:30 0.25 DRILL P PROD1 Orient TF around to 90R. 04:30 . 05:30 1.00 DRILL P PROD1 Drill to 11802' with 90-95R TF, 2.6/2.6bpm 3600/3950psi, 3k WOB & 60fph ave ROP. 05:30 - 08:45 3.25 DRILL P PROD1 POOH tractor lateral BHA#9 to window @ 1.5bpm. Jog back in hole circ @ 2.2bpm & jog back up. SID pumps & pull into window. Paint EOP @ 10800' & continue POOH. 08:45 - 09:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA and surface test Welltec tractor. 09:00 - 10:45 1.75 DRILL P PROD1 Pick up Welltec tractor above rig floor to check drive rollers. Found leak in turbine lower shaft seal, out of 1/8" weep hole at top of Welltec trac, so unable to surface test arms. Determined that FloPro had contaminated hydrualic fluid in tractor. UO tracter. C/O bit and motor. Check orienter. BHA #10 OAL = 65.03'. 10:45 - 12:50 2.08 DRILL P PROD1 RIH with Lateral MWD BHA #10 with new DS49 3.75" bit and 1.37 deg motor. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 9/19/2004 10/3/2004 N1 Spud Date: 7/7/1980 End: 10:45 - 12:50 DRILL SHT tools and orienter, OK. RIH. 12:50 - 13:20 DRILL Log GR tie-in at RA tag. -13 ft CTD net correction. 13:20 - 13:50 0.50 DRILL RIH clean to TO. Tag TO at 11,810'. 13:50 - 14:20 0.50 DRILL Orient TF to 90R. 14:20 - 16:30 2.17 DRILL Drilling Z1 lateral, 2.6/2.6 bpm, 3550 - 4000 psi, 95R, 92 deg incl, 60 fph, Drilled to 11886'. 16:30 - 18:15 1.75 DRILL P PROD1 Drilling Z1 lateral, 2.6/2.6 bpm, 3550 - 4000 psi, 90R, 92 deg incl, 60 fph, Swapped to new FloPro at 11,910'. Drilled to 11,960 ft. 18:15 - 19:40 1.42 DRILL P PROD1 Wiper trip to window. Observe slight motor work 100' from window. Jog back in hole circ @ 2.6bpm to 11300' & jog back up. SID pumps & pull into window clean. Continue wiping hole to TT. RBIH & tag TOWS @ 40R TF. Orient to 4L & run clean thru window. 19:40 - 19:50 0.17 DRILL P PROD1 Log-up GR & tie-into RA PIP tag. Add 5.5' to CTD. 19:50 - 20:25 0.58 DRILL P . PROD1 RIH & set down in shale @ 11600'. P/U & run thru. Continue RBIH to btm tagged @ 11961'. 20:25 - 20:45 0.33 DRILL P PROD1 Drill to 11964' with 95R TF, 2.7/2.7bpm 3350/3750psi, 6k WOB. Stacking wt & not wanting to drill. 20:45 - 21 :00 0.25 DRILL P PROD1 Short 100' wiper. RBIH. Up wt = 39.5k & S/O wt = 13k 21:00 - 21:10 0.17 DRILL P PROD1 Drill to 11972' with 85R TF, 2.7/2.7bpm 3350/3750psi, 3k WOB & 100fph ave ROP. 21:10 - 21:25 0.25 DRILL P PROD1 Orient & drill to 11995' with 95R TF, 2.7/2.7bpm 3350/3750psi, 3k WOB & 100fph ave ROP. 21 :25 - 21 :55 0.50 DRILL P PROD1 Orient & drill to 12021' with 110-130R TF, 2.7/2.7bpm 3350/3750psi, 3k WOB & 70fph ave ROP. 21:55 - 22:10 0.25 DRILL P PROD1 Orient TF around to 90R. 22:10 - 22:55 0.75 DRILL P PROD1 Drill to 12072' with 85R TF, 2.7/2.7bpm 3350/3750psi, 3k WOB & 75fph ave ROP. 22:55 - 23:15 0.33 DRILL P PROD1 Orient & drill to 12100' with 100R TF, 2.7/2.7bpm 3350/3750psi, 1k WOB & 120fph ave ROP. 23:15 - 00:00 0.75 DRILL P PROD1 Wiper trip to IT. Observe wt bubbles across shales @ 11600'. I RBIH. 9/27/2004 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 Set down in shale @ 11585'. P/U & orient to as-drilled TF (+/-70L). Ream thru shale. Backream/ream shale interval until clean. 01 :00 - 01 :15 0.25 DRILL P PROD1 RIH & set down @ 11885'. P/U & run thru. Backream shale clean. RIH to btm. 01:15 - 01:30 0.25 DRILL P PROD1 Orient TF around to 80R. 01 :30 - 01 :45 0.25 DRILL P PROD1 Drill to 12112' with 95R TF, 2.7/2.7bpm 3350/3650psi, 2k WOB & 120fph ave ROP. TF rolling right. 01 :45 - 02:00 0.25 DRILL P PROD1 Orient TF around to 50R. 02:00 - 02:30 0.50 DRILL P PROD1 Drill to 12136' with 60R TF, 2.7/2.7bpm 3350/3650psi, 2k WOB & 60fph ave ROP. 02:30 - 02:45 0.25 DRILL P PROD1 Orient & drill to 12150' with 90R TF, 2.7/2.7bpm 3350/3650psi, 2k WOB & 75fph ave ROP. 02:45 - 03:20 0.58 DRILL P PROD1 Orient & drill to 12198' with 120-130R TF, 2.7/2.7bpm 3350/3650psi, 2k WOB & 120fph ave ROP. 03:20 - 03:35 0.25 DRILL P PROD1 Orient TF around to 50R. 03:35 - 04:20 0.75 DRILL P PROD1 Drill to 12260' with 60R TF, 2.7/2.7bpm 3350/3650psi, 2k WOB & 120fph ave ROP. 04:20 - 05:30 1.17 DRILL P PROD1 Wiper trip clean to window. RBIH. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/27/2004 05:30 - 06:00 0.50 DRILL N DPRB PROD1 Set down in shale @ 11560'. P/U & run thru shale. Backream & RIH thru clean. Continue RIH to btm. 06:00 - 07:30 1.50 DRILL P PROD1 Orient & drill to 12,350' with 11 OL TF, 2.7/2.7bpm 3350/3650psi, 3k WOB & 95fph ave ROP. 07:30 - 08:50 1.33/ DRILL P PROD1 Wiper trip to window. Back ream slow up thru shales, clean. 08:50 - 09:15 0.42 DRILL P PROD1 Log GR tie-in with RA tag. Added 10.5 ft. 09:15 - 10:30 1.25 DRILL P PROD1 RIH. Ream shales at 11600' and 11900'. RIH. 10:30-12:10 1.67 DRILL IP PROD1 Drilled Z1A lateral, 2.6/2.6 bpm, 3400 - 4000 psi, 80L, 89 deg Incl, 60 fph, high reactive torque from 12,420-12,444'. Difficult drilling like faulted zone. Drilled to 12,444'. 12:10 - 12:30 0.33 DRILL P PROD1 Orient TF to high side. 12:30 - 14:00 1.50 DRILL P PROD1 Drilled Z1A lateral, 2.6/2.6 bpm, 3450 - 4000 psi, 30L, 89 14:00 - 15:151 I: deg Incl, 40-60 fph, Drilled to 12,505'. 1.25 DRILL PROD1 Drilled Z1A lateral, 2.6/2.6 bpm, 3450 - 4000 psi, 30L, 91 deg Incl, 40-60 fph, Drilled to 12,530'. 15:15 - 17:00 1.75 DRILL PROD1 Wiper trip to window. Add 1% LubTex for a total of 4% to system. Some overpull, no motorwork across same shales at 11600' and 11900'. Clean to window. RIH clean to TO. 17:00 - 17:25 0.42 DRILL P PROD1 Orient TF 50L. 17:25 - 17:50 0.421 DRILL P PROD1 Drilled Z1A lateral, 2.6/2.6 bpm, 3450 - 4000 psi, 50L, 93 deg Incl, 80-100 fph, Drilled to 12,558'. 17:50 - 18:20 0.50 DRILL P PROD1 Orient TF to 90L. 18:20 - 18:30 0.17 DRILL P PROD1 Drilled Z1A lateral, 2.6/2.6 bpm, 3400 - 4000 psi, 90L, 93 deg incl. Drilled to 12,568'. TF rolling right. 18:30 - 18:40 0.17 DRILL P PROD1 Orient TF to 120L. P/U wt = 38k. S/O wt = 12k. Central dispatch confirms truck will be available by midnight for mud swap. 18:40 - 19:30 0.83 DRILL P PROD1 Drill to 12614' with 120-140L TF, 2.7/2.7bpm 3600/4000psi, 5k WOB & 100fph ave ROP. 19:30 - 19:40 0.17 DRILL P PROD1 P/U to orient. Pull heavy (69k) & pop free. Orient to 90L. 19:40 - 19:55 0.25 DRILL P PROD1 Drill to 12630' with 80L TF, 2.7/2.7bpm 3600/4000psi, 5k WOB & 75fph ave ROP. 19:55 - 20:30 0.58 DRILL P PROD1 Orient & drill to 12675' with 55L TF, 2.7/2.7bpm 3600/4000psi, 5k WOB & 120fph ave ROP. 20:30 - 22:15 1.75 DRILL P PROD1 Wiper trip to TT. Observe slight wt bubbles across shales. RBIH & set down @ 11600'. P/U & run thru. Backream shale clean. RBIH to btm. 22:15 - 22:45 0.50 DRILL P PROD1 Orient & drill to 12689' with 65R TF, 2.7/2.7bpm 3600/4000psi, 6k WOB & 35fph ave ROP. Pump down 20bbls lubetex pill. 22:45 - 23:10 0.42 DRILL N STUC PROD1 P/U to orient & get differentially stuck. Pull to 75k - still stuck. Circ lubetex pill into OH & SID pumps for 10mins. Pull free with 60k. 23: 1 0 - 23:20 0.17 DRILL P PROD1 Wipe hole up to 12500' - ratty but no motor work. Orient TF to 75R. 23:20 - 23:30 0.17 DRILL P PROD1 Drill to 12711' with 80R TF, 2.7/2.7bpm 3700/4100psi, 4k WOB & 110fph aye ROP. 23:30 - 00:00 0.50 DRILL P PROD1 Orient & drill to 12750' with 80R TF, 2.7/2.7bpm 3800/4100psi, 7k WOB & 110fph ave ROP. Stacking wt. 9/28/2004 00:00 - 00:10 0.17 DRILL P PROD1 Orient TF around to 90R. 00:10 - 00:35 0.42 DRILL P PROD1 Drill to 12787' with 80R TF, 2.7/2.7bpm 3800/4100psi, 7k WOB & 140fph aye ROP. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-1 6 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/28/2004 00:35 - 01 :40 1.08 DRILL P PROD1 Orient & drill to 12836' with 100-140R TF, 2.7/2.7bpm 3800/4100psi, 7k WOB & 65fph ave ROP. 01 :40 - 02:40 1.00 DRILL P PROD1 Wiper trip to window. Shales are fairly clean. Jog back in hole & jog back up to window. 02:40 - 03:151 0.58 DRILL P PROD1 Log-up GR & tie-into RA PIP tag. Add 21' to CTD. 03:15 - 03:35 0.33 DRILL P PROD1 RBIH. 03:35 - 04:00 0.42 DRILL N DPRB PROD1 Set down in shale @ 11650'. P/U. Orient to as-drilled TF & work past shales. Backream/ream shale interval1x. 04:00 - 04:45 0.75 DRILL P PROD1 RBIH to btm tagged @ 12847'. Start pumping down fresh I 8.6ppg flopro mud with 4% L-T & 12ppb K-G. 04:45 - 05:00 0.25 DRILL P PROD1 Orient TF around to 75R. Up wt = 38k. Run-in wt = 14k. 05:00 - 06:30 1.50 DRILL P PROD1 Drill to 12900' with 90-100R TF, 2.7/2.7bpm 3800/4200psi, 4-6k WOB & 50fph ave ROP. 06:30 - 07:20 0.83 DRILL P I PROD1 Drilled 21 lateral, 2.4/2.4 bpm, 3400 - 4100 psi, full returns, jp 93 deg incl, Drilled to 12,912 ft. 107:20 - 10:30 3.17 DRILL PROD1 Wiper trip to window. Ream fault zone at 12420', Wiper up to window. Set down / ream shales at 11,600 ft. Ream up/down twice. RIH to TO. 10:30 - 12:15 1.75 DRILL P PROD1 Drilled 21 lateral, 2.5/2.5 bpm, 3400 - 4100 psi, 93 deg incl, 70R TF, Drilling shales, stacking wt, coil stacks wt, slides, then motor stalls. Drilled to 12,950'. 112:15 - 13:15 1.00 DRILL P PROD1 Drilling 21 sand, sand started at 12,950 ft. 2.6/2.6 bpm, 3500 - 4100 psi, 95 deg incl, drilling with 120R TF to drop incl, Drilled to 13,023 ft. 13:15 - 13:45 0.50 DRILL P PROD1 200 ft wiper trip to ream shales just drilled. Overpull iin shales from 12930-12880'. Ream up to 12800'. Ream down. 13:45 - 14:00 0.25 DRILL P PROD1 Drilled 21 sand to 13,033'. 120R TF, 100 fph. Need to orient to left side. 14:00 - 15:45 1.75 DRILL P PROD1 Wiper trip to window. Shales were good, slight overpull at each shale. RBIH clean to btm. 15:45 - 15:55 0.17 DRILL P PROD1 Orient TF around to 100L. Up wt '" 38k. S/O wt = 11.5k. 15:55 - 16:10 0.25 DRILL P PROD1 Drill to 13068' with 80L TF, 2.7/2.7bpm 3500/4000psi, 3k WOB & 110fph aye ROP. 16:10-16:30 0.33 DRILL P PROD1 Short 100' wiper. RBIH & grab 1 click. 16:30 - 17:00 0.50 DRILL P PROD1 Drill to 13111' with 55L TF, 2.6/2.6bpm 3400/3900psi, 4k WOB & 110fph aye ROP. 17:00 - 17:20 0.33 DRILL P PROD1 Orient TF around to 100L. 17:20 - 17:45 0.42 DRILL P PROD1 Drill to 13155' with 110L TF, 2.6/2.6bpm 3400/3900psi, 4k WOB & 100fph ave ROP. 17:45 - 17:55 0.17 DRILL P PROD1 Short 100' wiper. RBIH. 17:55 -18:15 0.33 DRILL P PROD1 Drill to 13174' with 120-150L TF, 2.6/2.6bpm 3400/3900psi, 4k WOB & 100fph aye ROP. 18:15-18:30 0.25 DRILL P PROD1 Orient TF HS. Drill ahead to 13186' MD. 18:30 - 19:30 1.00 DRILL P PROD1 Wiper trip to the window. - Motor work and 5k overpull at 11,255' MD. 19:30 - 19:45 0.25 DRILL P PROD1 Tie in to RA marker. - Correction + 12 feet. 19:45 - 21 :00 1.25 DRILL P PROD1 Wiper trip back to 13,186' MD. - Stack up at 11,650' shale. Orient to 40ROHS. No problem. 121:00 - 21:15 0.25 DRILL P PROD1 Orient TF to 100 L. 21 :15 - 22:15 1.00 DRILL P PROD1 Directionally drill in Zone 1A to 13,242' MD. - 2.6/2.7 bpm. - 4000 psi (3600 psi free spin). Printed: 10/4/2004 7:32,41 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 717/1980 End: - 100 fph ROP. · 35k PU, 10k SO weight · Sticky when picking up off bottom. 