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Home My WebLink About204-087New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 XHVZE e e Image Project Well History File Cover Page 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. J QLf. - ocg 7 Well History File Identifier Organizing (done) D Two-sided ""'11111111111111 D Rescan Needed III II 111I111111I111 RE~AN VCo1or Items: o Greyscale Items: DIGITAL DATA ~kettes, NO.~ D Other, Norrype: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: C~ J D Other:: Date 7 It 71ó~ '" iliP III 1111111111111111 Date J117/oh Isl .tl1£ (p 0 + J-.I = TOTAL PAGES <6 1_ O / (Count does not include cover sheet) Date: L? Isl 11111111111111 111I1 Project Proofing BY: CMari0 Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: <ð d- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date1117/0~ If NO in stage 1, page(s) discrepancies were found: YES NO Isl V11 P NO BY: Stage 1 BY: Maria Date: /s/ ""1111111111 "III Scanning is complete at this point unless rescanning is required. ReScanned III "1/11111/1 ,,1/1 BY: Maria Date: Is/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc -~~~ STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COM SIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband~ ~,/ 9/6/2008 .U^f'' ~ 12. Permit to Drill Number 204-087 - 308-202 - 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Date Spudded 6/8/2004 13. API Number 50-029-20808-02-00 " 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/13/2004 14. Well Name and Number: PBU 06-236 4577 FNL, 1008 FEL, SEC. 02, T10N, R14E, UM Top of Productive Horizon: 2655' FNL, 102' FEL, SEC. 02, T10N, R14E, UM 8. KB (ft above MSL): 74' - Ground (ft MSL): 37.05' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2559' FNL, 883' FEL, SEC. 02, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 10318 ~ 9037, Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 685970 y- 5941299 Zone- ASP4 10. Total Depth (MD+TVD) 10353 - 9035 ~ 16. Property Designation: ADL 028311 - TPI: x- 686827 y- 5943245 Zone- ASP4 Total Depth: x- 686044 y- 5943321 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^ Yes ®No I r ni n rin i fo i r 2 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): SGRC Combined GR ~ EWR, MGR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" 1. -4 7 ' 7 ' , „ -/" 47 1 1- 4" I I ' 7" ~ „ , ~-~n° X ~~s° x zais~ e.a~~ i s.2s i ssr ~ ~ ~ a-va° x 3-~a° 23. Open to production or inject ion? ^ Yes ®No 24. TuawG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SrLE DEPTH SET MD PACKER SET MD 5-1/2", 17#, L-80 8657 8644' MD TVD MD TVD 4-1/2", 12.6#, N-80 8754' ,.. ~+y ap s+~~ ~ 25. ACID, FRACTURE, CEMENT .SQUEEZE, ETC. ~ ~ ~ ~ ~ .,, ~ . ~t DEPTH INTERVAL MD AMOUNT ~ KIND OF MATERIAL USED 9290' 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 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITV-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? Yes No Sidewal l Core s A wired? Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, 'If needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~.OJP~,ppI~LETION t-OrrTl 10-407 KeV1Sea OZ/Z007 r CONTINUED UN REVERSE SIDE C t i~(~~ G . _~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested . Yes ®No Permafrost TOp If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9039' 8536' None Zone 4B 9136' 8616' Zone 3 9364' 8823' Zone 2C 9448' 8898' Zone 26 9533' 8964' 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. `I /~ / / y ( ~ w ~/V~ / ~ _ V ( J j ~ Title Technical Assistant Date j Signed Terrie Hubble PBU 06-238 204-087 308-202 Prepared By NameMumber. Tenie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Mel RixSe, 564-5620 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, SaR Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 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). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 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. ITeM 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 25.07E Form 10-407 Revised 02/2007 Submit Original Only U 06-23B, Well History (Pre Rig Sidetrack) Date Summary 6/19/2008 WELL S/I ON ARRIVAL. RAN 4.65" G-RING. TAG 5 1/2" CA. DSSSV C«? 2071' SLM. PULLED 5 1/2" CA. DSSSV FROM 2071' SLM. (intact). RAN 4 1/2" GS. SD ~ 8657' SLM, UNABLE TO LATCH BAKER KB LTP. RAN 3.75" LIB TO 8657' SLM, IMPRESSION APPEARS TO BE SHEAR STUD ON WRP. CURRENTLY POOH W/ 2 7/8" WFD WRP PULLING TOOL. 6/20/2008 PULLED F/N ONLY FROM 2 7/8" WFD WRP C~ 8,657' SLM. TAGGED WRP C~ 8,657' SLM W/ 3.75" L.I.B. (impression of wrp core) PULLED 2 7/8" WRP AT 8657' SLM W/ BAITED OVERSHOT (5/8" grapple) See below for missing parts. RAN 3.65" CENT, 3 1/2" BRUSH TO 8659' SLM, (g-fn appears clear.) JARRED FOR --6 HOURS ON BAKER KB LTP C~3 8,659' SLM (no movement). CURRENTLY RIH W/ 4 1/2" GS TO BAKER KB LTP @ 8,659' SLM. FISH IN HOLE: FROM 2 7/8" WFD WRP: Shear stud coupling w/shear stud remnant- 0.9" OD x 3" long 1 ea. slip 1" x 2" x 1/4" Lower cone: 2.00" OD x 4 "long 5 ea. Collet fingers from main mandrel 2 1/2" x 1/4" x 1/8" 2 ea. rubber elements 6/21/2008 T/I/0=2350/1650/250 temp=S1 Assist Slick line -Load and Kill well for LT Packer pull (CTD Prep). Pumped 5 bbls neat methanol spear and 327 bbls crude down TBG for kill. Packer pulled successfully. SSL on well at departure. Notified DSO of results. FWHP's=200/1350/40 6/21/2008 PULLED 4 1/2" BAKER KB LTP FROM 8618' BLM. (intact DRIFT TO 9513' SLM (3 3/16" x 2 7/8" XO) W/ 3 3/16" BLB, 2.70" G-RING W/O ANY PROBLEMS. DRIFT TO 9,151' SLM (target 9290' md) W/ 2.70" x 20'0" DUMMY WHIPSTOCK. 