22:15 - 22:30 0.25 DRILL P PROD1 Orient TF to 90 L. 22:30 . 00:00 1.50 DRILL P PROD1 Directionally drill in Zone 1A to 13,335' MD. ·2.6/2.7 bpm. - 4000 psi (3600 psi free spin). - 100 fph ROP. - 35k PU, 10k SO weight - Sticky when picking up off bottom (5k - 10k). 9/29/2004 00:00 - 00:30 0.50 DRILL P PROD1 Directionally drill in Zone 1A to 13,350' MD. ·2.6/2.7 bpm. ·4000 psi (3600 psi free spin). - 100 fph ROP. I - 35k PU, 10k SO weight - Sticky when picking up off bottom (5k . 1 Ok). 00:30 - 02:30 2.00 DRILL P I PROD1 Wiper trip to window. - Minimal bobbles near 11,650' MD. 02:30 . 02:45 0.25 DRILL P PROD1 Orient TF to 100L. 02:45 - 04:30 1.75 DRILL P PROD1 Directionally drill in Zone 1A to 13,422' MD. - 2.63/2.75 bpm. - 4150 psi (3600 psi free spin). - 100 fph ROP. - 35k PU, 10k SO weight 104:30 . 07:30 · Repeated stalling, difficult to get a bite. · Decision to pull for WellTeck Tractor. 3.00 DRILL P PROD1 POOH with BHA at 35 fpm, 2.5 bpm. - Open hole in good condition. No overpull or motor work. 07:30·08:15 0.75 DRILL P PROD1 OOH. PJSM. SIB injector. P/test CTC - OK. UD drilling BHA #10. Bit grades - 1/3/1 with some broken gauge cutters. Check motor - very weak (had 68hrs run time) - will be changed out Check orienter - OK will rerun. 08:15 - 08:30 0.25 BOPSUF P PROD1 Conduct weekly BOP function test - OK. 08:30 . 09:30 1.00 DRILL P PROD1 M/U lateral BHA #11 with a used HYC DS49 bit, spare 1.37deg I BHI motor with 40hrs run time, Sperry GR·DIR MWD with new probe insert. Scribe tools & M/U WellTec tractor. M/U injector & raise above floor. 09:30· 10:00 0.50 DRILL P PROD1 Surface test Welltec tractor 3x with upper 4 sets of wheels exposed & 1 set of lower wheels inside the lubricator. Record wheels opening @ 2.2bpm, fully extended @ 2.6bpm, fully closed @ 1.5 bpm & still closed @ 2.0bpm. 10:00·10:15 0.25 DRILL P PROD1 SIB injector. M/U orienter & MHA. M/U injector. Meanwhile GBR welder inadvertently cut thru Nordic pump #1 fluid end while attempting to cut & remove the valves for replacement. Fetch for spare fluid end & mobilize Schlumberger spare pump truck. 10:15·12:15 2.00 DRILL P PROD1 RIH with lateral BHA#11. SHT - OK. Continue RIH. SID pump. Tag window @ 10954' with 47L TF. Meanwhile R/U hardline to spare SLB pump & work on replacing pump#1 fluid end. 12:15· 13:30 1.25 DRILL N DPRB PROD1 Attempt to go thru window @ 30L, HS, 27R & 47R TFs - stacking out @ 10969' (suspect some debris @ the btm of the window). Decide to tie-into the PDC log to confirm window depth. PUH to 10880' for tie-in log. Printed: 10/4/2004 7:32:41 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/29/2004 13:30 - 14:15 0.75 DRILL P PROD1 Log down GR & tie-into PDC log. Subtract 2' from CTD. 14:15 - 14:30 I 0.25 DRILL N DPRB PROD1 Attempt to go thru window @ 25R - set down @ 10955'. Orient to 10L. RBIH & stack out @ 10969'. Slowly bring on pumps to 0.75bpm & wash down to 10974'. SID pump & finally managed to work BHA thru the window. 14:30 - 15:45 1.25 DRILL N PROD1 Continue RIH. Set down several times across shale intervals. Finally tag @ 13412'. 15:45 - 16:00 0.25 DRILL N PROD1 Orient TF to 60L. Up wt = 37k. Run-in wt = 10k. 16:00 - 16:30 0.50 DRILL N PROD1 Attempt to drill from 13412 - not able to get motorwork. Looks like BHA is hanging up. Wipe up hole to 13300'. RBIH & set down @ 13412'. Reduce pump rate. Creep in hole with I 1.5bpm & finally find btm @ 13422'. 16:30 -17:00 0.50 DRILL P PROD1 Drill to 13437' with 20L TF, 2.5/2.5bpm 3800/41 OOpsi, 7k WOB, 3k CT wt & 30fph ave ROP. Start pumping down fresh 8.6ppg flopro mud with 4% L-T & 12ppb K-G. 17:00 - 17:15 0.25 DRILL P PROD1 Wipe up hole to 13300' with new mud out of the bit. 17:15 - 18:30 1.25 DRILL P PROD1 Drill to 13455' with 45L TF, 2.5/2.5bpm 365013750psi, 7k WOB, 3k CT wt & 20fph ave ROP. Wt stacking & not getting enough 1.251 DRILL motorwork. 18:30 - 19:45 P PROD1 Drill to 13,477' MD - TF at 45L. - 2.55/2.78 bpm - 4000 psi (3600 psi free spin). - 40k PU; 10k SO - 7k - 15k WOB - Difficult to get drilling. Making some hole with the higher WOB. 19:45 - 20:00 0.25 DRILL C PROD1 Orient TF to 90L. 20:00 - 21 :45 1.75 DRILL C PROD1 Drill to 13,515' MD - TF at 90L. - 2.55/2.7 bpm (flushed out micromotion) - 4000 psi (3600 psi free spin). - 40k PU; 10k SO - 10k - 15k WOB - No evidence of the tractor in the drilling parameters. 21:45 - 23:00 1.25 DRILL C PROD1 Drill to 13,580' MD. . ROP at 100 fph when on bottom. Has been drilling-off after 5 - 10 minutes of drilling ahead with pressure decreasing to 3600 psi. - Attempted to stall BHA, no go. - Vary 'in rate' parameters from 2.5 to 2.8 bpm. Saw no conclusive indications of tractor work. Continue to drill-off. - Formation change from shale to sand has enabled us to drill ahead at 60 - 135 fph ROP, 2.8 bpm, 4300 psi, with WOB varying between 7k and 15k with no drill-off or stalling. Since formation change, we have been drilling with positive weight without drilling-off. - Decreased rate from 2.8 bpm to 1.5 bpm (to close arms on tractor). Brought rate back up to 2.5 bpm. Drilling continued at 3900 psi, 9k WOB with no drill off. o Currently drilling ahead at 2.8 bpm, 4200 psi, 1 0-15k WOB at 130 fph at 60 L TF. 23:00 - 0.00 DRILL C I PROD1 Wiper trip to window. Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 9/29/2004 23:00 - 0.00 DRILL C PROD1 9/30/2004 00:00 . 02:00 2.00 DRILL C IPROD1 02:00 - 03:00 1.00 DRILL C 03:00 - 03:15 0.25 DRILL C 03:15·06:15 3.00 DRILL C PROD1 PROD1 PROD1 06:15 - 08:15 2.00 DRILL P PROD1 08:15 - 08:40 0.42 DRILL P PROD1 08:40 - 10:50 2.17 DRILL P PROD1 10:50 - 13:15 2.42 DRILL P PROD1 13:15 - 13:40 0.42 DRILL P PROD1 · Pumping at 1.5 bpm, 20 fpm. - Slight motor work at 13,460', 12,650' MD. Continue wiper trip to window at 1.5 bpm, 20 fpm. - Slight motor work at 11,600' MD - "Jog" at window - Bring pump #1 online. Rig down and release SLB pump truck. RBIH at 2.2 bpm, 40 fpm to depth at 13,580' MD. · Orient through shales at 11,600' MD. - Motor work at 12,950' MD Orient TF to 75R. Drill to - TF at 75R. - 2.72/2.82 bpm - 4100 psi (3600 psi free spin). - 40k PU; 10k SO - 5k - 15k WOB - 30 - 100 fph ROP. - Multiple occurrences of 500 - 800 psi increases which ultimately drilled off. This section has not required picking up off bottom to get the BHA to drill. · Stalled at 13,660' MD. Gee call TD @ 13689. Wiper trip to window @ 1.5bpm & 20fpm. Log up GR & tie into RA PIP tag. Add 4' to CTD. RBIH relatively clean. Had minor WI bubble @ 11640'. Set down @ 13550', 13650'. P/U & continue RIH to TO tagged 2x @ 13685'. POOH lateral BHA laying-in fresh flopra mud in OH. Paint EOP flags @ 10800' & 8000'. Function tested the tractor @ 8000' while RIH @ +/-30fph with the following results: ¡Time Rate-In CTP ROP 13:15 1.50bpm 1,926 psi 8,065.8ft 12,122Lbs OLbs 33fph 13:19 1.50 bpm 1,926 psi 8,068.5 ft 11,700 Lbs 0 Lbs 33 fph 13:20 2.00bpm 2,540 psi 8,068.5ft 11,700Lbs OLbs 34fph 13:24 2.00 bpm 2,540 psi 8,071.5 ft 11,907 Lbs 0 Lbs 34 fph 13:25 2.20 bpm 2,871 psi 8,071.5 ft 11,939 Lbs 0 Lbs 31 fph 13:29 2.20 bpm 2,871 psi 8,073.6 ft 11,848 Lbs 0 Lbs 31 fph 13:30 2.55 bpm 2,871 psi 8,073.6 ft 11,927 Lbs 0 Lbs 30 fph 13:34 2.55bpm 2,871 psi 8,076.3ft 11,731 Lbs OLbs 31 fph 13:35 2.80 bpm 3,757 psi 8,076.3 ft 11,946 Lbs ° Lbs 30 fph 13:39 2.80bpm 3,757 psi 8,078.6ft 11,692Lbs OLbs 31 fph Depth CTWt WOB Printed: 10/4/2004 7:32:41 AM Drop 13/16" ball & cìrc to circ sub. Open cìrc sub with 2400psi. Continue POOH circ @ 2.7bpm to surface. Chase solids to surface, jog back in hole @ 100fpm & chase back up to surface. 15:30 . 16:00 0.50 I DRILL P I PROD1 100H. PJSM. SIB injector. Flush BHA & UO MHA, upper flex & orienter. 16:00 - 16:30 I 0.50 I DRILL P I PROD1 I M/U injector & raise W ellT ec tractor above rig floor to function test wheels. As in the 1st tractor run, observe leak in turbine lower shaft seal, out of 1/8" weep hole at top of tractor. Hydrualic fluid in tractor has been contaminated by flopro mud. Pump up to 2.2bpm & could not open tractor wheels. SID test. 16:30 - 17:30 1.00 DRILL P \ PRODt ¡UDWeIlTec, MWD, motor & bit. 17:30 . 19:30 2.00 I DRILL P PROD1 MU Baker CTC. - Pull test to 3500 Ibs. - Pressure test to 3500 psi. - RU dart catcher. - Launch Dart. - Dart latched at 54.5 bbls. 19:30·20:00 0.50 CASE P I RUNPRD Clear rig floor. Bring tools to rig floor. I Fill hole (4 bbls to fill). 20:00 - 20:30 0.50 CASE P \ RUNPRD PJSM for running liner. 20:30 - 00:00 3.50 CASE P RUNPRD Pick up liner. - FE, 59 jts 2-7/8", LSL, 29 jts 3-3/16",1 jt 3-1/2", X nipple, Deployment sleeve. 10/1/2004 100:00 - 00:45 0.75 CASE P \ RUNPRD Continue picking up liner. I - FE, 59 jts 2-7/8", LSL, 29 jts 3-3/16", 1 jt 3-1/2", X nipple, Deployment sleeve. MU CTLRT. MU Injector. 00:45 - 02:00 1.25 CASE P I RUNPRD I RIH with liner at 100 fpm pumping 0.25 bpm. · At window: 43k PU; 16k SO - No problems through window 02:00 - 03:45 1.75 CASE P I RUNPRD I RIH with liner into openhole at 75 fpm pumping 0.25 bpm. - Bobble at 12,150'. - Stack up at 12,400' MD. PU (46k) twice, fell through. - Stack up at 12,950' MD. PU (49k) once, fell through. - Stack up at 13,100' MD. PU (51k) once, fell through. · Stack up at 13,290' MD. PU (53k) once, fell through. - Stacking up from 13,441' MD. PU (47k - 66k) various times, changing running speeds and pump rate. - Ultimately made it to 13,631' MD with 10k Ibs stacked. · Depth counter puts bottom of liner at 13,628' MD; TOL at 10,791' MD, 25' below the packer at 10,766' MD. This is confirmed by the flag location (13,647') which is approximately 20' behind the horse head on the reel; this places the bottom of liner approximately 13,627' and the TOL at 10,791'MD. 03:45 - 04:35 0.83 CASE P I RUNPRD Load and pump 5/8" steel ball. - 2.3 I 2.4 bpm to 40 bbls away. - Reduce rate to 0.5 bpm. - Ball on seat at 47.1 bbls. 04:35 - 04:45 0.17 CASE P I RUNPRD Release from liner. - Pressure up to release. Printed: 10/4/2004 7:32:41 AM Spud Date: 7/7/1980 End: Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 02-16 02-16 REENTER+COMPLET NORDIC CALISTA NORDIC 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 9/19/2004 10/3/2004 N1 Spud Date: 7/7/1980 End: - Release at 4000 psi. - PU 30k to confirm release. - SO 16k to confirm set. - Tag shows top at 10,791' MD and shoe at 13,628' MD. 04:45 - 09:15 4.50 CASE P RUNPRD Displace well to 2% double slick KCI at 2.82/2.97 bpm, 2850 I psi. Meanwhile R/U Dowell cementers. 09:15 - 09:30 0.25 CEMT P RUN PRO PJSM with all personnel concerning cementing operations. Meanwhile continue circulating 2% KCI @ 2.52/2.35bpm & IRUNPRD 1500psi. 09:30 - 11 :00 1.50 CEMT P Batch mix 30bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt @ 09:45hrs. Flush/PT lines to 4k. Pump 29.8bbls cmt slurry @ 2.40/2.20bprn & 2150psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 25bbls IbiO-KCL @ 2.5/2.3bpm & 1900psi. CTWP engage LWP @ 55.9bbls away. Shear plug with 3900psi. Continue displacing LWP @ 2.65/2.55bpm, 3180psi & bump @ 72.9bbls away with I 1000psi over. Bleed off & check floats - held. Pressure up to 250psi & sting out of liner. 27.3bbls cmt pumped around shoe. CIP @ 10:55hrs. 11:00 -12:30 1.50 CEMT P RUNPRD POOH @ 100fpm pumping @ 0.55bpm to replace CT voidage only. 12:30 . 13:20 0.83 CEMT P RUNPRD OOH. PJSM. UD CTLRT. 13:20 - 14:00 0.67 EVAL P LOWER1 Initialize & test logging tools. P/U tools to rig floor. 114:00 - 14:15 0.25 EV AL P LOWER1 PJSM on P/U & RIH MCNL tools & 1-1/4" CHS tbg. 14:15 -16:15 2.00 EVAL P LOWER1 P/U 10gging/cIeanout BHA #13 with 2-1/4" 0331 mill, 2-1/8" straight motor, XO, 2jts of 1-1/4" CSH tbg, MCNUCCUGR logging tool carrier, XO, lower MHA, 90jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. 16:15-17:40 1.42 EVAL P LOWER1 RIH with logging/cleanout BHA #13. 17:40 - 20:30 2.83 EVAL P LOWER1 Wait on cement to get to 500psi compressive strength. 20:30 - 22:30 2.00 EVAL P LOWER1 Log down at 30 fpm from 10,300' MD. . Tag PBTD at 13,595' MD. 22:30 - 23:30 1.00 EVAL P LOWER1 Log up at 60 fpm from PBTD. - Lay in 35 bbls of perf pill at 0.64 bpm. 23:30 - 00:00 0.50 EV AL P LOWER1 POOH with 10gging/cIeanout asembly. - 1.3/ 1.0 bpm - 1400 psi 10/2/2004 00:00 - 01 :30 1.50 EVAL P LOWER1 Continue to POOH with logging/cleanout asembly. . 1.3 /1.0 bpm - 1400 psi - 70 fpm. Stand back injector. 01 :30 - 03:30 2.00 EVAL P LOWER1 Rack back 45 stands of CS Hydril. 03:30 - 04:45 1.25 EVAL P LOWER1 PJSM. POOH with logging BHAlsource. LD same. Clear rig floor of tools. Fill hole. 04:45 . 05:30 0.75 CASE P RUNPRD Pressure test liner lap to 2000 psi for 30 minutes. Time Press. Delta 0 2025 5 1985 -40 10 1952 -33 Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 7/7/1980 End: 10/2/2004 10/3/2004 04:45 - 05:30 05:30 - 07:15 07:15 - 07:30 07:30 - 10:15 10:15 - 11:15 11:15 -13:55 113:55 - 14:35 14:35 - 15:30 15:30 - 16:00 16:00 - 17:15 17:15 - 17:45 17:45 - 19:45 19:45 - 20:00 20:00 - 00:00 00:00 - 00:45 00:45 - 01 :00 01 :00 . 02:30 02:30 - 04:30 I 04:30 - 04:45 04:45 - 05:00 0.75 CASE P 1.75 EVAL P 0.25 EV AL P 2.75 PERFOB P 1.00 PERFOB P 2.67 PERFOB P 0.67 PERFOB P 0.92 PERFO, P 0.50 PERFOB P 1.251 PERFOB P 0.50 PERFOB P 2.00 PERFOB P 0.25 PERFOB P 4.00 PERFOB P 0.75 PERFOB P 0.25 PERFOB P 1.50 PERFOB P 2.00 PERFOB P 0.25 PERFOB P 0.25 PERFOB P RUNPRD 15 20 25 30 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 LOWER1 1915 -37 1893 -22 1871 -22 1857 -14 Total Delta: 190 psi I Flush the stack. Continue loading the shed with guns. Meanwhile download MCNL data. Fax CNL log to ANG Geo. From log data, TOL was located @ 10784' & PBTD was @ 13598.71'. PJSM on P/U & RIH perf guns & 1-1/4" CHS tbg. M/U 65jts of 2" HSD 6spf 2006PJ guns & blank with CBF firing system. M/U lower MHA, XO, 49jts of 1-1/4" CSH tbg, XO & upper MHA. BHA OAL - 2913.92'. M/U injector. RIH with perforating BHA circ perf pill @ 0.3 bpm. Tag PBTD 2x @ 13598'. Pull to P/U wt & correct CTD to 13598.7' (PBTD as per MCNL log). PUH to ball drop postion @ 13310'. Hook-up PSSD (portable seismic shot detection) sensor to WHO. Pump a total of 20bbls perf pill ahead. Load 5/8" AL ball. Blow ball into CT with 10bbls perf pill behind. Position guns for btm shot @ 13300'. Chase ball @ 2.34bpm/2380psi. Slow to 1.0bpm/1060psi @ 40bbls. Ball on seat after 56.3bbls away. RBIH to 13305'. PUH very slowly & ramp up to 3500psi with btm shot @ 13300'. Observe guns fire with good pressure drop indication & vibration on PSSD. Perforated interval = 11920' . 112320', 12560' - 12735', 12950' - 13200' & 13270' - 13300'. PVT = 176bbls. POOH with perf gun BHA @ 40fpm pumping down the CT @ 0.35bpm/200psi. POOH to 11914' (above Top perf). Paint EOP flag @ 9000'. Continue POOH to 10600' (above TOL). PVT = 161bbls - 1bbllosses while POOH to 10600'. SID pump & flowcheck well for 30 mins - well stable. Continue POOH with perf gun BHA @ 100fpm pumping down the CT @ 1 bpm & 570psi. PVT = 120bbls - total of 1 bbl losses. OOH. Held PJSM for RIB 1-1/4" CSH. Meanwhile SID pump & flowcheck well - stable. SIB injector. UD upper MHA, XO, 49jts of 1-1/4" CSH tbg, XO & lower MHA. PJSM on handling 2" spent Perf Guns LD Perf Guns Finished LD guns, clean floor,make ready to PU Run #2 PJSM on PU Perf Guns Run #2 Measured, checked perf and disconnect balls, OK. PU Perf Gun Run #2 Run 10 std CSH, PU MHA and Injector head RIH w/ Perf Guns No corrected at Flag Tagged @ 10,784 ft /11,642 ft Pumped 16 bbl perf pill. PUH to lanch ball Lanched 5/8" ball and followed with 8 bbl perf pill. PUH to bottom perf depth Cir 5/8" ball down CT. Fly bye perforated using 48 bbl's and Printed: 10/4/2004 7:32:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-16 02-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/19/2004 Rig Release: 10/3/2004 Rig Number: N1 Spud Date: 717/1980 End: 10/3/2004 04:45 - 05:00 0.25 PERFOB P LOWER1 3200 psi. Perf 11,310 ft to 11,350 ft 2" Guns 6 spf Perf 11,370 ft to 11,535 ft 2" Guns 6 spf Vol pits = 188 bbl 05:00 - 06:45 1.75 PERFO LOWER1 POOH keeping hole full 06:45 - 07: 15 0.50 PERFO LOWER1 OOH. Held PJSM for RIB 1-1/4" CSH. Meanwhile SID pump & flowcheck well - stable. 07:15 - 08:15 1.00 PERFO LOWER1 SIB injector. UD MHAs & R/B 20stds of 1-1/4" CSH tbg. 08:15 - 08:30 0.25 PERF LOWER1 RlU to UD perf guns. 08:30 - 08:45 0.25 PERF LOWER1 PJSM for UD perf guns. 08:45 - 09:30 0.75 PERF LOWER1 UD 11jts of perf guns & partials. Conduct valve drill while UD guns. ASF! 09:30 - 10:25 0.92 RIGD P POST M/U & RIH with nozzle BHA to 2500'. Start pumping MeOH. 10:25 - 10:50 0.42 RIGD P POST Lay in MeOH @ 60/40 from 2500' to 300'. Circulate 100% MeOH to surface. SI Swab (29 turns). 10:50 - 11:00 0.17 RIGD P POST PJSM for B/D CT with N2. 11 :00 - 11 :45 0.75 RIGD P POST PlTest N2 lines - OK. B/D CT & lines with N2 & bleed off. Jet stack while blowing down. SIB injector & LID nozzle BHA. Meanwhile clean out pits & tanks. 11 :45 - 12:00 0.25 RIGD P POST PJSM for N/D BOP. 12:00 - 13:30 1.50 RIGD P POST N/D BOP. N/U & P/test tree cap. Release rig @ 13:30Hrs on 10/3/04. Printed: 10/4/2004 7:32:41 AM . . 15-0ct-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2-168 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,947.47' MD 10,949.00' MD 13,685.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date q ~('u ~vL Signed ~~~ DiM Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ¡;t tl ~ - ( Ç') Survey Ref: svy4407 SpE!í'í'V-SUI'1 DRILLING seAV,c:es A Halliburton Company Surface Coordinates relative to Project H Reference: 950867.74 N, 187542.26 E (Grid) Surface Coordinates relative to Structure Reference: 2069.77 N, 46.42 W (True) Kelly Bushing Elevation: 58. 76ft above Mean Sea Level Kelly Bushing Elevation: 58. 76ft above Project V Reference Kelly Bushing Elevation: 58.76ft above Structure Reference e Your Ref: API 500292044802 Surface Coordinates: 5950867.74 N, 687542.26 E (700 16' 14.1985" N, 148028' 59.3591" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 7 October, 2004 Survey Report Job No. AKMW3297732, Surveyed: 30 September, 2004 e North Slope Alaska BPXA PBU_EOA DS 02 02-16 - 2-16B Halliburton Sperry-Sun Halliburton Sperry-Sun Survey Report for P8U_EOA OS 02 - 02-16·2-168 Your Ref: API 500292044802 Job No. AKMW3297732, Surveyed: 30 September, 2004 8PXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10947.47 50.850 306.160 8728.95 8787.71 3591.40 N 4662.66 W 5954341.84 N 682791.56 E 5748.27 Tie On Point 10949.00 51.000 306.180 8729.91 8788.67 3592.10 N 4663.62 W 5954342.51 N 682790.59 E 9.856 5749.42 Window Point 10981.04 55.330 300.150 8749.13 8807.89 3606.08 N 4685.08 W 5954355.96 N 682768.78 E 20.228 5773.93 11011.15 58.850 295.250 8765.49 8824.25 3617.80 N 4707.46 W 5954367.12 N 682746.12 E 17.977 5797.29 11050.66 65.810 289.410 8783.84 8842.60 3631.03 N 4739.81 W 5954379.53 N 682713.45 E 21.938 5828.22 e 11085.47 68.800 284.690 8797.27 8856.03 3640.43 N 4770.50 W 5954388.16 N 682682.53 E 15.172 5855.15 11115.85 70.750 282.420 8807.78 8866.54 3647.10 N 4798.21 W 5954394.15 N 682654.66 E 9.505 5878.07 11149.42 70.840 278.720 8818.82 8877.58 3652.92 N 4829.37 W 5954399.19 N 682623.37 E 10.412 5902.55 11179.57 70.310 273.440 8828.86 8887.62 3655.93 N 4857.63 W 5954401.49 N 682595.04 E 16.608 5923.03 11212.23 73.130 265.680 8839.11 8897.87 3655.67 N 4888.61 W 5954400.47 N 682564.08 E 24.152 5942.74 11245.98 77.890 260.220 8847.56 8906.32 3651.65 N 4921.01 W 5954395.63 N 682531.79 E 21.073 5960.49 11274.31 81.760 255.110 8852.57 8911.33 3645.69 N 4948.24 W 5954389.00 N 682504.72 E 22.398 5973.42 11302.85 84.230 252.470 8856.05 8914.81 3637.78 N 4975.43 W 5954380.41 N 682477.73 E 12.617 5984.85 11330.71 86.700 248.420 8858.25 8917.01 3628.49 N 5001.59 W 5954370.47 N 682451.80 E 16.987 5994.54 11366.29 89.870 255.110 8859.32 8918.08 3617.37 N 5035.35 W 5954358.51 N 682418.34 E 20.797 6007.72 11395.50 90.220 261.100 8859.30 8918.06 3611.35 N 5063.92 W 5954351.79 N 682389.93 E 20.542 6021.48 11422.64 89.120 264.390 8859.45 8918.21 3607.92 N 5090.84 W 5954347.69 N 682363.10 E 12.782 6036.16 11453.05 89.560 270.020 8859.80 8918.56 3606.44 N 5121.20W 5954345.45 N 682332.79 E 18.569 6054.53 11485.18 88.510 275.640 8860.34 8919.10 3608.03 N 5153.27 W 5954346.24 N 682300.69 E 17.791 6076.37 11516.63 85.960 280.210 8861.86 8920.62 3612.35 N 5184.37 W 5954349.79 N 682269.49 E 16.624 6099.67 11549.43 84.200 280.040 8864.68 8923.44 3618.10 N 5216.54 W 5954354.73 N 682237.18 E 5.391 6124.75 e 11574.96 84.020 276.170 8867.30 8926.06 3621.68 N 5241.68 W 5954357.68 N 682211.97 E 15.095 6143.65 11607.30 87.100 272.300 8869.80 8928.56 3624.06 N 5273.82 W 5954359.26 N 682179.77 E 15.265 6166.14 11637.90 90.440 273.710 8870.46 8929.22 3625.66 N 5304.37 W 5954360.10 N 682149.19 E 11.847 6181.00 11670.27 90.440 279.160 8870.21 8928.97 3629.29 N 5336.52 W 5954362.92 N 682116.96 E 16.836 6210.44 11705.64 92.990 283.200 8869.15 8927.91 3636.14 N 5371.19 W 5954368.91 N 682082.13 E 13.502 6237.98 11737.98 93.250 287.600 8867.39 8926.15 3644.71 N 5402.32 W 5954376.71 N 682050.80 E 13.609 6264.56 11763.81 92.110 291.290 8866.18 8924.94 3653.30 N 5426.64 W 5954384.68 N 682026.27 E 14.937 6286.77 11794.30 94.310 296.030 8864.47 8923.23 3665.51 N 5454.52 W 5954396.20 N 681998.10 E 17.116 6314.04 11823.40 92.460 299.900 8862.75 8921.51 3679.13 N 5480.17 W 5954409.17 N 681972.12 E 14.719 6340.96 11854.06 91.760 305.000 8861.62 8920.38 3695.57 N 5506.02 W 5954424.96 N 681945.87 E 16.779 6370.17 11885.37 92.640 309.390 8860.42 8919.18 3714.47 N 5530.93 W 5954443.24 N 681920.49 E 14.290 6400.67 11921.59 93.510 318.010 8858.47 8917.23 3739.44 N 5557.06 W 5954467.55 N 681893.75 E 23.886 6436.58 11954.23 92.370 322.930 8856.80 8915.56 3764.57 N 5577.80 W 5954492.16 N 681872.39 E 