6/22/2008 RAN PDS 24 ARM CALIPER FROM 9,415' SLM TO 8,298' SLM (No Data). RAN 2.70" x 11'0" DUMMY WHIPSTOCK TO 9,431' SLM (tight from 9151' slm to 9,186' slm). RE-RAN PDS 24 ARM CALIPER FROM 9,415' SLM TO 8,298' SLM (good data). RAN 2.70" x 18' 10" DMY WHIPSTOCK TO 9082' SLM. STOPPED DUE TO DEV. RAN 2.65" x 16'1" BARBELL SET-UP TO 9400' SLM. NO PROBLEMS ENCOUNTERED. WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS. 7/2/2008 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 1900/1900/25. RAN BAKER 2.63" WHIPSTOCK TO 9080' AND COULD NOT GET ANY DEEPER. TARGET DEPTH WAS 9290'. POOH W/ WHIPSTOCK. WILL RETURN AT LATER DATE TO RE-ATTEMPT. FINAL T/I/O = 1900/1900/25. WELL SHUT-IN ~ WING. SWAB AND SSV CLOSED, MASTER AND CASING VALVES OPEN. DSO NOTIFIED. JOB POSTPONED. 7/29/2008 MIRU CTU. RIH with Baker 2 1/8" motor and 2.74" String mill / 2.74" HSD Parabolic mill. Sat down dry at XO C~ 9528' ctmds PUH. PU C~ 9522' ctmd. Saw no obstruction going in. Make 4 passes up and 3 down rotating mill, saw no motor work. Drop ball and chase out of hole. Freeze protect well to 2200' with 50/50 methanol. Rig down. 7/30/2008 WELL S/I ON ARRIVAL. RU S/L UNIT. ATTEMPT TO RUN 16' x 2.70" DMY WHIPSTOCK, C«3 150 FPM. UNABLE TO PASS 8775' SLM C~ 150 FPM OR FASTER. 7/31/2008 DRIFT TBG TO 9523' SLM W/ 2.75" G-RING & 2.80" BLB. DRIFT TBG TO 9i 03' SLM W/ 2.70" DMY WHIPSTOCK. TBG VERY TIGHT FROM 8800' SLM TO 9103' SLM. UNABLE TO REACH TARGET DEPTH OF 9290'. (DRIFT= 6' x 2.70"DMY WS & 8' x 2.625" WEIGHT BAR, OAL= 16' 4") WELL S/I ON DEPARTURE, NOTIFY DSO. 8/28/2008 MIRU CTU. Initial T/I/O: 2295/2300/575. Perform partial well kill. MU and RIH with Baker whipstock drift. Drift assembly is 17.8' long. The uppermost 8.6' is comprised of a Baker #10 "J" hydraulic setting tool and setting sleeve and is 2.65" OD. The lowermost 9.2' is a monobore whipstock/packerassernbly sans slips and elements and is 2.625" OD. Drift cleanly at 60 fpm to 9450' ctmd without any weight bobbles. Pull to surface and freeze protect wellbore to 2500' TVD with 50/50 methanol/water. Communicate status of well to DSO. RDMO. Final T/I/O: 1285/1820/80. Job complete. Page 1 of 2 • • 06-236, Well History (Pre Rig Sidetrack) Date Summary 8/29/2008 T/I/0= SSV/1380/80. Temp= SI. IA FL (CTD prep). Integral on IA. No AL. IA FL C~ 2929' STA #1 DMY (129 bbls). SV,WV,SSV=C. MV=O. IA,OA=OTG. NOVP. 8/29/2008 WELL S/I ON ARRIVAL. SET 5-1/2" DSSSV IN SVN ~ 2067' SLM ((id= 2.62", oal= 70", 3 sets os pkg; lock: 4.580" no-go on db lock, id= 2.80"). LEFT WELL S/I, TURNED WELL OVER TO DSO. 8/30/2008 T/I/0= 1150/180/0 Temp= S/I Load Tbg and IA (Pre CTD). Loaded Tbg with 5 bbls Meth, 307 bbls crude. Loaded IA with 5 bbls meth, 145 bbls crude. Final WHPs 700/800/250. IA/OA casing valves open to gauges, swab shut needle valve open to gauge at time of departure. 8/30/2008 T/I/O=SSV/1350/75. Temp= SI. Bleed IAP & OAP to 0 psi (CTD prep). Integral on IA. No AL. IA FL C«~ 2929' STA #1 DMY (129 bbls). OA FL C~ 40'. Bled IAP to OT from 1350 psi to 50 psi in 5 hours. Bled OAP from 75 psi to 0 psi in 10 minutes. 30 minute monitor. IAP increased 60 psi, OAP increased 15 psi in 30 minutes. Final IA FL @ 1100'. Final WHPs= 1180/110/15. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. 8/31/2008 T/I/O=6PV/450/50. Temp=Sl. Bleed IAP & OAP to 0 psi (CTD prep). No AL. IAP increased 340 psi & OAP increased 35 psi overnight. Unable to bleed WHPs due to tie in crew pulling flowline. Intergal on IA. SV, WV=C MV, SSV=O. IA & OA=OTG. NOVP. Tie in crew on location. 8/31/2008 T/I/0=150/500/0. Set 5" ISA BPV #520 thru tree, pre Nordic. 1-2' ext used, tagged Q 96". No problems. 9/2/2008 T/I/0=0+/400/0. Puil 5" ISA BPV thru tree, due to incomplete DH work. 1-2' ext used, tagged C«~ 92". No problems. 9/3/2008 T/I/0=250/400/0. Set 5-1/8" ISA BPV #520 thru tree, pre-Nordic. 1-2' ext used, tagged C~ 92". No problems. Installed 3-1/8" CIW HWO valve to existing I/A valve. 9/3/2008 WELL S/I ON ARRIVAL. PULL 5.5" DMY SSSV W/ MIN I.D. OF 2.625" (BTM-SUB ASSYI. SET SAME 5.5" DMY SSSV W/ 2.805" BTM-SUB, DB-6 LOCK I.D.=2.781 " (BENCH DRIFT ASSY W/ 2.75" G-RING), 3 SETS O/S PACKING. RE-SET SAME DSSSV W/ 2.805" BTM-SUB, DB-6 LOCK I.D.=2.781" (BENCH DRIFT ASSY W/ 2.75" G-RING), 3 SETS O/S PACKING. SPRING ON Z-6 RUNNING TOOL IN UPPER POSITION. BLED BALANCE LINE DOWN TO 0 PSI. NOTIFY DSO LEFT WELL S/I. Page 2 of 2 BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 06-23 Common Well Name: 06-23 Spud Date: 10/1/1982 Event Name: REENTER+COMPLETE Start: 8/28/2008 End: 9/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/15/2008 Rig Name:. NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/3/2008 19:00 - 20:30 1.50 MOB P PRE Rig is parked on E pad. Will remove the 2-3/8" reel here and scope the derrick down for travel to DS6. 20:30 - 22:30 2.00 MOB P PRE Lower 2-3/8" CT reel onto truck. 22:30 - 00:00 1.50 MOB P PRE Move rig from E pad to DS6. 9/4/2008 00:00 - 09:30 9.50 MOB P PRE Continue moving rig from E pad to DS6. 09:30 - 11:00 1.50 MOB P PRE Raise derrick. 11:00 - 14:30 3.50 MOB N PRE Bleed off inner annlus from 400 psi. 14:30 - 15:00 0.50 MOB P PRE Load reel while continuing to bleed off annulus. 15:00 - 15:30 0.50 MOB P PRE Spot rig over well. Accept rig at 15:30 hours. 15:30 - 19:00 3.50 MOB P PRE N/U BOPs. Make up 1502 line inside reel, hook up J-box. 19:00 - 00:00 5.00 BOPSU P PRE Pressure test and chart BOPs. Test annular, blind /shears, 2" pipe /slip, 2-3/8" pipe /slip, lower 2" pipe /slip, HCR, kill line valves and stabbing valves. AOGCC Bob Noble has waived the test witness. 9/5/2008 00:00 - 01:10 1.17 BOPSU P PRE Continue testing BOPs. 01:10 - 02:20 1.17 RIGU P PRE Prepare to pull CT across pipe shed roof. Install stripper on injector. 02:20 - 02:30 0.17 RIGU P PRE SAFETY MEETING. Discuss hazards and crew positions for pulling CT across pipe shed. 02:30 - 03:00 0.50 RIGU P PRE Pull on CT to remove securing bar. Pull CT across pipe shed roof and into injector. 03:00 - 04:00 1.00 RIGU P PRE Cut off grapple, prepare to fill reel. Install cable boot. M/U CT riser, fill reel backwards. 04:00 - 05:45 1.75 RIGU P PRE Break off CT riser. Install hydraulic CT cutter. Cut off 50 ft of CT to find cable. Cut off another 50 ft to find a good section of pipe for CT connector. 05:45 - 07:00 1.25 RIGU P PRE Electric test of cable. Install CTC. 07:00 - 09:00 2.00 STWHIP P WEXIT PU lubricator and test to 1000+ si. Pull BPV with Iubricator.260 psi trapped pressure. 09:00 - 10:00 1.00 STWHIP P WEXIT Head up E Coil. Test CTC 3800 psi. Test inner reel valve. 10:00 - 11:00 1.00 STWHIP P WEXIT Install Ck valves in Coiltrak head. MU nozzel and stab onto well. 11:00 - 11:40 0.67 STWHIP P WEXIT Circulate one CT volume forward. 11:40 - 13:40 2.00 STWHIP P WEXIT Open well 183 psi. RIH to 9550'.X0. Bulhead 15 bb1.132bb1 in tiger. 13:40 - 14:35 0.92 STWHIP P WEXIT Shut in well 40 psi. POHIay in 2# bio holding. 150 psi. 14:35 - 15:30 0.92 STWHIP P WEXIT Shut-in 516 psi. Empty TT. RIH to 9550' 15:30 - 16:15 0.75 STWHIP P WEXIT Bull head 10 bbl final pressure 2142 psi Shut-in 648 psi. Bleed off to 500 psi returned 8.1 bbls, 16:15 - 18:25 2.17 STWHIP P WEXIT Circulate bottom up drillers method. 1.7 bpm cir pressure 1700 psi. 18:10 - At 120 bbls shut down pump, shut in well and get a strap on tiger tank - 58 bbls. Resume bottoms up circulation. 18:25 - 19:40 1.25 STWHIP P WEXIT Trouble getting 2.0 bpm, pump losing prime. Try to regain pump rate. Switch to pump#1, get back to 2.0 bpm. After 200 bbls in, circ at 2.06 / 2.08 bpm. Density 8.40 / 8.19 ppg, still gas cut. After 250 bbls in, circ at 2.06 / 2.00 bpm. Density 8.40 / 8.36 Printed: 10/7/2008 4:37:57 PM • BP EXPLORATION Page 2 of'9 Operations Summary Report Legal Well Name: 06-23 Common Well Name: 06-23 Spud Date: 10/1/1982 Event Name: REENTER+COMPLETE Start: 8/28/2008 End: 9/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/15/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/5/2008 18:25 - 19:40 1.25 STWHIP P WEXIT ppg. 300 bbls in, circ at 2.04 / 2.03 bpm. Density 8.40 / 8.38 ppg. 19:40 - 20:05 0.42 STWHIP P WEXIT Shut down pump and flow check well. Well is dead. 20:05 - 21:40 1.58 STWHIP P WEXIT Establish good circulation at 2.00 bpm then POOH. 21:40 - 21:50 0.17 STWHIP P WEXIT Tag stripper and flow check well. SAFETY MEETING. Discuss hazards and contingencies for_ well flow Burin BHA Chan e. 21:50 - 22:10 0.33 STWHIP P WEXIT Lay down nozzle + stinger. Pick up BHA#2 - 2-3/8" CoilTrack, #10J setting tool, and whipstock. 22:10 - 00:00 1.83 STWHIP P WEXIT Open EDC at surface, test tool. RIH, pump min rate through EDC. Slow down going through SSSV and GLMs. 9/6/2008 00:00 - 00:30 0.50 STWHIP P WEXIT Continue RIH with whipstock. 00:30 - 01:10 0.67 STWHIP P WEXIT Log GR down from 9,250 tt to tie in depth. Correct -11 ft. 01:10 - 01:20 0.17 STWHIP P WEXIT RIH to 9,305 ft and pick up to 9,296.1 ft to set whipstock in tension, this will leave pinch point at 9,290 ft. Up weight is 34 Klbs. Orient to 0 deg. Close EDC. Pressure up slowly, at 0.3 bpm. Ball seat shears at 3,850 psi, with 5 Klbs down on whipstock. Whiastock is set at OL orientation, with top of whipstock (top, window at 9 290 ft. 01:20 - 02:45 1.42 STWHIP P WEXIT POOH. 02:45 - 03:00 0.25 STWHIP P WEXIT PJSM for change out BHA. 03:00 - 03:40 0.67 STWHIP P WEXIT Lay down CoilTrack and #10J setting tool, minus whipstock. Looks like a normal set. Break off HOT from CoilTrack and add blind sub. Test tool at surface. 03:40 - 04:10 0.50 STWHIP P WEXIT M/U BHA #3 - 2.74" diamond string mill +string reamer, 2-1/8 BOT Xtreme motor, 2 jts 2-1/16" CSH, 2-3/8" CoilTrack with DPS, DGS, EDC. Diamond string mill and reamer both 2.73 no-go. 04:10 - 05:50 1.67 STWHIP P WEXIT RIH, pump min rate. 05:50 - 06:10 0.33 STWHIP P WEXIT Lo GR down from 9,213 ft. Correction -13.5' 06:10 - 12:50 6.67 STWHIP P WEXIT Tag WS @ 9290. 