15.453 6469.17 11986.12 92.370 327.500 8855.48 8914.24 3790.73 N 5595.97 W 5954517.86 N 681853.57 E 14.318 6500.89 7 October, 2004 -13:53 Page 2 of 5 Oril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for P8U_EOA OS 02 - 02-16 - 2-168 Your Ref: API 500292044802 Job No. AKMW3297732, Surveyed: 30 September, 2004 8PXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 12017.20 90.790 331.020 8854.62 8913.38 3817.43 N 5611.85 W 5954544.15 N 681837.03 E 12.410 6531.55 12050.15 92.200 336.990 8853.76 8912.52 3847.02 N 5626.28 W 5954573.37 N 681821.87 E 18.610 6563.49 12074.38 92.460 341.910 8852.78 8911.54 3869.69 N 5634.77 W 5954595.82 N 681812.81 E 20.317 6586.31 12108.51 92.370 344.370 8851.34 8910.10 3902.32 N 5644.66 W 5954628.19 N 681802.11 E 7.206 6617.67 12134.83 93.510 348.950 8849.99 8908.75 3927.89 N 5650.73 W 5954653.60 N 681795.41 E 17.910 6641 .15 e 12168.28 92.110 355.450 8848.35 8907.11 3960.97 N 5655.26 W 5954686.56 N 681790.06 E 19.854 6669.41 12195.43 89.300 358.790 8848.01 8906.77 3988.08 N 5656.62 W 5954713.63 N 681788.02 E 16.075 6691.05 12234.41 90.970 6.170 8847.92 8906.68 4026.99 N 5654.93 W 5954752.57 N 681788.74 E 19.411 6719.78 12261.01 90.440 10.210 8847.59 8906.35 4053.31 N 5651.15 W 5954778.98 N 681791.87 E 15.317 6737.50 12293.49 87.540 1.950 8848.17 8906.93 4085.57 N 5647.71 W 5954811.31 N 681794.50 E 26.947 6760.01 12321.01 86.920 356.860 8849.50 8908.26 4113.05N 5647.99 W 5954838.78 N 681793.53 E 18.611 6781.24 12350.59 88.640 355.180 8850.64 8909.40 4142.53 N 5650.05 W 5954868.20 N 681790.75 E 8.125 6805.14 12381.25 89.740 350.530 8851.08 8909.84 4172.94 N 5653.86 W 5954898.51 N 681786.18 E 15.583 6830.89 12411.26 89.820 344.730 8851.19 8909.95 4202.24 N 5660.28 W 5954927.64 N 681779.02 E 19.329 6857.47 12449.52 87.800 343.500 8851.99 8910.75 4239.03 N 5670.75 W 5954964.15 N 681767.64 E 6.181 6892.38 12479.51 88.330 345.610 8853.00 8911.76 4267.92 N 5678.73 W 5954992.83 N 681758.94 E 7.250 6919.64 12518.41 93.080 342.270 8852.52 8911.28 4305.28 N 5689.49 W 5955029.92 N 681747.26 E 14.926 6955.17 12549.85 94.220 338.400 8850.52 8909.28 4334.82 N 5700.05 W 5955059.19 N 681735.97 E 12.808 6984.59 12582.90 92.810 333.480 8848.49 8907.25 4364.94 N 5713.49 W 5955088.95 N 681721.78 E 15.458 7016.30 12616.11 88.330 332.070 8848.16 8906.92 4394.46 N 5728.68 W 5955118.09 N 681705.86 E 14.142 7048.67 12646.72 88.420 328.380 8849.03 8907.79 4421.01 N 5743.87 W 5955144.25 N 681690.01 E 12.054 7078.78 e 12674.04 89.560 326.270 8849.51 8908.27 4444.00 N 5758.62 W 5955166.87 N 681674.70 E 8.777 7105.87 12703.81 91.760 329.780 8849.17 8907.93 4469.25 N 5774.38 W 5955191.71 N 681658.31 E 13.914 7135.34 12732.51 92.110 331.540 8848.20 8906.96 4494.25 N 5788.43 W 5955216.36 N 681643.64 E 6.249 7163.53 12768.59 93.160 334.360 8846.54 8905.30 4526.35 N 5804.82 W 5955248.04 N 681626.45 E 8.332 7198.65 12800.17 93.600 341.210 8844.68 8903.44 4555.51 N 5816.73 W 5955276.90 N 681613.82 E 21.698 7228.65 12837.69 93.690 344.200 8842.29 8901.05 4591.26 N 5827.86 W 5955312.36 N 681601.80 E 7.957 7263.19 12867.86 93.340 351 .230 8840.44 8899.20 4620.67 N 5834.27 W 5955341.59 N 681594.67 E 23.286 7289.83 12899.24 92.460 353.520 8838.85 8897.61 4651.73 N 5838.42 W 5955372.54 N 681589.74 E 7.809 7316.30 12937.78 94.920 0.720 8836.37 8895.13 4690.11 N 5840.36 W 5955410.86 N 681586.85 E 19.704 7346.94 12966.68 95.540 8.810 8833.73 8892.49 4718.77 N 5837.97 W 5955439.57 N 681588.52 E 27.959 7367.36 13005.23 93.080 9.340 8830.83 8889.59 4756.72 N 5831.91 W 5955477.67 N 681593.64 E 6.527 7392.54 13038.60 89.820 14.080 8829.99 8888.75 4789.37 N 5825.14 W 5955510.48 N 681599.59 E 17.234 7413.20 13077.48 90.000 3.890 8830.05 8888.81 4827.73 N 5819.08 W 5955548.97 N 681604.69 E 26.213 7438.68 13109.32 92.550 357.560 8829.34 8888.10 4859.54 N 5818.67 W 5955580.78 N 681604.31 E 21.427 7462.79 7 October, 2004 - 13:53 Page 3 of 5 Oril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for P8U_EOA OS 02·02-16·2·168 Your Ref: API 500292044802 Job No. AKMW3297732, Surveyed: 30 September, 2004 8PXA Comment Vertical Section Dogleg Rate (0/100ft) Global Coordinates Northings Eastings (ft) (ft) Local Coordinates Northings Eastings (ft) (ft) Vertical Depth (ft) Sub-Sea Depth (ft) True Azim. North Slope Alaska Incl Measured Depth (ft) 7495.64 7525.15 7550.16 7583.79 7613.09 11 .243 23.794 25.642 12.930 15.710 681600.11 E 681593.04 E 681584.10 E 681571.23 E 681559.76 E 5955620.88 N 5955654.01 N 5955679.48 N 5955712.98 N 5955741.92 N 5821.87 W 5828.11 W 5836.41 W 5848.44 W 5859.19 W 4899.73 N 4933.02 N 4958.71 N 4992.52 N 5021.74 N 8886.89 8886.84 8887.60 8890.22 8892.88 8828.13 8828.08 8828.84 8831 .46 8834.12 353.340 345.430 338.750 342.090 337.520 90.880 89.300 87.450 84.200 86.040 13149.67 13183.57 13210.59 13246.58 13277.84 e 7643.28 7674.31 7708.30 7730.37 7764.22 10.135 24.499 9.981 8.281 5.856 681546.51 E 681530.80 E 681511.08 E 681497.19 E 681473.88 E 5955770.50 N 5955798.02 N 5955825.94 N 5955843.13 N 5955867.69 N 5871.72 W 5886.74 W 5905.76 W 5919.22 W 5941.91 W 5050.64 N 5078.55 N 5106.95 N 5124.47 N 5149.61 N 8894.36 8894.95 8895.16 8895.16 8894.65 8835.60 8836.19 8836.40 8836.40 8835.89 335.590 327.850 324.510 320.470 315.380 88.590 89.300 90.000 90.000 91.720 13309.38 13341.10 13375.29 13397.39 13431.27 7798.43 7827.43 7858.44 7883.60 7906.85 12.336 19.290 12.426 15.563 12.246 681448.37 E 681424.97 E 681397.98 E 681374.94 E 681353.50 E 5955890.81 N 5955908.83 N 5955926.38 N 5955939.60 N 5955951.69 N 5966.83 W 5989.78 W 6016.33 W 6039.03 W 6060.16 W 5173.36 N 5191.96 N 5210.17 N 5223.97 N 5236.58 N 8892.90 8891.03 8888.72 8885.64 8881.59 8834.14 8832.27 8829.96 8826.88 8822.83 311.850 306.210 302.690 299.870 301.810 94.100 93.130 95.070 98.150 100.530 13465.75 13495.36 13527.64 13554.39 13579.33 7943.49 7972.30 7989.06 8008.58 11.992 17.456 15.612 0.000 681321.42 E 681298.01 E 681285.02 E 681270.05 E 5955972.25 N 5955990.01 N 5956000.90 N 5956013.73 N 6091.71 W 6114.68 W 6127.39 W 6142.03 W 5257.94 N 5276.27 N 5287.48 N 5300.68 N 8874.08 8868.73 8866.45 8864.21 8815.32 8809.97 8807.69 8805.45 306.390 310.790 312.030 312.030 101.760 98.850 96.480 96.480 13618.18 13648.06 13665.16 13685.00 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 02-16. Northings and Eastings are relative to 02-16. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. e Ori/lQuest 3.03.06.006 Page 4 of 5 The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 02-16 and calculated along an Azimuth of 320.000° (True) Based upon Minimum Curvature type calculations, at a Measured Depth of 13685.00ft. The Bottom Hole Displacement is 8113.06ft., in the Direction of 310.795° (True). 7 October, 2004 - 13:53 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-16· 2-16B Your Ref: API 500292044802 Job No. AKMW3297732, Surveyed: 30 September, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10947.47 10949.00 13685.00 8787.71 8788.67 8864.21 3591.40 N 3592.10 N 5300.68 N 4662.66 W 4663.62 W 6142.03 W Tie On Point Window Point Projected Survey e Survey tool program for 02-16 - 2-168 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9394.76 0.00 9394.76 7398.71 13685.00 7398.71 CB-GYRO-MS (02-16) 8864.21 MWD Magnetic (2-16A) e 7 October, 2004 . 13:53 Page 5 of 5 DrillQuest 3.03.06.006 GRAY GEN2 FMC ¡\ / ( µ 15-1/2" TBG, 17#, L-80, .0232 bpf, ID 113-3/8" CSG, 72#, N-80, ID::: I TOP OF 7-5/8" I 9-5/8" CSG, MILLOUT WINDOW 9450' - 9500' 14-1/2" PARKERSW$ NIP, IT' ¡ 4-1/2" I TOP OF LNR-CT, 9.3#, L-80, bpf, ID ITOPOF 2-7/8" LNR· 4-1/2" I 7" LNR, 29#, NT-BO, .0371 bpf. 10::: 6.184" 14-1/2" TEG, 12,6#, 13-CfMiO, ,0152 bpf, ID::: DATE 06/80 10/31/93 12/10/00 03/08/01 01/31/02 06/11/03 BY REV8Y ORIGINAL COMPLETION SIS-SL T CONVERTED SIS-MD FINAL RNITP CMOITLP KB ) -- L - ~ 1 2 3 4 SP . [ill} !Æ~!Æ~ . AI,A.SIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 02-16B BP Exploration (Alaska) Inc. Permit No: 204-157 Surface Location: 4948' NSL, 801' EWL, SEC. 36, TIIN, RI4E, UM Bottomhole Location: 4819' NSL, 5211' WEL, SEC. 26, TIIN, RI4E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissi witness any required test. Contact the Commission's petroleum field inspector at (907) 6 7 (pager). BY ORDER 91 THE COMMISSION DA TED this¡L day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. o Drill B Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4948' NSL, 807' EWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 3101' NSL, 3664' WEL, SEC. 26, T11N, R14E, UM Total Depth: 4819' NSL, 5211' WEL, SEC. 26, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 687542 y- 5950868 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 11000 feet Maximum Hole Angle: 93 degrees I STATE OF ALASKA . RECÊÑ~ßlZ.004 ALASKA AND GAS CONSERVATION COMMISSIONAUG 1 \6"2.004 PERMIT TO DRILL . ." 20 MC 25.005 ~ska Oil & Gas Cons. COmffilSSIO 11 b. Current Well Class 0 Exploratory B Developm~p~OrwMultiPle Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: / Bond No. 2S100302630-277 P8U 02·168 6. Proposed Depth: 12. Field I Pool(s): MD 134 75 rvD 8818ss Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028308 8. Land Use Permit: 13. Approximate Spud Date: October 1, 2004 / 14. Distance to Nearest Property: 32,000' 9. Acres in Property: 2560 18. Casing Program: Size Hole Casing 4-1/8" x 3-314" 3-3116" x 2-718" 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 58.76' feet 1,500' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.0,.,- Downhole: 3250 Surface: 2370 $etting[fflp*h TOp·>· > »<>...><8ottom Coupling Length MD rvD MD rvD (including stage data) TCIII STL 2625' 10850' 8720' 13475' 8818' 121 sx Class 'G' Weight 6.2# 16.16# Grade L-80 PRESENT WELL CONDITION SUMMARY (To be completedforRedriUANDRe~e"trYOpérations) Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth rvD 11933 8875 None 11933 8875 Structural Conductor Surface Intermediate Production Liner 2006' 7" Liner Tieback 845' 7-5/8" Liner 135' 4-1/2" Liner 342' 3-1/2" x 2-7/8" Perforation Depth MD (ft): 11098' - 11923' 98' 3029' 9450' 20" 13-3/8" 9-518" 431 sx Permafrost 2500 sx Fondu, 400 sx PF 'C' 1965 sx Class 'G', 300 sx Permafrost 'C' 98' 3029' 9450' 98' 2676' 7447' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch 380 sx Class 'G' 9299' - 11305' Uncemented 8454' - 9299' Uncemented 11212'-11347 Uncemented 11178' -11520' IPerfOration Depth rvD (ft): 8867' - 8875' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements 7317' - 8902' 6616' - 7317' 8895' - 8900' 8890' - 8892' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sean McLaughlin Title CT Drilling Engineer Date: Contact Sean McLaughlin, 564-4694 Phone API Number: 1 Permit Approval 50- 029-20448-02-00 Date: Samples Required DYes ;8'No Mud Log Required Hydrog ulfide Measures %yes D No Directional Survey Required Other: Tee; t bO ¡) E ,'~S"Oo psi per C. v, 'S ¡ Co. coo. See cover letter for other requirements DYes WNo 18Yes DNa ORIGINAL APPROVED BY THE COMMISSION Date ~'~~ I"Cf ~':t Inhu;licate . BP 02-16B Sidetrack . CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement and perforate Mud Program: · Well kill: 8.4 - 8.9 .:;:P~rjè · Milling/drilling: 8'VPg used PIo Pro or biozan for milling, new PIo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class n wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / · 33/16" x 2 7/8" solid cemented liner completion~ 0850' -- 13475'. · The liner cement volume is planned to be<....25 Is of 15.8 ppg class G. CasinelLiner Information '---c 13 3/8", N-80, 72#, Burst 5380 psi; collapse 2670 psi 95/8", L-80 47#, Burst 6870, collapse 4750 psi 7", NT-80, 29#, Burst 8160, collapse 7020 psi 4 W' L-80, 12.6#, Burst 8430 psi; collapse 7500 psi planned 3 3/16" L-80 TCn, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") 27/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size 3.75") 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 94 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property line: 32000' ft · Distance to nearest well within pool: 1500 ft Logging · MWD directional and Gamma Ray will be run over all of the openhole section. · MCNL will be run cased hole. Hazards · Drill Site 2 is not designated as an HzS pad. · One planned fault crossing · Lost circulation risk is considered low. / Reservoir Pressure · Res. press. is estimated to be 3250 psi at 8800'ss (7.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2370 psi. ) -- TREE = GRA Y GEN 2 W8.LI-EAD = FMC ACTUATOR = AXELSON KB. aEV = 58.8' BF. aEV = KOP = 1298' Max Angle = 97 @ 11784' Datum MD = 11077' Datum TVD = 8800' SS 15-1/2" 1BG, 17#, L-80, .0232 bpf, ID = 4.892" H 29' 1 TOP OF 4-1/2' 1BG H 29' 113-3/8" CSG, 72#, N-80, ID = 12.347" H 3029' IMinimum ID =2.441" @ 11186' 3-1(2" X 2-7/8" XO TOPOF7-518" LNR-TlffiACK H 17-518" LNR- TBK, 29.7#, NT-BO, :0459 bpf, D = 6.875" H ITOPOF7" LNR H rTOPOFCEWENT H 02-16A ~ ) j; I t-Â 8454' 9299' 9299' 9306' 1 g.518" CSG, 47#, L-80, ID = 8.681" H 9450' r-, II II 14-1/2"TBG,12.6#, L-80, .0152bpf,ID=3.958" H 10922' 1 TOP OF 3-lIZ' LI\R - CT H 11178' 1 3-1/2"lNR-CT, 9.3#, L-80, .0087 bpf,lD = 2.992' H 11186' J ITOPOF2-7/S"ll\R-PORTED H 11186' r I TOP OF 4-1/Z'lBG H 11212' J 7" LNR, 29#, NT-BO, .0371 bpf, 10 = 6.184" H 11305' 14-1/Z'1BG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" H 1134T ÆRFORATION SUMMð.RY REF lOG: MND ON 10122/93 ANGlEA T TOP PERF: 68 @ 11098' robte: Refer to A"oduction DB for hisbrical perf data SIZE SPF IN1ERVAl OprVSqz DATE 2-7/8" 4 11098-11114 0 10/16/00 2-7/S" 32 11347 -11923 0 10,Q2/93 2-7/S" 32 11347 - 11520 0 04/29/94 [)ð. TE RBI BY COMWENTS 06/BO O~INAL COMA.E1lON 10131/93 SIŒTRAO< 12/10100 SS-SL T CONVERTED TO CANV AS 03108101 SIS-M) FINAL 01/31/02 RNIlP CORREC1lONS 06111/03 CM)/lLP KB B.EV A TION OORRECTION L_ SAFETY NOTES: 4-112' a-JROMETBG. HORIZONTAL WELL - 700 @ 11097' AND 90" @ 11274' 29' H5-1/Z' X 4-1/2" XO I . - 2103' H4-1/Z' CAM 1RCP-4A SSSV NP,ID=3.S12" ~ GAS LIFT Mð.NJR8.S ST M) TVD DEV TYÆ VlV LATCH PORT DATE 1 3597 3056 48 TGFÐ RK 2 6941 5444 39 TGFÐ RK 3 9100 7148 33 lMPDX BK 4 9205 7237 32 lMPDX BK L - 9270' H4-1/Z' BAKER FaR I MIlLOUT WlNJON 9450' - 9500' I 10754' H4-1/Z' PARKERSWS NP,ID =3.S12" I 1 10766' H7" BAKER SABL-3 PKR I 10909' H4-1/2" PAR<ERSWS NIP, 10= 3.81Z 10922' H4-1/Z' TLBING TAIL WlEG J H8.MDTTNOTlOGGED I 11178' H4-1/2"BAKERSC-1LPKR 11186' 11212' 11218' H3-1/2" X 2-7/fr' XO, D = 2.441" H7" BAKER FB-1 A<R(BB-I LNR) H4-1/2" PARKER fNIIS NIP. I 110= 3.813" ----f 11347'. H4-1/Z'lUBINGTAIl 12-718" LNR- PORTED, 6.5#, H 11520' L-80, .0056 bpf, 10 = 2.441" I . ~ 11933' DATE REV BY COMWENTS PRUDI-OE BAY LNIT WElL: 02-16A PERMTrob: 1931160 API rob: 50-02g.20448-01 SEC 36, T11 N, R14E, 4589.95' ÆL & 1417.31' FNl BP Exploration (Alaska) GRAY GEN2 WELLHEAD'" FMC 15-1/2" TBG, 17#, l-80, .0232 bpf,ID '" ¡TOP OF 7-5/8" 17-518" lNR- TBK, 29.7#, NT-80, ,0459 bpf, ID '" 8.875" ! TOP OFT' lNR I.., I TOP OF CEMENT 1 9-5/8" 47#, MlllOUT WINDOW 9450' - 9500' 4-1/2" TBG, 12.6#, TOPOF 3c1/:?" lNR ~ ¡ 3-1/2" lNR-CT, 9.3#, l-80, .0087 bpf, 10 '" ¡ TOP OF I TOP OF 4-1/2" TaG H 17" lNR, 29#, NT-80, .0371 bpf, ID H TBG, 12.8#, ,0152 bpf. tD'" 3,958" H PERFORATION SUMMARY REF LOG: MWD ON 10/22/93 ANGLE AT TOP PERF: 68 @ 11098' Note: Refer to Production DB for historíc¡:¡lperf data SPF INTERVAL Opn/Sqz 2-7/8" 4 11098 - 11114 0 2-718" 32 11347 -11923 0 2-7/8" 32 11347 -11520 0 10/16/00 10/02/93 04/29/94 DATE 06/80 10/31/93 12/10/00 03/08/01 01/31102 06/11/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL RNlTP CORRECTIONS CMO/TLP KB ELEVATION /) 61 ~ ) l - g 10922' 11341' ~ ~ ttE~ ~ ~ 2-7/8"LNR- romED, ¡-¡ ,Q056bpf,IJ"'2A41" I COMMENTS 29' 2103' . MD ìVD 1 3597 3056 2 6941 3 9100 4 9205 DATE ¡ ! !D '" 3.813" 11347' 1- 4-1/2" TU61NGTAIL I 11520' 11520' 11933' ObP . . B.. ....... INTEQ BP-GDB Baker Hughes INTEQ Planning Report Field: Prudhoe 8ay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Datum: Mean Sea Level Map Zone: Coordinate System: Model: Alaska, Zone 4 Well Centre Site: P8 OS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948800.37 ft 687638.44 ft Latitude: Longitude: North Reference: Grid 70 15 53.847 N 148 28 58.060 W True 1.43 Well: 02-16 Slot Name: 16 02-16 Well Position: +N/-S 2069.27 ft Northing: 5950867.76 ft Latitude: 70 16 14.199 N +E/-W -44.66 ft Easting : 687542.23 ft Longitude: 148 28 59.360 W Position 0.00 ft Wellpath: Plan#5 02-168 500292044802 Current Datum: 39: 169/10/199300:00 Magnetic Data: 8/9/2004 Field Strength: 57620 nT Vertical Section: Depth From (TVD) ft 28.76 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 02-16A 10978.70 ft Mean Sea Level 25.21 deg 80.85 deg Direction Height 58.76 ft 320.00 Targets Name 02-168 Polygon4.1 0.00 5356.29 -6183.06 5956067.99 681228.00 70 17 6.853 N 148 31 59.485 W -Polygon 1 0.00 5356.29 -6183.06 5956067.99 681228.00 70 17 6.853 N 148 31 59.485 W -Polygon 2 0.00 4792.23 -6109.09 5955505.99 681316.00 70 17 1.306 N 148 31 57.317 W -Polygon 3 0.00 4309.14 -5952.07 5955026.99 681485.00 70 16 56.556 N 148 31 52.732 W -Polygon 4 0.00 3894.41 -5768.33 5954616.99 681679.00 70 16 52.478 N 148 31 47.371 W -Polygon 5 0.00 3580.55 -5618.10 5954306.99 681837.00 70 16 49.393 N 148 31 42.988 W -Polygon 6 0.00 3433.35 -5130.59 5954171.99 682328.00 70 16 47.948 N 148 31 28.786 W -Polygon 7 0.00 3500.24 -4964.86 5954242.99 682492.00 70 1648.607 N 148 31 23.961 W -Polygon 8 0.00 3727.00 -5152.28 5954464.99 682299.00 70 16 50.836 N 148 31 29.424 W -Polygon 9 0.00 3898.98 -5470.11 5954628.99 681977.00 70 16 52.526 N 148 31 38.685 W -Polygon 10 0.00 4269.23 -5554.92 5954996.99 681883.00 70 16 56.166 N 148 31 41.163 W -Polygon 11 0.00 4834.88 -5692.87 5955558.99 681731.00 70 17 1.728 N 1483145.194W -Polygon 12 0.00 5205.53 -5753.66 5955927.99 681661.00 70 17 5.373 N 148 31 46.973 W 02-168 Fault 1 0.00 4203.64 -5371.48 5954935.99 682068.00 70 16 55.523 N 148 31 35.818 W -Polygon 1 0.00 4203.64 -5371.48 5954935.99 682068.00 70 16 55.523 N 148 31 35.818 W -Polygon 2 0.00 3419.39 -5333.01 5954152.99 682126.00 70 16 47.810 N 148 31 34.682 W 02-168 Fault 2 0.00 4283.12 -6071.76 5954997.99 681366.00 70 16 56.299 N 148 31 56.218 W -Polygon 1 0.00 4283.12 -6071.76 5954997.99 681366.00 70 16 56.299 N 148 31 56.218 W -Polygon 2 0.00 5592.17 -6335.24 5956299.99 681070.00 70 17 9.171 N 148 32 3.924 W 02-168 T4.4 8818.00 5145.95 -5972.23 5955862.99 681444.00 70 17 4.786 N 148 31 53.338 W 02-168 T4.1 8861.00 3648.70 -5021.18 5954390.00 682432.00 70 16 50.067 N 148 31 25.604 W 02-168 T4.3 8862.00 4304.89 -5701.08 5955028.99 681736.00 70 16 56.516 N 148 31 45.421 W 02-168 T4.2 8866.00 3619.93 -5432.05 5954350.99 682022.00 70 16 49.781 N 148 31 37.570 W ObP Annotation 10978.70 11000.00 11020.00 11060.00 11352.00 11552.00 11777.00 12387.00 12537.00 12737.00 13017.00 13475.00 8748.00 8760.23 8771.17 8790.67 8860.98 8863.50 8866.34 8863.36 8862.13 8855.69 8839.66 8817.84 . . Bii. ...... INTEQ BP-GDB Baker Hughes INTEQ Planning Report TIP KOP end 9 DLS / begin 20 DLS 4 end 20 DLS / begin 12 DLS 6 7 8 9 10 11 TO Plan: Plan #5 After importing Finder surveys Yes Plan Section Information Date Composed: Version: Tied-to: 8/9/2004 6 From: Definitive Path 10978.70 53.92 306.68 8748.00 3606.11 -4682.54 0.00 0.00 0.00 0.00 11000.00 56.00 305.95 8760.23 3616.43 -4696.59 10.16 9.77 -3.43 343.76 11020.00 57.69 305.22 8771.17 3626.17 -4710.21 9.00 8.47 -3.64 340.00 11060.00 63.95 299.51 8790.67 3644.80 -4739.71 20.00 15.64 -14.29 320.00 11352.00 90.00 245.19 8860.98 3648.46 -5010.22 20.00 8.92 -18.60 287.50 11552.00 88.58 269.15 8863.50 3604.35 -5203.78 12.00 -0.71 11.98 93.50 11777.00 90.00 296.11 8866.34 3653.09 -5421.29 12.00 0.63 11.98 87.20 12387.00 90.48 9.31 8863.36 4159.07 -5682.34 12.00 0.08 12.00 89.50 12537.00 90.46 351.31 8862.13 4308.44 -5681.53 12.00 -0.02 -12.00 270.00 12737.00 93.18 327.45 8855.69 4494.18 -5751.38 12.00 1.36 -11.93 276.80 13017.00 93.20 1.10 8839.66 4759.41 -5826.05 12.00 0.01 12.02 89.00 13475.00 91.84 . 306.10 8817.84 5153.57 -6021.83 12.00 -0.30 -12.01 270.00 11060.00 63.95 299.51 8790.67 3644.80 -4739.71 5954393.11 682713.46 5838.71 20.00 322.18 4 11075.00 64.89 296.35 8797.15 3651.14 -4751.66 5954399.14 682701.36 5851.24 20.00 287.50 MWD 11100.00 66.59 291.19 8807.43 3660.31 -4772.51 5954407.80 682680.28 5871.67 20.00 288.86 MWD 11125.00 68.46 286.17 8816.99 3667.70 -4794.39 5954414.64 682658.23 5891.40 20.00 290.98 MWD 11127.76 68.68 285.63 8818.00 3668.41 -4796.86 5954415.28 682655.74 5893.53 20.00 292.90 02-168 11150.00 70.48 281.29 8825.76 3673.25 -4817.12 5954419.62 682635.37 5910.26 20.00 293.10 MWD 11175.00 72.62 276.52 8833.68 3676.91 -4840.54 5954422.70 682611.86 5928.12 20.00 294.62 MWD 11200.00 74.88 271.87 8840.68 3678.66 -4864.47 5954423.85 682587.90 5944.84 20.00 296.13 MWD 11225.00 77.22 267.32 8846.71 3678.49 -4888.72 5954423.07 682563.66 5960.30 20.00 297.43 MWD 11250.00 79.65 262.86 8851 .72 3676.39 -4913.12 5954420.37 682539.33 5974.37 20.00 298.53 MWD 11275.00 82.13 258.46 8855.68 3672.38 -4937.47 5954415.75 682515.09 5986.95 20.00 299.42 MWD 11300.00 84.66 254.12 8858.56 3666.50 -4961.59 5954409.27 682491.12 5997.95 20.00 300.12 MWD 11325.00 87.22 249.82 8860.33 3658.78 -4985.29 5954400.96 682467.62 6007.27 20.00 300.62 MWD 11350.00 89.79 245.53 8860.98 3649.29 -5008.40 5954390.90 682444.76 6014.86 20.00 300.92 MWD 11352.00 90.00 245.19 8860.98 3648.46 -5010.22 5954390.02 682442.96 6015.39 20.00 301.04 end 20 11375.00 89.83 247.94 8861.02 3639.31 -5031.32 5954380.35 682422.10 6021.94 12.00 93.50 MWD 11400.00 89.65 250.93 8861.13 3630.53 -5054.72 5954370.99 682398.92 6030.26 12.00 93.50 MWD . , ObP . . 