31.5K UP wt, Circulate at 1.4 bpm tag with ~k pump on. X9288.5. ~(p.23G 06:30 9288.5, 1.4 bpm @ 2245 psi FS, 2350 psi. WOB .4K ECD 8.98. 08:40 9289.9' 1.5 bpm ~ 2350 psi FS, 2560 psi WOB 1.28K, ECD 9.07 10:45 9292.17 1.5 bpm 2430 psi WOB 1.4K , ECD 9.01 11:20 9292.6 1.5 bpm 3000psi WOB -.2K Stall ~ 9292.9 mill to 9295' 12:50 - 14:20 1.50 STWHIP P WEXIT Drill rat hole to 9302' 1.5 bpm ~ 2715 psi, WOB 1.1 K, ECD 9.03, ROW 9. Ream window. Dry tag OK. 14:20 - 15:40 1.33 STWHIP P WEXIT POH. 15:40 - 16:40 1.00 STWHIP P WEXIT LD window mills.Mill gauge 2.74 Go, 2.73 No Go. PU 16:40 - 17:30 0.83 DRILL P PROD1 PU 1.2 degree bend motor build assembly. 17:30 - 19:15 1.75 DRILL P PROD1 RIH. Pnntetl: lU/7/LOUC 4:acS/ rM VFILHEAD = ~ FMC ~CTUATUR= AXELSON DRLG DRA!~ ;B. ELEV = 7a• IF. ELEV = :OP = 46ar ZO" CANDUCTOR 79' Aax Angle=97° ~ 11518' 91.5#, H-40' )alum AAD = 9426' D = 19.124" ?alum TVD = 8800' SS 13-3/8" CSG, 72#, L-8o BUTT, D = 12.347" 2525 Minimum ID =1.91" ~ 8680' 3-1/2" x 2-3/8" XO 5-117' TBG, 17#, L-80 8RD, .0232 bpf, ID = 4.897' BOT KB LTP TOP OF 2-318" LNR TOP OF3-1/2" LNR 1 2929 2929 0 MIAG DMY RK 0 07R4/OS 2 4763 4757 12 MVNG DMY RK 0 07/24/05 3 6120 6023 32 MWG DMY RK 0 05/23!04 4 7211 6914 32 MIAG DMY RK 0 10/19/82 5 7829 7450 28 MVMG DMY RK 0 10/19/82 6 7906 7519 27 MurG DMY RK 0 05!23/04 7 8244 7821 25 MNG DMY RK 0 10/19/82 8 8314 7884 24 MMG DMY RK 0 10/19/82 9 8535 8088 23 MMG DMY RK 0 OSR3/04 10 8608 8154 24 M41G OMY RK 0 10/16/07 8631' ~5-1/2" BKR PBRASSY, D=? I $644' 9-5/8" X 5-1 /2" BKR SA B PKR, ID = 4.865"? 8651' 7" BKR MLLOUT EXTENSION, D = ? 8657' 7" X 4112" XO, D = 3.958" 8~9. 86$9' 9-518" X 7" LNR TOP HGR 8693' 3.781" BKR DEPLOY SLV, D = 3.0" $699' 3-i R" STL PIN, ID = 2.990" 8713' 3-1 R" HOWCO X NP, D = 2.813" 3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.990" 14-112" TBG, 12.6#, N-80 BTC, D = 3.958" EST TOP OF CBI~ENT 9-5/8" CSG, 47#, L-80 BTGRC, ID = 8.681" PERFORATION SUMMARY REF LOG: Memory CNL 09/14/2008 A NGLE AT TOP PERF: 84° ~ 10460' 06-23A Note: Refer to Production DB for historical p ert data S¢E SPF INTERVAL Opn/Sqz DATE 1.56" 6 10,460 - 11,530' O 09/14/08 1.56' 6 11,690' -11,880' O 09!14/08 ~3-1/2"X3-3/16" XO, D = 2.786" ~ H {' 0' H TOC ' ' ' ' ' ~ PBTD 11893' 7" LNR, 29#, L-80 BTGRC..0371 bpf, D = 6.184" 9870' 9290' 3-3/16" w hipstock/KB Packer Assy 06-23C 9294' RA Tag 06-236 3-3/16" LNR, 6.2#, L-80 TG11, .0076 bpf, D = 2.80" 9528' 2-3/8"L80 ST-L,4.7#,.00194 bpf,iD=1.995" 11933' 2-7/8' LNR, 6.16#, ST-L, .0058 bpf, ID = 2.441" 10353' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 10/23/82 ROWAN 26 ORI(3 COMPLETK~f11 10/29/07 PJC DRAWNJG CORRECTIONS WELL: 06-23C 05/27/00 N4/3S SIDETRACK "A" 11/17/07 CJNIPJC SET DSSSV (11/09/07) PERMIT No: "1080920 06/16/04 NORDIC 1 CTD SIDETRACK "B" 02/19/08 JKDITLH WRP SET / PERFS API No: 50-029-20808-03 11 /10105 SGS/PJC GLV GO 0484/08 MSE PROPOSED CTD SIDETRACK SEC 2, T10N, R14E, 707 FSL 8 1010' FEL 10/16/07 TEL/PJC GLV CIO 09/15/08 Nordic 1 CTD SIDETRACK "C' 10/16!07 BSEJPJC PULL WRPlQ 865T BP Exobratbn (Abskal I SAFETY NO : IA X OA SLOW COMM ~ O ~ -~ ~ ~ 2099' 5-112" CAM BAL-O SSSV NP, D = 4.562" w / S-1 /7' CA M DSSSV (11 !09/07), ID = 2.99: • GA S LFT MANDRELS NOT OPERABLE: 06-23B (PTD #2040870) Sustained casing pressure due to TxIA Com... Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ Q /,z~/ Sent: Thursday, July 31, 2008 1:21 PM ~`~ l To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; Rixse, Mel G; Dean, James A; NSU, ADW Well Integrity Engineer; NSU, ADW WL & Completion Supervisor Subject: NOT OPERABLE: 06-23B (PTD #2040870) Sustained casing pressure due to TxIA Comm through SSSV nipple Hi all, Weil 06-236 (PTD #2040870) has known TxIA communicafion throu h the SSSV ni le and is being pre ap red for a coil tubing sidetrack. The tubing and IA were oaded to facilitate milling the XN nipple in prepara#ion for the rig. With the wellhead pressures reduced, the well has been reclassified as Not Operable. A whipstock with a permanent plug will be set in the next few days. Please let me know if you have any questions. Thank you, Anna dude, ~P. E. Well Integrity Coordina#or GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~N~~ SwA ~ ~ 20D$ From: NSU, ADW Well Integrity Engineer Sent: Sunday, July 06, 2008 1:41 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCi/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Rixse, Mel G; Dean, James A Subject: UNDER EVALUATION: 06-23B (PTD #2040870) Sustained casing pressure due to TxIA Comm through SSSV nipple Hi all, Well 06-236 has known TxIA communication through the SSSV nipple. The well is being prepared for a coil tubing sidetrack requiring the dummy SSSV and secure plug to be pulled. With the DSSSV out of hole and the well unsecured, the known TxIA communication has allowed for high IAP pressure. The wellhead pressures were tubing/IA/OA equal to SSV/2100/60 psi on 7/4/08. The well has been reclassified as Under Evaluation on a 28 day clock. The plan will be to reset the DSSSV after the well is prepared for the CTD sidetrack. Operations may allow for the IA pressure to continue to build as the IA has been test and passed to 3000 psi. The plan forward includes: 1. Slickline: Pull secure plug -DONE 2. Coil/Slickline/Eline: Prepare well for CTD sidetrack 3. Slickline: Reset DSSSV until rig is ready to move over the well A wellbore schematic and TIO plot have been included for reference. 8/29/2008 NOT OPERABLE: 06-23B (PTD #2040870) Sustained casing pressure due to TxIA Com... Page 2 of 2 • • Please call with any questions. Thank you, Anna dude, ~'.~ Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 8/29/2008 PBU 06-23B PTD 204-087 a,ooa 3,000 2,000 1,000 Ofi-23 TIC Pbt -a x1801008 4121 x1008 5/80100$ 5121 x2008 6/502008 612002008 718!2008 7x2112008 -~- Tbg f- IA -~k- OA OOA f OOOA • TREE = FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4600' Max Angle = 93 @ 10332' Datum MD = 9421' Datum TV D = 8800' SS ~ 06-23 20" CONDUCTOR - j 7Q` ~-' 91.5#, H-40' ID = 19.124" 13-318" CSG, 72#, L-80 BUTT, ID = 12,347" I-j 2525' Minimum ID = 2.387" @ 9528" 3-3116" x 2-71$" XO 5-112" CAM BAL-O SSSV NiP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2929 2929 0 MME DMY RK 0 07(24105 2 4763 4757 12 MMIG DMY RK 0 07/24/05 3 6120 6023 32 MMIG DMY RK 0 05/23/04 4 7211 6914 32 MMIG DMY RK 0 10119/82 5 7829 7450 28 MMIG DMY RK 0 10(19!82 6 7906 7519 27 MMIG DMY RK 0 05/23/04 7 8244 7821 25 MMIG DMY RK 0 10/19!82 8 8314 7884 24 MMIG DMY RK 0 10/19182 9 8535 8088 23 MMIG DMY RK 0 05!23!04 10 8608 8154 24 MMIG DMY RK 0 10/16/07 8631' -~5-112"BKRPBRASSY,ID=? 5-112" TBG, 17#, L-80 BRD, 8644' g~~ 9-518" X 5-112" BKR SAB PKR, ID = 4,865"? .0232 bpf, ID = 4.892" 8651' 7" BKR MiLLOUT EXTENSION, ID = ? 8657' 7" X 4-112" XO, ID = 3.958"1 TOP OF 7" LNR 8689' ,a. 8689° 9-5/8" X 7" LNR TOP HGR, ID = ? TOP OF 3-112" LNR $5g3' $693° 3.781" BKR DEPLOY SLV, ID = 3.0" 8699' 3-1 /2" STL PIN, ID = 2.990" 8713` 3-1/2" HOWCO X NIP, ID = 2.813" (3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.990" ', 4-1/2" TBG, 12.6#, N-80 BUTT, .0152 bpf, ID = 3.958" EST TOP OF CEMENT 9-518" CSG, 47#, L-80 BTGRC, ID = 8.681" sl 7~' I $754° I 88flfl' I PERFORATION SUMMARY REF LOG: SWS CNL 05124100 A NGLE AT TOP PERF: 46° @ 9537 ' Note: Refer to Froductian DS for histarlcal perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9537 - 9547 O 02119/08 2" 6 9600 - 9625 O 07102/05 2" 6 9655 - 9705 O 04/25/05 2" 4 10050 - 10150 E; 02/17/05 2" 6 10000 - 10310 C 06/15/04 8741' 4-112" CAMCO DB-6 NIP, ED = 3.813" {BEHIND CT LNRj 8745' 3-112" X 3-3116" XO, ID = 2.786" $755' 4-112" TUBING TAIL (BEHIND CT LNR} 8741' ELMD TT LOGGED 09!17187 (BEHIND CT LNR) 9723' 7" MARKER JOINT MILLOUT WINDOW (06-236} 9056' - 9063' ? FISH - 2-718" WRP DEBRIS {06/20108) 9528 3-3/16" X 2-718" XO, ID = 2.387" 7" LNR, 29#, L-80 BTGRC..0371 bpf. ID = 6.184" I-~ 987®' ~ 9995' - CIBP {04/25/05} 2-7/8" LNR, 6.16#, FL4S, .0058 bpf. ID = 2.441" 10636' _ PBTD 1 fl318' 3-3116" LNR, 6.2#, L-80 TG11, .0076 bpf, ID = 2.80" 9528' 2-7/$" LNR, 6,16#, L-$0 STL, .0058 bpf, ID= 2.441" 10353' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/23182 ROWAN 26 OR1G COMPLETION 10129107 PJC DRAWING CORRECTIONS 05!27100 N4t3S SIDETRACK"A" 11117!07 CJNlPJC SETDSSSV {11/09!07) 06/16104 NORDIC 1 CTD SIDETRACK "B" 02/19!08 JKD?TLH WRP SET / PERFS 11/10105 SGSIPJC GLV C/0 06(23/08 SWC/SV WRP & LTP PULLED {06121108} 10/16107 TEL/PJC GLV C!O 10/16!07 BSFJPJC PULL WRP @ 8657' PRUDHOE BAY UNIT WELL: 06-23B PERMIT No: 2040870 API No: 50-029-20808-02 SEC 2, T10N, R14E, 702' FSL & 1010' FEL BP Exploration {Alaska} • ~ ~':- .. ~,~ .- `~ SARAH PAL/N GOVERN °`~a$~ OIL ~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQA7'IO1~T CODIMISSIOIQ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rixse CT Drilling Engineer BP Exploration Alaska Inc. ~~ANNE®JUN ~ $ ~ppg PO Box 196612 _ ~J Anchorage, AK 99519-6612 a~ ~ d $ / Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-23B Sundry Number: 308-202 Dear Mr. Rixse: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Cathy P. Foerster Commissioner DATED this 1Q.~ay of June, 2008 Encl. STATE OF ALASKA -4~ ALA OtL AND GAS CONSERVATION COM ION ~, APPLICATION FOR SUNDRY APPROVAL ~~UN 6 r_ 20 AAC 25.280 ,,,-,_,,_ ^., „ ~ ~Q 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Exte sio iSSiO ~nc~or a~~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspende ell ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development' ^ Exploratory 204-087' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20808-02-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 06-23B ' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028311 ' 74' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12_ PRESENT WELL :CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10353 9035 ' 10318 , 9037 - 9570' & 9995' None asin Len th iz MD TVD Burst Colla se tr aural nd r 79' 20" 79' 79' 14 0 47 urface 2525' 13-3/8" 2525' 2525' 5380 2670 Intermediate 9016' 9-5/8" 9016' 8516' 6870 4760 Pr i n finer 823' 7" 8697' - 9520' 8235' - 8941' 8160 7020 Liner 1954' 2-7/8" 8684' - 10638' 8223' - 9004' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9537' - 10310' 8967' - 9037' 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 8754' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 8644' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O rations: June 16, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse, 564-5620 Printed Name Mel Ri se Title CT Drilling Engineer Prepared By Name/Number: Signature Phone 564-5620 Date~~^~`~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number.