8ii. ..... INTEQ BP-GDB Baker Hughes INTEQ Planning Report 89.47 253.93 8861.32 3622.98 -5078.55 5954362.86 682375.28 6039.80 12.00 93.48 MWD 89.29 256.92 8861.59 3616.70 -5102.74 5954355.97 682351.26 6050.53 12.00 93.46 MWD 89.11 259.92 8861.94 3611.68 -5127.23 5954350.34 682326.91 6062.43 12.00 93.43 MWD 11500.00 88.93 262.91 8862.37 3607.95 -5151.94 5954346.00 682302.30 6075.45 12.00 93.38 MWD 11525.00 88.76 265.91 8862.88 3605.51 -5176.82 5954342.94 682277.49 6089.58 12.00 93.33 MWD 11550.00 88.59 268.91 8863.45 3604.38 -5201.78 5954341.19 682252.56 6104.76 12.00 93.27 MWD 11552.00 88.58 269.15 8863.50 3604.35 -5203.78 5954341.11 682250.57 6106.02 12.00 93.20 6 11575.00 88.71 271.90 8864.05 3604.56 -5226.77 5954340.75 682227.58 6120.96 12.00 87.20 MWD 11600.00 88.87 274.90 8864.58 3606.04 -5251.72 5954341.61 682202.60 6138.13 12.00 87.13 MWD 11625.00 89.02 277.90 8865.04 3608.83 -5276.56 5954343.77 682177.71 6156.23 12.00 87.07 MWD 11650.00 89.18 280.89 8865.43 3612.91 -5301.22 5954347.24 682152.96 6175.20 12.00 87.02 MWD 11675.00 89.34 283.89 8865.75 3618.27 -5325.63 5954351.99 682128.42 6195.01 12.00 86.97 MWD 11700.00 89.50 286.88 8866.01 3624.90 -5349.73 5954358.02 682104.16 6215.58 12.00 86.93 MWD 11725.00 89.66 289.88 8866.19 3632.79 -5373.45 5954365.31 682080.25 6236.86 12.00 86.90 MWD 11750.00 89.83 292.88 8866.30 3641.90 -5396.73 5954373.84 682056.76 6258.81 12.00 86.88 MWD 11775.00 89.99 295.87 8866.34 3652.22 -5419.50 5954383.58 682033.74 6281.34 12.00 86.86 MWD 11777.00 90.00 296.11 8866.34 3653.09 -5421.29 5954384.41 682031.92 6283.17 12.00 86.86 7 11800.00 90.03 298.87 8866.34 3663.71 -5441.69 5954394.52 682011.26 6304.42 12.00 89.50 MWD 11825.00 90.05 301.87 8866.32 3676.35 -5463.26 5954406.61 681989.39 6327.96 12.00 89.50 MWD 11850.00 90.08 304.87 8866.29 3690.10 -5484.14 5954419.84 681968.18 6351.91 12.00 89.50 MWD 11875.00 90.10 307.87 8866.25 3704.92 -5504.26 5954434.15 681947.69 6376.21 12.00 89.51 MWD 11900.00 90.13 310.87 8866.20 3720.78 -5523.59 5954449.52 681927.98 6400.77 12.00 89.51 MWD 11925.00 90.16 313.87 8866.14 3737.62 -5542.06 5954465.90 681909.10 6425.55 12.00 89.52 MWD 11950.00 90.18 316.87 8866.07 3755.41 -5559.62 5954483.25 681891.10 6450.47 12.00 89.52 MWD 11975.00 90.20 319.87 8865.98 3774.10 -5576.22 5954501.51 681874.03 6475.45 12.00 89.53 MWD 12000.00 90.23 322.87 8865.89 3793.62 -5591.83 5954520.64 681857.95 6500.44 12.00 89.54 MWD 12025.00 90.25 325.87 8865.78 3813.94 -5606.39 5954540.59 681842.88 6525.37 12.00 89.55 MWD 12050.00 90.27 328.87 8865.67 3834.99 -5619.87 5954561.30 681828.89 6550.16 12.00 89.57 MWD 12075.00 90.29 331.87 8865.55 3856.72 -5632.23 5954582.71 681815.99 6574.74 12.00 89.58 MWD 12100.00 90.32 334.87 8865.41 3879.06 -5643.43 5954604.77 681804.23 6599.06 12.00 89.60 MWD 12125.00 90.33 337.87 8865.27 3901.97 -5653.45 5954627.41 681793.65 6623.05 12.00 89.61 MWD 12150.00 90.35 340.87 8865.12 3925.36 -5662.26 5954650.57 681784.26 6646.63 12.00 89.63 MWD 12175.00 90.37 343.87 8864.96 3949.18 -5669.83 5954674.20 681776.10 6669.75 12.00 89.65 MWD 12200.00 90.39 346.87 8864.80 3973.37 -5676.14 5954698.22 681769.19 6692.33 12.00 89.67 MWD 12225.00 90.40 349.87 8864.62 3997.85 -5681.18 5954722.57 681763.54 6714.33 12.00 89.69 MWD 12250.00 90.42 352.87 8864.44 4022.56 -5684.93 5954747.18 681759.17 6735.67 12.00 89.71 MWD 12275.00 90.43 355.87 8864.26 4047.44 -5687.39 5954771.98 681756.10 6756.30 12.00 89.73 MWD 12300.00 90.45 358.87 8864.06 4072.41 -5688.53 5954796.92 681754.33 6776.17 12.00 89.75 MWD 12325.00 90.46 1.87 8863.87 4097.41 -5688.37 5954821.91 681753.87 6795.21 12.00 89.77 MWD 12350.00 90.47 4.87 8863.67 4122.36 -5686.90 5954846.89 681754.72 6813.38 12.00 89.80 MWD 12375.00 90.48 7.87 8863.46 4147.20 -5684.13 5954871.79 681756.87 6830.63 12.00 89.82 MWD 12387.00 90.48 9.31 8863.36 4159.07 -5682.34 5954883.69 681758.37 6838.56 12.00 89.85 8 12400.00 90.48 7.75 8863.25 4171.92 -5680.41 5954896.59 681759.97 6847.17 12.00 270.00 MWD 12425.00 90.48 4.75 8863.04 4196.77 -5677.69 5954921.50 681762.08 6864.46 12.00 269.99 MWD 12450.00 90.48 1.75 8862.84 4221.73 -5676.27 5954946.48 681762.87 6882.66 12.00 269.96 MWD 12475.00 90.47 358.75 8862.63 4246.72 -5676.16 5954971.47 681762.36 6901.74 12.00 269.94 MWD 12500.00 90.47 355.75 8862.42 4271.69 -5677.36 5954996.40 681760.54 6921.64 12.00 269.91 MWD 12525.00 90.46 352.75 8862.22 4296.56 -5679.86 5955021.20 681757.41 6942.30 12.00 269.89 MWD 12537.00 90.46 351.31 8862.13 4308.44 -5681.53 5955033.04 681755.45 6952.47 12.00 269.86 9 12550.00 90.64 349.76 8862.00 4321.27 -5683.67 5955045.80 681753.00 6963.67 12.00 276.80 MWD 12575.00 90.99 346.78 8861.65 4345.74 -5688.75 5955070.14 681747.31 6985.68 12.00 276.79 MWD 12600.00 91.34 343.80 8861.13 4369.91 -5695.09 5955094.14 681740.36 7008.28 12.00 276.74 MWD 12625.00 91.69 340.82 8860.47 4393.72 -5702.69 5955117.75 681732.18 7031.40 12.00 276.68 MWD . . ObP . . B.. ...... INTF.Q BP-GDB Baker Hughes INTEQ Planning Report 12650.00 92.03 337.84 8859.66 4417.09 -5711.50 5955140.90 681722.78 7054.97 12.00 276.60 MWD 12675.00 92.37 334.85 8858.70 4439.97 -5721.53 5955163.52 681712.19 7078.94 12.00 276.51 MWD 12700.00 92.70 331.87 8857.59 4462.30 -5732.72 5955185.56 681700.44 7103.24 12.00 276.39 MWD 12725.00 93.03 328.88 8856.34 4484.00 -5745.06 5955206.94 681687.57 7127.80 12.00 276.26 MWD 12737.00 93.18 327.45 8855.69 4494.18 -5751.38 5955216.96 681681.00 7139.66 12.00 276.11 10 12750.00 93.20 329.01 8854.97 4505.21 -5758.22 5955227.82 681673.89 7152.50 12.00 89.00 MWD 12775.00 93.25 332.02 8853.56 4526.94 -5770.50 5955249.23 681661.07 7177.04 12.00 89.09 MWD 12800.00 93.28 335.02 8852.14 4549.28 -5781.63 5955271.29 681649.39 7201.31 12.00 89.26 MWD 12825.00 93.31 338.03 8850.70 4572.17 -5791.57 5955293.92 681638.88 7225.23 12.00 89.43 MWD 12850.00 93.32 341.03 8849.26 4595.55 -5800.30 5955317.07 681629.57 7248.75 12.00 89.60 MWD 12875.00 93.33 344.04 8847.81 4619.35 -5807.79 5955340.68 681621.49 7271.80 12.00 89.77 MWD 12900.00 93.33 347.04 8846.35 4643.51 -5814.02 5955364.68 681614.66 7294.32 12.00 89.95 MWD 12925.00 93.32 350.05 8844.90 4667.97 -5818.98 5955389.01 681609.10 7316.24 12.00 90.12 MWD 12950.00 93.30 353.05 8843.46 4692.66 -5822.64 5955413.59 681604.82 7337.51 12.00 90.30 MWD 12975.00 93.27 356.06 8842.03 4717.50 -5825.01 5955438.37 681601.83 7358.06 12.00 90.47 MWD 13000.00 93.23 359.06 8840.61 4742.43 -5826.08 5955463.26 681600.15 7377.84 12.00 90.64 MWD 13017.00 93.20 1.10 8839.66 4759.41 -5826.05 5955480.23 681599.75 7390.83 12.00 90.81 11 13025.00 93.20 0.14 8839.21 4767.39 -5825.96 5955488.22 681599.63 7396.89 12.00 270.00 MWD 13050.00 93.19 357.14 8837.82 4792.34 -5826.56 5955513.15 681598.42 7416.39 12.00 269.95 MWD 13075.00 93.18 354.13 8836.43 4817.23 -5828.46 5955537.97 681595.90 7436.67 12.00 269.78 MWD 13100.00 93.15 351.13 8835.05 4841.98 -5831.66 5955562.64 681592.08 7457.69 12.00 269.61 MWD 13125.00 93.12 348.12 8833.68 4866.54 -5836.15 5955587.07 681586.98 7479.39 12.00 269.45 MWD 13150.00 93.08 345.12 8832.33 489D.82 -5841.93 5955611.20 681580.60 7501.70 12.00 269.28 MWD 13175.00 93.03 342.12 8831.00 4914.77 -5848.97 5955634.96 681572.97 7524.57 12.00 269.12 MWD 13200.00 92.97 339.11 8829.69 4938.31 -5857.25 5955658.30 681564.10 7547.94 12.00 268.96 MWD 13225.00 92.90 336.11 8828.41 4961.40 -5866.76 5955681.13 681554.02 7571.73 12.00 268.80 MWD 13250.00 92.83 333.11 8827.16 4983.95 -5877.47 5955703.41 681542.75 7595.89 12.00 268.65 MWD 13275.00 92.74 330.10 8825.95 5005.92 -5889.34 5955725.07 681530.34 7620.35 12.00 268.50 MWD 13300.00 92.65 327.10 8824.77 5027.23 -5902.35 5955746.05 681516.80 7645.04 12.00 268.35 MWD 13325.00 92.56 324.10 8823.64 5047.83 -5916.46 5955766.30 681502.19 7669.89 12.00 268.21 MWD 13350.00 92.45 321.10 8822.54 5067.67 -5931.63 5955785.75 681486.53 7694.84 12.00 268.08 MWD 13375.00 92.34 318.10 8821.50 5086.69 -5947.81 5955804.36 681469.88 7719.81 12.00 267.94 MWD 13400.00 92.22 315.10 8820.50 5104.84 -5964.97 5955822.07 681452.27 7744.75 12.00 267.82 MWD 13425.00 92.10 312.10 8819.56 5122.07 -5983.06 5955838.84 681433.76 7769.57 12.00 267.70 MWD 13450.00 91.97 309.10 8818.67 5138.32 -6002.03 5955854.62 681414.39 7794.21 12.00 267.59 MWD 13475.00 91.84 306.10 8817.84 5153.57 -6021.83 5955869.37 681394.22 7818.62 12.00 267.48 TO BP Amoco WELLPATH OMTÞdLS Pl3n#f 02'46. 500292044302 Pa...nt W~lp.th: 024U Tie Oft MO: 109'18.10 "'0' ftot. ÞatUm1 V .s.etÎ(U~ ..... 39 16 9/10/1&93 0:1):0.0 58.'16ft ~~~ ~~; ~::~ 28.76 58.76 , , , 4 . ¡ i! TV. ~3.1U 300.$$ 8741:1",\)(. ~.OO <$OS.95 376.0'.2:3- n.R .:rojJ~2 ð771,i7 S3;.M 291M!-1 &1~e7 S(I.ot) .245.1& -8$i'i~-aa 8,$.$4 261M:!> 3t1&3..ßO 00.00 "Ö6.11 &lMla.34 $0,:4$ $.31 UU,H &0.46 351,;).1 8M2.,;a fl,'Ui: 321.4$ 885$;651 93,20 1.10' .&839.. 1»,$4 ~.10 $17.114 'iWtlEM-f 3e16.4~ 3626.17 :W44AIÐ "'...... 3$4;;35- 3Øsa..09 415$.0'7 43/W44 ......,. :;:::i tlt.!lCS TF4IQ! 0.00 -U,M 10.:f6 '343.76. IUW- 340'.00 $0,00 :no..OO :20.00 287,iSO fZM .M.M 12<00 81'.20 1~OO $9,;50 1:t.oo- -1i!:7Ø,OO 1Z.00 2:J!'·!MIO 1%;00 !MUm 1:¡"OO 270..00 V'"'. .$772.3.2 5749,2.6- 46OI>.4B- 51U&.11 50'15,39 ~I"IQIU)2 62ß;t,n 68Zð.56 6ttn,4'1 71afMI$ 7390.83 71'1iaÆ2 ANNOTAT"'.S { YO Anm>taUon TI. KO' _d f,I OLS! healll :to 01. i'" ,. D" , ".i. .. ,. " TD _L '¡" ;;¡ 8100 .... 88200 ,.. .....8300 = 1'8400 Q ... 8500' ca .28600 1: ~ 8700 ID ë 8800~ ... 8900 9100 9200 - LEGEND 02-16 (02-16) 02-16 {02~16A} 15·42 (15-42) 15-42 (15-42A) P!an#502-168 P!an#5 T ^M Azimuths to True North Magnetic North: 25.21' Ma9netic Field Strength: 57620n T Dip Angle-:-80.85' Date: 8/9/2004 Model: bggm2004 Plan: Plan #5 (02~ 16/Plan#5 02-16B) Created By: Brij Potnis Date: 8/1312004 InformsTIon 6400 3600 6200 6000 5800 5600 '¡"5400 i 5200 Q g 5000 ..... +4800 ..... .&: 1: 4600 o _ !!; 4400 - . ..... .&: 4200 .. :5 : 4000 3800 3400 3200 3000 -8000 -7800 -7600 -7400 -7200 -7000 -6800 -6600 -6400 -6200 -6000 -5800 -5600 -5400 -5200 -5000 4800 -4600 -4400 -4200 4000 -3800 -3600 -3400 -3200 -3000 -2800 West(-)/East{+) [200ft/in] 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 Vertical Section at 320.00· [100ft/in] I WELJ DETAILS ANTI-COLLJS!ON SETTINGS COMPANY DETAILS Na",,' "N -S -E·\\' ¡>';"flhmg Lm;!"d~ LOl\g!wd" SI<'I Interpolation MethodMD + StatíbDærvaJ 10.00 Dept.h Range From" 11000.00 To 13475.00 MaXimum Range ¡ 544.62 Reference: Plan: Plan #5 BPAmOC0 O~-¡Ó W~(j867_7b 7()"j(¡<!4.199N !48'2S'W.:MiJ'I'i 16 -326 100 50 o 50 100 150 --200 250 300 L.-326 300 250 200 150 / /// ~ TravelJing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] n"plJ,Fm Dep!¡ rü Sm-v"y'H.m 10978.70 D·175.00 PJarU1.o<J:P!:¡11i15V6 SeRVFY PROGRAM 90 ------ WELLPATH lÆTAILS MWI) P!ani<5Ü2·\6B í00292044i;02 ¡).ar~'n WdJpa!h' 02-16/1. rl~ "n J,.