~o 8- aD a- Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ 17~.~'~r> ~ ~~ ~ ~~~ Subsequent Form Required: ~ i ~\ `~V APPROVED BY A roved B : ~ ~---~ COMMISSIONER THE COMMISSION Date t/ ~ v ~ ~ Form 10-403 Revised 06/2006 ORIGINAL Submit In Duplicate S SFI. ~u~ ~ ~ 2000 ' To: Tom Maunder • Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: June 4, 2008 Re: DS06-23B Perforation Abandonment and new CTD Sidetracks Sundry Approval Request Sundry approval is requested for DS 06-236. Isolation of the existing perforations with a KB style permanent packer followed by a new coil tubing drilling sidetrack is proposed. The CTD side track will target the Zone 2A sands in an offset fault block to the to the north in a Zone 2A wedge. HISTORY: Well 06-23B is a coil sidetrack that was completed in June 2004. Initial production rates were more than 50 percent lower than expected, averaging about 400 bopd. The well has experienced high GOR as a result of the low oil rate; although it is a new well the gas rate is not excessively high and seems to have plateaued. In Jul-05, DHD found a braden head leak on the casing hanger. The well was SI due to high IA and OA pressures and finally secured with a WRP ~ 8657' on Aug-05, classified as TxIAxOA. In Jul- 05 DGLV were set in stations 2 & 1, and a DSSSV was set with oversize packing. In March-06 the Braden head was repaired. In Oct-07 the well was pressure tested and passed aMIT-IA and MIT-OA, PPPOT-T to 5000 psi and PPPOT-IC to 3500 psi. The well was POP on 11/17/07 to verify the existence of IAxOA communication and based on the DART the well was re-classified as operable with IAxOA manageable by bleeds. 06-236 passed aMIT-IA to 3000 psi and passed aMIT-OA to 2000 psi in April 2008. A caliper log on 04/09/08 indicated tubing in good to fair condition, no significant areas of cross-sectional wall loss or ID restrictions are recorded. REASON FOR SUNDRY AND SIDETRACK: In Feb-08 end of life perforations shot an identified lens in the 23SB sands right above the 26N shale. The lens proved to be swept and the well does not currently add value to the field. The new CTD lateral will provide horizontal offtake in 60 acre drainage area to the north with 1000' perforations in a Z2A wedge. Pre-Rig Work: 1. O PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi 2. O MIT-OA, MIT-IA. DONE 06-Apr-08/05-Apr-08 3. O PPPOT-T & IC DONE 11-April 2008 4. S Pull BOT KB Liner Top Packer (8678' MD) 5. S Drift to 9400'MD for Baker 3-3/16" monobore whipstock set on KB packer. 6. S Calliper log 3-3/16" liner and 3-1/2" liner from 9400' to TOL ~ 8693' MD. 7. E Set Whipstock/KB packer assembly (TOWS 9290' MD) 8. O MIT-T ~ ~~ `7 9. O Function test LDS. 10. O Set BPV ~~~~ 11. O Bleed production flow lines and GL lines down to zero and blind flange 12. O Remove wellhouse, level pad, drill mouse hole. Rig Sidetrack Operations: (Sch d to begin on August 15, 2008) • 1. NU 7-1/16" CT Drilling ROPE an test to 250 psi low and 3500 psi high 2. Pull BPV. 3. Mill 2.74" window at 9290'. 4. Drill build/turn section with 3" bicenter bit, and land well. 5. Drill lateral section to 11,550' MD w/ resistivity log. 6. Run 2-3/8" solid liner w/cementralizers to TD. Place liner top at 8675' MD. 7. Cement liner from TD to 9100'MD (Base of Sag) with 15.8ppb cement. 8. Clean out liner. 9. Run MCNVGR/CCL log. 10. Test liner lap to 2000 psi. 11. Perforate per geologist. 12. Set liner top packer (if fails liner lap test) 13. Freeze protect well to 2000' with diesel. 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU st se ator, flow test well. Mel Rixse CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble WELLHEAD= FNIC ACTUATOR= AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4600' Max Angle = 33 ~ 40332' Datum MD = 9421' Datum TV D = 8800' SS ~ 06-236 20" CONDUCTOR 79' 91.5#, H-40' ~ =19.124" 13-3/8" CSG, 72#, L-80 BUTT, ID = 12.347" ~-{ 2525' Minimum ID = 2.375" ~ 8678" KB LNR TOP PKR 5-12" TBG, 17#, L-80 880, H .0232 bpf, ~ = 4.892" ~ `- OF3-1/2" LNR H 8878' OP OF T' LNR 8889' /2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.990" H 8745' 4-112" TBG, 12.8#, N-80 BUTT, 8754' .0152 bpf, ID = 3.958" EST TOP OF CEMENT $800' PERFORATION SUMMARY REF LOG: SWS CNL 05/24/00 ANGLEATTOP PERF: 46° ~ 953T Note: Refer to Production DB for h~toricai pert data S¢E SPF INTERVAL OpNSgz CATS 2" 6 9537 -9547 O 02/19/08 2" 6 9600 -9625 C 07/02/05 2" 6 9655 - 9705 C 04/25/05 2" 4 10050 - 10150 C 02/17/05 2" 6 10000 - 10310 C 06/15/04 T' LNR, 29#, L-80 BTC-RC..0371 bpf, ID = 6.184" H 9870' 2-7/8" LNR, 6.16#, FL4S, .0058 bpf, ID = 2.441" 10838' 3-3/16" LNR, 6.2t1, L-80 - SA TES: 2099' 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" w/ 5-1/2" CAM DSSSV (11/09/07), ID= 2.992" GAS LIFTMANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2929 2929 0 MMIG DMY RK 0 07124!05 2 4783 4757 12 MMIG DMY RK 0 07/24/05 3 8120 8023 32 MMIG DMY RK 0 05/23/04 4 7211 6914 32 MMIG DMY RK 0 10/19/82 5 7829 7450 28 MMIG DMY RK 0 10/19/82 6 7906 7519 27 MMIG DIM' RK 0 05/23/04 ? 