-fD ¡097JPO Rig Rd:Daium ì69WII}9]OOoO(j 5fU6l1 ~~g.s Ongm cE.W ~::~¡1VD LEGEND 02-16 (02-16), NOERRORS 02-16 (02-16A), NOERRORS 07-33 (07-33), Major Risk 07-33 (07-33A), Major Risk 07-33 (07-33APB I), Major Ris~¡ 07-33 (07-33APB2), Major Ris!; 07-33 (07-33B), Major Risk 15-11 (15-11), Major IYsk 15-11A (15-11A), Major Risk 15-11 (Plan 15-118), Major Ris 15-38 (15-38), Major Risk 15-38 (15-38A), Minor 1/10 15-38 (15-38AP81), Major RisM 15-42 (15-42), Minor 1/10 1542 (15-42A), Minor 1/10 15-42 (15-42P8 1), Major Risk 1542 (15-42P82), Major Risk 15-42 (15-42P83), Major Risk Plan#5 02-168 Plan #5 $ECTJON ¡)ETA!L$ 8/13/2004 1:32 PM I 2500----;~"-" ....-. ¢:: '--' ~ o .- ...... ro a 0.- (j) U') (j) J:J ~ (j) U 1500--, o ...... (j) J:J ~ (j) u 500 o rlan: rlan #5 (02-16fI>lan#5 02-16B) I i 12500 Measured Depth [ft] 02-16 (02-16) 07-33 (07-33) 07-33 (07-33APB1) 07-33 (07-33B) I5-I1A (l5-IIA) 15-38 (15-38) 15-38 (15-38APB1) 15-42 (15-42A) 15-42 (I5-42PB2) 02-16 (02-16A) 07-33 (07-33A) 07-33 (07-33APB2) 15-11 (15-11) 15-11 (plan I5-lIB) 15-38 (15-38A) 15-42 (15-42) 15-42 (15-42PBl) 15-42 (15-42PB3) - - . ". ObP . BP-GDB Anticollision Report . ... ..... INTEQ _._-"~"---~~"~-----~--~..~"~~>-~._-_._~----,-~._------------------~-----"-~~~-_.~~,---,.- -~~---~-----~'--l i Comp~ny: BP Amoco Date: 8/13/2004 Time: 13:19:56 Page: 1 i I Field: Prudhoe Bay I Reference Site: PB DS 02 C(H)rdlnate(NE) Reference: I i Reference Well: 02-16 Vertical (TVD) Reference: I [~~!:e~e.nce~elll~l!t~:_.~~an~g~:1~!3____.________.______~________~ ____________~__~__ J)b:~racle ____J I-GLOBALSCANAPPU:ED~A";'cllp;h;-;ith¡;; 2oo'+lòoìloÒO ~f;~ie-;;~;e-:Th;;; ar~tlfell;i;;-thB~la;;-#5 & -NOT¡;LAN-NEO¡;ROG~ V1 ! Interpolation Method: MD + Stations Interval: 10.00 ft Error Model: ISCWS~ Ellipse : ¡ Depth Range: 11000.00 to 13475.00 ft Scan Method: Trav Cylinder North I i_M~~m.'l~ ~a~i~s-=-_1~44~6~__ft__ .__ _ ___ _______ _ ___.______________ _____Error~~tilce:__~~Ii¡)~~_+~~~~__.____________: Casing Points I-----MD---TVI)----D¡;~eter -~HOI~ SI~--- N~;~-~--------m------m-m----------I i ft ft In m ¡ r-3029.00--·2674~94----1i375----1-7 :SOO-~-13-3;8;;---~- ~--- --------------·-------·-----------------1 I 9450.00 7446.99 9.625 12.250 95/8" I i 11000.00 8818.99 7.000 8.500 7" i ¡ 13475.00 8876.60 2.875 3.750 27/8" i '_^'~__ ._______._~~ ____ ____.______________..___.___~__ ~~__~_______.___ _ _ .__ c_.______._.__"____~_.______._ ~___~__~_____.,_.~__"__,,___.____,~___._,.~,._____ _._____.____,_____~___~_,_____..___....l Plan: Plan #5 After importing Finder surveys Yes Date Composed: Version: Tied-to: 8/9/2004 6 From: Definitive Path Summary r~------·----Otrs;W_;lIpath-=----·~-~--;-----~-~R;fe~;---Otrset --- Ctr..ctrN~ AllOw~h~-____~c----~ ¡Site Well WellPath MD M.D Distance 'Area D~latiOD Waming I ! ft ft ft ft ft I I -PBDS-02 -- ---- -- 02-16- - - --- ~--~02-1ãV7----·----- ---110Ó2.0S---11oo0.00 234.75--0.00---234:75- Pass: NOERRORS PB os 02 02-16 02-16A V1 11000.00 11000.00 0.00 0.00 0.00 FAIL: NOERRORS PB OS 07 07-33 07-33 V4 11788.56 11200.00 1134.37 857.13 277.24 Pass: Major Risk PB OS 07 07-33 07-33A V1 11736.36 11300.00 1018.99 845.39 173.59 Pass: Major Risk PB OS 07 07-33 07-33APB1V5 11737.49 11300.00 1011.38 846.03 165.35 Pass: Major Risk PB OS 07 07-33 07-33APB2 V1 11736.36 11300.00 1018.99 845.39 173.59 Pass: Major Risk PB OS 07 07-33 07-33B V5 11817.81 10890.00 1278.25 856.40 421.85 Pass: Major Risk ! PB OS 15 15-11 15-11 V2 13431.97 11120.00 1374.54 901.33 473.21 Pass: Major Risk PBOS15 15-11A 15-11AV3 Out of range PB OS 15 15-11 Plan 15-11B VO Plan: 1 Out of range PB OS 15 15-38 15-38 V3 Out of range PB OS 15 15-38 15-38A V3 12156.12 13820.00 819.98 0.00 819.98 Pass: Minor 1/10 PB OS 15 15-38 15-38APB1 V3 12800.00 13290.00 1028.83 984.88 43.95 Pass: Major Risk PB OS 15 15-42 15-42 V4 13450.00 10890.00 608.89 0.00 608.89 Pass: Minor 1/10 PB OS 15 15-42 15-42A V1 13450.00 10890.00 608.89 0.00 608.89 Pass: Minor 1/10 PB OS 15 15-42 15-42PB1 V1 Out of range PB OS 15 15-42 15-42PB2 V1 Out of range L...~~ [)S~5___._ __ _~~~~_______1_~:t~~iI~_"'~______ __ ___ .__________________________<?~t Of!~\!.~______l Site: PB OS 02 Well: 02-16 Rule Assigned: NOERRORS Wellpath: 02-16 V7 Inter-Site Error: 0.00 ft Reference otrset Semi-Major Axis ~mlng MD TVD MD TVD Ref Offset TFO+AZI TFO-HS" Casing!JJS>istance . Area Deviation ft ft ft ft ft ft deg in ft ft 11002.05 8820.13 11000.00 8791.66 248.49 287.24 25.92 80.05 234.75 0.00 234.75 Pass 11009.96 8824.50 11010.00 8800.32 248.46 287.40 27.03 81.45 236.31 0.00 236.31 Pass 11017.75 8828.73 11020.00 8808.98 248.42 287.55 28.15 82.85 238.00 0.00 238.00 Pass 11024.01 8832.06 11030.00 8817.64 248.29 287.53 29.09 84.47 239.86 0.00 239.86 Pass 11029.55 8834.93 11040.00 8826.30 248.05 287.41 29.96 86.17 241.93 0.00 241.93 Pass 11034.95 8837.66 11050.00 8834.96 247.79 287.24 30.85 87.85 244.21 0.00 244.21 Pass 11040.20 8840.25 11060.00 8843.62 247.54 287.04 31.75 89.50 246.71 0.00 246.71 Pass 11045.30 8842.71 11070.00 8852.28 247.29 286.81 32.66 91.13 249.43 0.00 249.43 Pass 11050.27 8845.04 11080.00 8860.95 247.05 286.54 33.57 92.73 252.37 0.00 252.37 Pass 11055.09 8847.25 11090.00 8869.61 246.71 286.26 34.48 94.31 255.52 0.00 255.52 Pass 11059.78 8849.34 11100.00 8878.27 246.38 285.95 35.38 95.85 258.89 0.00 258.89 Pass 11063.74 8851.07 11110.00 8886.93 245.86 285.47 36.16 97.45 262.47 0.00 262.47 Pass 11067.60 8852.74 11120.00 8895.61 245.34 284.95 36.91 99.01 266.27 0.00 266.27 Pass 11071.38 8854.37 11130.00 8904.30 244.83 284.38 37.65 100.54 270.27 0.00 270.27 Pass 11075.00 8855.91 11140.00 8913.00 244.34 283.81 38.37 102.02 274.48 0.00 274.47 Pass 11078.74 8857.49 11150.00 8921.72 243.63 283.16 39.05 103.48 278.88 0.00 278.87 Pass "_N_-' ___~~._,_ All Measurements are from top of Riser 8/9/2004 ~ CD en .- cr: 02-168 top of bag .1: ~,~ , ,.'. . ÙH1f " .1 ,'n ..¡ ~-~~jI1 ~ '" L i¡ .,,,,. ~ !~.." I¡ :e : ~ 10 : l ,~ '¥ I··¡ : I.', i.' ; '~ 'II r BAG 71/16" 5000 psi. bttm of bag middle of slips Blind/Shears .......................... middle of pipes TOTs 23/8" combi ram/slips t..........·...···.····7 1/16" 5000psi ,....--. ,...--,. middle of flow cross Mud Cross Mud Cross 7 1/16" 5000psi ,--..,¡ middle of pipe/slips I variable bore pipe 3 1/2"-27/8" I I'· ........................ middle of blind/shears TOTs 23/8" combi ram/slips L..........············7 1/16" 5000psi ~r"_ "'~I -.. ~¡~ ~j,'-"~- ;;~}' .. "j i :~ -.-.j. : :.J:L It " ; -" ~~~- ~ Flow Tee 135 89-6/1252 TERRIE· LHU8BI;.E . BP EXPLO.RATIQNAK ·INC PO B.OX 1'96612. MB 7-6 ANCHORAGE, AK 9951 ~,6612 ('8-11011/ DATE 100.00 _L^RS -1Q~'~ ~~~" $ ,r:~/, . ',' (),~ Œ/ ~CC- Jry.. 71(1) . 0(1 PA'y r·O·TH E' ~'A-~..... ORDER OF~ 1"v'(J D(\Q~ ...... ... .. ..' First Na.tional Bank Alaska AnChòrage, AK 99501 . MEMO Ç)~.' toE> . e ~ 5 5 bU· I' b227 "' .:.~ 25 2000bO.:qq u. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /lð'ú 02.-/£ ß PTD# .2oLJ-/17 X Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic "CLUE"- The permit is for a new weJJbore segment of existing well, . Permit No, . API No. Production.sbould continue to be reponed as a function' of tbe original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), aU records, data and logs acquired for tbe pilot bole must be dearly differentiated ID both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). P~OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to full compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exceptioD that may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample inter:vals througb target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 _ Well Name: PRUDHOE BAY UNIT 02-16B _Program DEV _ Well bore seg 0 PTD#: 2041570 Company BP EXPLORATION (ALASKA) INC Initial ClassfType DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 0 Administration 1 P.ßcmitfee attache~ _ _ Xes - - - - - - 2 _Leasenumberap:)ropriate _ _ - - - - - - - Y.ß$_ 3 _U_nlquewellname_aod oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Y.ß$ _ _ _ _ _ - - - - - - - - - -- 4 We.llJocat.ßd ina d_efine~ppol_ _ _ Y.ß$ 5 We.llJocat.ßd proper _distance_ from driJling unitb_ound_al'Y_ _ Y.ß$ _ _ 6 We.lllocat.ßd proper _distance_ from otlJer welJs Ye$_ - - - -- 7 _S_utficient _acreage_ayailable in_drilJing unjt _ Y.ß$ 8 Jtd.ßvi<!ted, js_ weJlboJe plaUncJuded _ _ Xe$_ - - - - 9 _O.J)erator only affected party _ _ _ _ Xe$_ 10 _O.J)ecator lJas_appr9priate_b.ond lnJQrCe _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.ßs _ _ _ _ _ - - - - - - - - - -- 11 Pecmit can be issued wjtbout co_n$erva_tion order _ _ _ Y.ßs_ - - - -- Appr Date 12 P.ß(lTlit can be issued wjtlJout ac!miois.tcatÍ\!e_a.J)prpvaJ _ _ _Y.ß$ - - - - - RPC 8/16/2004 13 Can permit be approved before 15-day wait Yes . 14 We.ll located withio <!rea <!n.d_strata_authorizec! by_lojectipo Ordec # (put 10# in_c9mm.ßnts)_ (For _ _NA _ - - - - - -- 15 _AJI welJs_ witþin J l4)uile _are.a_of (eyieW ideoUfied (Fpc servjC.ß -,,>!.ell onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ - - - - - - - - - -- 16 Pre-proc!uçed injector; ~uration_of pre-.J)roduGtipo I.ßSS th<!n 3 montbs_ (For service well onJy) _ _NA 17 ACMP_ finding _of CQnsißtency_ h_as beeJl Jssued_ for_ tbis pcolect NA _ Engineering 18 _C_ol1du_ctor s.t(in.gprovided _ _ _ _NA 19 _Sm"fac.ß _casing_ pJotects alLknown. USDWs. _ _ _ _ . NA 20 _CMTvoladeQuate_to circ!Jlate_on_cooductoc& S.UJ(CJ>g _ _NA _ 21 CMT vol adeQu_ate_ to tie-in long _striog to surf C$g_ _ _ _ _NA 22 _CMT will coyeraJll<oowJlPro_d\.lGtiye lJorilOns _ _ _ Y.ßs_ - - - -- 23 C_asil1g desigl1s <!d_equa_te fpr C,_T" B_&permafr_ost _ Yes 24 AdequateJan_kage_oJ reserye pit _ - - - - - - _ _ _ _ Y.ßs _ CTDU._ _ _ _ _ __ 25 JtaJe-~cilt has a_ 10A0;3 for abandon.me_nt be.ßO ¡¡PPJoved _ _Y.ß$ * 26 A~equate-,..!ellbore.sepªratjo_n_pro.J)os.e~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.ßs _ _ _ _ _ - - - - - - - - - -- 27 Jtdjverter require.d, does it meet reguJa.tipns_ _ _ _ _ _ _ _ _ _NA Sidetcack. _ _ _ _ Appr Date 28 _DJilliog fluid_ program sc.hematic_& equip listadequate _ _ _ Y.ßs _ _ _ Max MW_8~9. ppg, WGA 8/17/2004 29 BOPE$,_dp Jhey meet reguJa.tion _ - - - - -- Xes . 30 _BOPE_pre.ss raliog <!p.J)rop(iate;Jest to_(pu_t ps.ig in_comments.) Xes _ T e.st tp _3500_ psi. 31 CMkemanjfOld complies_w/APlRI'-53 (May 84) _ _ - - - - Y.ß$ _ 32 Work will occ_ur withoutoperatio_n _shutdown_ Y.ßs_ 33 Is presence of H2S gas_ prob.able _ _ _ No Notan H2S pad. 34 MeçlJanlcaLcpoditlon 9f we.lI$ within AOR verified (fpc s_ervice welJ only) NA - Geology 35 Pecmit c_an be lssu.ed wlo hydcogen s_ulfide meas!Jres _ No_ 36 _D_ata_presfmted on :)ote_ntial pve_rpressure _zones _ . NA Appr Date 37 _S.ßismicanalysis_ Qf slJaJlow gas_zpoe.s_ . NA. RPC 8/16/2004 38 _S.ßabe~ _condjtiJ)o survey -Of Off-!¡h_ore) _ . NA - - - - - 39 _ Contact nam_elpÞOl1eJorweekly prJ)gresueport$ [ex:)loratpl'Y _oolYl NA _ Geologic Date: Engineering Date Date ~Commissioner Commissioner: JÜTs J/liJL- ~Yðr e e 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 infonnation, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. " . . C:<tJ'I-/57 Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 03 07:40:48 2004 ~ J ~<? I~ Reel Header Service name.............LISTPE Date.....................04/ll/03 Origin................... STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/03 Origin...................STS Tape Name.... ............UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOr Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-16B 500292044802 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 02-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003297732 S. LATZ R. WHITLOW / MWD RUN 5 MW0003297732 S. LATZ R. WHITLOW / MWD RUN 6 MW0003297732 S. LATZ R. WHITLOW / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW00032 977 32 S. LATZ J. EGBEJIMBA # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 llN 14E 4948 807 58.76 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.130 4.500 10922.0 # REMARKS: . . 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 2-16A WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 10950'MD AND THE BOTTOM WAS AT 10967'MD. 4. MWD RUNS 4 & 7 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 5 & 6 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO PROGRESS WAS MADE ON MWD RUNS 1 - 3. 5. DUE TO A TOOL PROBLEM, REAL-TIME SGRD DATA ARE PRESENTED FROM 12360'MD TO 13392 'MD. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN IN THE 2-16B WELLBORE ON 2 OCTOBER 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 27 OCTOBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 4 - 7 REPRESENT WELL 2-16B WITH API#: 50-029-20448-02. THIS WELL REACHED A TOTAL DEPTH(TD)OF 13685'MD/8805'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .04/11/03 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10939.0 10974.5 STOP DEPTH 13662.0 13689.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10939.0 10943.0 10950.0 10954.5 10957.5 10959.0 10961.5 GR 10939.5 10943.5 10946.5 10952.0 10957.5 10959.0 10961.0 10965.0 10967.5 10970.0 10974.5 10996.0 11003.0 11014.5 11033.5 11043.5 11045.0 11047.5 11057.0 11065.5 11071.0 11073.5 11085.5 11091.5 11097.0 11103.5 11139.0 11154.0 11178.0 11186.5 11195.5 11205.0 11211.5 11220.5 11233.5 11241.5 11250.0 11254.5 11291.5 11302.5 11310.5 11328.0 11338.5 11342.5 11345.5 11370.0 11409.5 11464.0 11472.0 11519.5 11541.5 11547.5 11557.5 11574.0 11578.0 11598.0 11611.0 11698.0 11712.0 11 721. 0 11726.5 11728.5 11757.5 11769.0 11777.5 11780.5 11791. 0 11801. 0 11809.5 11812.5 11819.5 11822.5 11831.5 11890.0 11895.5 11905.5 11909.5 11921.0 11930.0 11943.0 11948.5 11955.5 . . 10964.5 10967.0 10969.5 10973.5 10996.0 11003.0 11014.5 11032.5 11043.0 11044.5 11048.0 11057.5 11067.0 11071. 5 11073.5 11083.5 11092.0 11097.5 11102.5 11139.0 11151.5 11179.0 11187.5 11196.5 11204.0 11211.0 11220.0 11234.0 11240.0 11247.5 11252.5 11291. 0 11302.0 11312.0 11332.5 11341.5 11344.5 11346.5 11368.5 11408.0 11462.0 11469.5 11516.5 11537.5 11543.5 11555.0 11571.0 11574.0 11596.5 11609.5 11694.0 11707.5 11718.0 11723.0 11725.0 11755.0 11765.5 11774.5 11776.5 11789.5 11797.5 11808.0 11810.0 11816.0 11819.0 11828.0 11886.0 11890.0 11899.0 11905.5 11913.5 11924.5 11940.5 11946.0 11953.0 11962.5 11965.0 11969.5 11981.0 11991. 5 11996.0 12005.5 12010.0 12015.5 12020.0 12030.0 12041.5 12099.0 12106.0 12127.5 12131. 5 12137.0 12139.0 12144.5 12156.5 12162.5 12173.5 12241.0 12244.5 12251. 0 12256.0 12266.0 12294.5 12325.5 12335.5 12338.0 12339.5 12389.5 12434.0 12441. 0 12448.0 12453.0 12459.0 12469.0 12482.5 12494.0 12524.5 12532.5 12548.5 12554.0 12562.0 12589.5 12599.0 12602.5 12609.5 12618.0 12742.5 12753.0 12757.5 12765.5 12777.5 12780.5 12784.5 12787.0 12793.5 12806.5 12815.5 12818.5 12825.5 12844.0 12861.5 12919.5 12925.5 12933.0 12938.0 12946.0 13041.5 13057.0 13063.0 13088.0 . . 11960.0 11964.0 11968.0 11978.0 11989.5 11992.0 12005.5 12009.0 12016.0 12020.0 12029.5 12040.5 12097.5 12104.0 12123.5 12127.5 12133.0 12135.0 12140.0 12152.5 12159.0 12170.0 12238.5 12241. 5 12246.5 12252.0 12262.5 12292.0 12320.5 12332.0 12333.5 12336.5 12386.0 12431. 5 12439.5 12444.0 12450.0 12455.5 12465.5 12478.5 12489.5 12521. 5 12529.5 12543.0 12547.0 12554.0 12581.0 12592.5 12595.0 12599.0 12608.0 12735.5 12743.0 12750.5 12757.5 12770.5 12773.0 12776.5 12780.0 12786.5 12797.5 12808.0 12811. 5 12820.5 12839.5 12857.5 12919.5 12924.0 12931.5 12936.0 12943.5 13036.0 13051.5 13057.5 13082.5 . . 13104.0 13111. 5 13116.0 13119.5 13121.5 13123.5 13126.0 13135.5 13138.0 13146.0 13150.5 13156.0 13170.5 13173.0 13188.5 13196.5 13215.5 13228.0 13254.5 13274.0 13289.5 13300.5 13303.5 13343.0 13345.5 13362.0 13373.5 13389.0 13404.5 13432.0 13459.5 13482.5 13497.5 13505.5 13507.5 13689.0 $ 13099.0 13106.0 13110.0 13115.0 13116.5 13118.5 13121.0 13129.5 13132.0 13141.0 13144.5 13150.5 13166.5 13168.5 13186.0 13193.0 13211.5 13225.5 13251. 5 13272.5 13286.5 13294.5 13298.5 13340.0 13342.0 13363.5 13370.0 13386.0 13400.0 13430.5 13456.0 13479.5 13496.0 13502.0 13503.5 13685.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 4 5 6 7 MERGE TOP 10939.5 11428.0 11810.0 13422.0 MERGE BASE 11428.0 11810.0 13422.0 13685.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type........... .......0 Data Specification Block Type... ..0 Logging Direction.................Down Optical log depth units..... .... ..Feet Data Reference Point..............Undefined Frame Spacing..................... 60 olIN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Code Offset o 4 8 Channel 1 2 3 Name Service Order DEPT ROP MWD GR MWD Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10939 13689 12314 5501 10939 13689 ROP MWD FT/H 0.18 1065.79 77.2851 5430 10974.5 13689 GR MWD API 12.87 355.78 87.2531 5447 10939 13662 . First Reading For Entire File..........10939 Last Reading For Entire File...........13689 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .04/11/03 Maximum Physical Record..65535 Fi 1 e 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.......04/11/03 Maximum Physical Record..65535 Fi Ie Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 4 .5000 START DEPTH 10939.5 10973.5 STOP DEPTH 11400.5 11428.0 # 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 (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 25-0CT-04 Insite 4.3 Memory 11421.0 10972.0 11421. 0 51.0 90.2 TOOL NUMBER 78005 4.130 10922.0 Flo Pro 8.70 65.0 9.5 30000 6.8 .000 .000 .000 .000 .0 141.4 .0 .0 . . # NEUTRON TOOL MATRIX: MATRIX DENSITY, HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point...... ....... .Undefined Frame Spacing..................... 60 olIN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD040 MWD040 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10939.5 11428 11183.8 978 10939.5 11428 ROP MWD040 FT/H 0.46 1065.79 64.9793 910 10973.5 11428 GR MWD040 API 12.87 355.78 63.6542 923 10939.5 11400.5 First Reading For Entire File..........10939.5 Last Reading For Entire File...........l1428 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/ll/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name........ .....STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/11/03 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 3 header data for each bit run in separate files. 5 .5000 START DEPTH 11401. 0 STOP DEPTH 11779.5 . ROP $ 11428.5 11810.0 # 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 (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 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 Absent val ue. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units..................... . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 GR MWD050 Units FT FT/H API Size 4 4 4 Rep 68 68 68 Code Nsam 1 1 1 26-SEP-04 Insite 7.75 Memory 11802.0 11421.0 11802.0 84.0 93.3 TOOL NUMBER TLG009 4.130 10922.0 Flo Pro 8.60 65.0 9.4 22000 6.8 .000 .000 .000 .000 .0 150.1 .0 .0 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11401 11810 11605.5 819 11401 11810 ROP MWD050 FT/H 0.18 431. 97 42.0031 764 11428.5 11810 GR MWD050 API 53.44 158.55 94.9152 758 11401 11779.5 Offset o 4 8 Channel 1 2 3 . First Reading For Entire File..........l1401 Last Reading For Entire File...........1l810 File Trailer Service name.. ...........STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/03 Maximum Physical Record..65535 File Ty'Pe.............. ..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.......04/11/03 Maximum Physical Record..65535 File Type................ La Previous File Name...... .STSLIB.003 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR Rap $ 4 . header data for each bit run in separate files. 6 .5000 START DEPTH 11780.0 11810.5 STOP DEPTH 13392.0 13422.0 # 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 (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural garruna ray # 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 TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 26-SEP-04 Insite 7.75 Memory 13422.0 11802.0 13422.0 84.2 94.9 TOOL NUMBER TLG009 3.750 10922.0 Flo Pro 8.60 65.0 9.1 26000 6.8 .000 .000 .000 .0 167.0 .0 . . MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD060 MWD060 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11780 13422 12601 3285 11 780 13422 ROP MWD060 FT/H 0.19 620.69 90.4869 3224 11810.5 13422 GR MWD060 API 29.34 275.73 87.6973 3225 11780 13392 First Reading For Entire File..........11780 Last Reading For Entire File...........13422 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/11/03 Maximum Physical Record. .65535 File Type.. 00 00 00 00' 00' ooLO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/11/03 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: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 5 header data for each bit run in separate files. 7 .5000 START DEPTH STOP DEPTH . GR ROP 13392.5 13422.5 13658.0 13685. C' >? # 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 VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 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 olIN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD070 GR MWD070 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 01-0CT-04 Insite 4.3 Memory 13685.0 13422.0 13685.0 91. 7 101. 8 TOOL NUMBER 78005 3.750 10922.0 F10 Pro 8.60 65.0 9.5 25000 5.6 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 .0 166.0 .0 .0 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEFT FT 13392.5 13685 13538.8 586 13392.5 13685 ROP MWD070 FT/H 0.74 341. 03 68.5957 526 13422.5 13685 GR MWD070 API 39.81 226.19 113.202 532 13392.5 13658 , . . . First Reading For Entire File..........13392.5 Last Reading For Entire File...........13685 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/11/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date.................... .04/11/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/11/ 03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File