6244 7821 25 MMIG DMY RK 0 10/19/82 8 8314 7884 24 MMIG DMY RK 0 10/19/82 9 8535 8088 23 MMIG DMY RK 0 05/23/04 10 8608 8154 24 MMIG DI1AY RK 0 10/167 8831' 1~5-1/2" BKR PBRASSY, ID=? 8844' 9-5/8" X 5-1/2" BKR SAB PKR, ~ = 4.865"? 8851' T' BKR M~.LOUT EXTENSION, ID = ? 8857' 7" X 4-1/2" XO, ID = 3.958" 5878' BOT K8 LTP, ~ = 2.375" 8889' 9-518" X 7" LNR TOP HGR, ID = ? 8893' 3.781" BKR DEPLOY SLV, ID = 3.0" 8899' 3-1/2" STL PMI, ~ = 2.990" 8713' 3-1/2" HOWCO X NIP, ID = 2.813" 8741' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" (BEHINDCT LNR) 8745' 3-1/2" X 3-3118" XO, ID = 2.786" 8755' 4-1/2" TUBEVG TAIL (BE}UND CT LNR) 8741' ELMD TT LOGGED 09/17/87 (BEFdND CT LNR) --C 9123' ~ MARKER JOINT MILLOUT WMIDOW (OB-238) 9056' -9063' 9528' 3-3/16" X 2-7/8" XO, ID = 2.387" 8670' 2-7/8" WRP (02/19/0 1, .0078 bpf, ID = 2.80" H 9528' DATE REV BY COAAIAEMS 108382 ROWAN Z5 OR1G COMPLETION 10/29107 PJC DRAWING CORRECTIONS 0587/00 06/15/04 N1/3S NORDIC 1 SIDETRACK"A" CTD SIDETRACK "B" 11/17/07 02/19/ CJNIPJC JKD/TLH SETDSSSV (11/09/07) WRP SET/ PERFS 11 /10105 . SGS/PJC GLV C/0 10/18/07 TEUPJC GLV C!O 10/16/07 BSE/PJC PULL WRP @ 865T HcIBP coarzS/os) 10318' PRUDHOE BAY UNIT WELL: 08-238 PERMIT No: 2040870 API No: 50-029-20808-02 SEC 2, T10N, R14E, 702' FSL & 1010' FEL ~ E~Cpioration (Alaska) 1 ~ nc~ - rtv~, vov ~ WELLHEAD= FMC ACTLWTOR= AXELSON KB. ELEV = 74' BF. ELEV = KOP = 4600' Max Angle = 33 ~ 10332' Daatum MD = 9421' Datum ND = 8800' SS O ~ ~~ ~ ~ SAF~OTES: IA X OA SLOW COMM P zoposed C TD S i3etrack 2099' S-1/2" CAM BAL-O SSSV NIP, ID = 4.562" 20"CONDUCTOR 79' w/5-1/2"CAMDSSSV(11/09l07),ID=2.992" 91.5#, H-40' ID = 19.124" O GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80 BUTT, ID = 12.347" ~~ 2525' Minimum ID = 2.375" ~ 8678" KB LNR TOP PKR 5-112" TBG, 17#, L-80 BRD, 8844' .0232 bpf, ID = 4.892" BOT KB LTP-~ 8665' TOP OF 2-3/8" LNR 8675' TOP OF 3-1 /2" LNR 8678' TOP OF T' LNR ~ $s$9' ~3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.990" I 8745' 4-1/2" TBG, 12.6#, N-80 BTC, ID = 3.958" 8754' ESTTOP OFCEMENT -~ 8800' - ~;-so- a;r..a , ID = 8.681 ° 9016' REF LOG'. SWS CNL 0524ID0 ANGLEAT TOP PERF 46' g 953T Nde: Refer to Roductwn DB fa netakN aM Gte .QE SPF MlT6NAL OPN6gz OGTE T' 6 9537 -9517 O 07/19A8 z" 6 shoo - 96zs c o7,ozos 0 6 -2 3 A 2" 6 9655 - 9705 ~ 0425105 z" ~ fooso-fofso c ozn7ios 2" 6 10000- 10710 C 06175A4 T' LNR, 29#, L-80 BTGRC..0371 bpf, ID = 6.184" -~ 9870' f 9290' 3-3/16"whipstock/KBPackerA~~. 3-3/16" LNR, 6.2#, L-80 TG11, .0076 bpf, ID = 2.80" 952E 2-7/8" LNR, 6.16#, ST-L, .0058 bpf, ID = 2.441" 10353' 06 23B ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2929 2929 0 MMIG DNI1' RK 0 07/24!05 2 4763 4757 12 MMIG DMY RK 0 07124!05 3 6120 6023 32 MMIG DMY RK 0 05/23/04 4 7211 6914 32 MMIG DMY RK 0 10/19/82 5 7829 7450 28 MMIG DMY RK 0 10/19/82 6 7906 7519 27 MMIG OMY RK 0 05/23/04 7 8244 7821 25 MMIG DMY RK 0 10/19/82 8 8314 7884 24 MMIG OMY RK 0 10/t 9/82 9 8535 8088 23 MMIG DMY RK 0 05/23/04 10 8608 8154 24 MMIG DMY RK 0 10/16/07 8631' 5-1/2" BKR PBRASSY, ID=? 8644' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.865"? 8651' 7" BKR MILLOUT EXTENSION, ID =? 8657' 7" X 4-1/2" XO, ID = 3.958" 8678' BOT KB LTP, ~~ _ ~ 375" to be retrieved 8689' - ~9-5/8" X T' LNR TOP HGR 8693' 3.781" BKR DEPLOY SLV, ID = 3.0" 8699' 3-1/2" STL PIN, ID = 2.990" 8713' 3-1/2" HOWCO X NIP, ID = 2.813" 8745' ~~ 3-1/2" X 3-3/16" XO, ID = 2.786" u1 0-0 TOC PBTD 11510' 06 23C 2-3/8" LNR, 4.7#, L-80 STL, xx bpf, ID = 1.995" ~~ 11550' DATE REV BY COMMENTS GATE REV BY COMMENTS PRUDHOE BAY UNIT 10/23!82 ROWAN 26 ORIG COMPLETION 10/29/07 PJC DRAWING CORRECTIONS WELL: 06-23C 05/27/00 N4/3S SIDETRACK "A" 11!17/07 CJWPJC SET DSSSV (11/09107) PERMIT No: 06/16!04 NORDIC 1 CTD SIDETRACK "B" 02!19/08 JKQ~TLH WRP SET / PERFS API No: 50-029-20808-03 11!10/05 SGS/PJC GLV GO 04/24/08 MSE PROPOSED CTD SIDETRACK SEC 2, T10N, R14E, 702' FSL 8 1010' FEL 10/16!07 TEUPJC GLV GO 10/16/07 BSE/PJC PULL WRP ~ 8657' BP 6cploration (Alaska) ~~ ~~' ~ STATE OF ALASKA ~°'~~~ ~~~ AL A OIL AND GAS CONSERVATION COM SIGN ~'~~ ~, ZaQ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Otlier`' ' Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver une Extensioi~t~]"~da ~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Welf 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 2oa-os7o - 3. Address: P.O. Box 196612 Stratigraphic ~~' Service 6. API Number: Anchorage, AK 99519-6612 50-029-20808-02-00 7. KB Elevation (ft): 9. Well Name and Number: 74 KB ~ PBU 06-23B - 8. Property Designation: 10. Field/Pool(s): ADLO-028311 PRUDHOE BAY Field) PRUDHOE OIL Pool 11. Present Well Condition Summary: ' Total Depth measured 10353 feet Plugs (measured) 9995 9570 true vertical 9035.06 - feet Junk (meas u red) None gg~~ t ~ G3~./6"~B910C ~~~ ~d~~ Effective Depth measured 10318 - feet true vertical 9036.88 - feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 33 -112 33 - 112 1490 470 Surface 2493 13-3/8"72# L-80 32 - 2525 32 - 2525 ,_.4930 2670 Production 8985 9-5/8" 47# L-80 31 - 9016 31 - 8516 6870 4760 Liner 67 3-1/2" 9.3# L-80 8678 - 8745 8218 - 8278 10160 10530 Liner 376 7"29# L-80 8680 - 9056 8220 - 8550 8160 7020 Liner 783 3-3/16" 6.2# L-80 8745 - 9528 8278 - 8961 Liner 825 2-7/8" 6.16# L-80 9528 - 10353 8961 - 9035 13450 13890 Perforation depth: Me asured depth: 9537 - 9547 C 9600 - 9625 C 9655 - 9705 C 10000 - 10050 C 10000 - 10100 ~ _ ~ 74 310 008 O~` ` o ~ 310 05 9 ~ ~ T h: 96 r ue Vert~ca 004 9015 9024 - 9031 9035.62 - 9034.31 9035.62 - 9034.04 ~~-n~ ~-s~c'vC,~~~~ 9035 - 9037 9034 - 9037 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 28 - 8657 4-1/2" 12.6# N-80 8657 - 8755 Packers and SSSV (type and measured depth) 5-1/2" Baker SAB Packer 8644 3-1/2" Baker KB Top Packer 8678 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Developm ent (++ Service ~` Daily Report of Well Operations X 16. Well Status after proposed work: Ojl ~' Gas ~ WAG ~' GIN) WIN) ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble ~(~~h g~~g t ,,}} 6~ Printed Name Gary Pre Title Data Management Engineer Signature . Phone 564-4944 Date 2/25/2008 Form 1 - S / ~ ` / ~ to • 06-23B • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/18/2008 *""WELL SHUT-IN UPON ARRIVAL*""` INITIAL T/I/O = 2200/1200/0 PSI SET 2-7i8" WEATHERFORD WRP CENTER ELEMENT AT 9570' PLUG LENGTH = 2.4', CE TO TOP OF PLUG 1.8'. TOP OF PLUG AT 9568.2'. FINAL T/I/O = 2300/1200/0 PSI ***JOB CONTINUED ON 19 FEB 08**" __ 2/19/2008 "**CONTINUED FROM PREVIOUS DAY""" INITIAL T/I/O = 2300/1200/0 PSI PERFORATED FROM 9537'-9547' WITH 2" POWERJET HSD GUN. USED SLB MCNL LOG DATED 15 JUNE 04 FOR TIE IN (+0' TO TIE IN LOG TO = REFERENCE LOG - SPERRY SUN MWD LOG DATED 14 JUNE 04) .FINAL T/I/O = 2300/1200/0 PSI JOB COMPLETED. ***WELL LEFT SHUT IN AND TURNED OVER TO DSO""* FLUIDS PUMPED BBLS 1 diesel 1 Total • • -,~ ~: - MICROFILMED 03/01/2008 DO NOT PLACE Nom.,, , '~ ,~~ ~"` -:~, 'y ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc 1 ~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Operator BP EXPLORATION (ALASKA) INC Permit to Drill 2040870 Well Name/No. PRUDHOE BAY UNIT 06-23B ,¡'r,/^O~i MD 10353 / TVD 9035 r'" Completion Date ~ Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: SGRC, GR &EWR, MGR, CCl, CNL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number D Current Status 1-01L J ~ '8 J--~tf APftO. 50-029-20808-02-00 UIC N Directional ~ (data taken from logs Portion of Master Well Data Maint I~ ~D fD I Name Directional Survey Directional Survey Directional Survey Directional Survey Induction/Resistivity Interval Start Stop 9630 10353 9630 10353 9000 10603 9000 10603 9072 10603 Log Log Run Scale Media No C Lis 13590 D Tap 12793 Rate of Penetration 9035 12793 LIS Verification 12792 Induction/Resistivity JÅICfJ...lnd",,.ti"~(Re5istivity L'!'b V-t~dU~, 12850 Neutron 9035 9035 9035 8502 D Tap Lis 12850 Neutron Blu 8503 Well Cores/Samples Information: . OH/ CH Received Comments 7/16/2004 IIFR IIFR 7/16/2004 PB1 IIFR 7/16/2004 PB1 IIFR Open 2/22/2006 ROP NPG EWR plus Graphics / PB 1 9072- 10603 ROP NGP EWR plus Graphics 10559 Open 10/29/2004 1 0559 Open 1 0/29/2004 1 0309 1 0/29/2004 10309 1 0/29/2004 1 0242 Case 12/23/2004 1 0236 12/23/2004 Name Interval Start Stop Received Sample Set Number Comments Sent GRlEWR4/ROP/MWD/PB 1/ GR/EWR4/ROP/MWD/PB1 I GR/EWR4/ROP/MWD GRlEWR4/ROP/MWD VERIFICATION LISTING INCLUDED COMPENSATED NEUTRON lOG MEMORY GR/CCL/CNl _~ . Permit to Drill 2040870 MD 10353 TVD 9035 ADDITIONAL INFORMATION Well Cored? Y® Chips Received? 'N-ttI- Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. PRUDHOE BAY UNIT 06-23B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20808-02-00 UIC N Comments: Completion Date 6/6/2004 Completion Status 1-01L Current Status 1-01L Compliance Reviewed By: Daily History Received? ;QN ~N Formation Tops ~ Date: o1.._?J~~ ýJ . . . . 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 / 3590 RE: MWD Formation Evaluation Logs 06-23B + PB1, 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 06-23B + PB1: LAS Data & Digital Log Images: 50-029-20808-02, 70 :jD4~D81 1 CD Rom '. 0.,. N' 10.1'- ("\ ;,L-:'\, :'ft:.w G 0 Ii ê;ol~~;U0 9--1 ~i(j-I ùu RJ:.l.a:: t V 1::. U . STATE OF ALASKA a AUG 1 8 2005 ALA _ Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATION$laska Oil & Gas CfjlH~. CQmmission 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D Other [ßjJ!;nmage Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Opera!. Shutdown D Perforate 0 Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: ~q:rrent RI ExpIcral:ay D 204-0870 3. Address: P.O. Box 196612 Stratiga::hc ~ce 6. API Number: Anchorage, AK 99519-6612 50-029-20808-02-00 7. KB Elevation (ft): 9. Well Name and Number: , .... " 8. Property Designation: 74 KB ADL-028311 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Liner Production Liner Liner Liner Perforation depth: measured 10353 true vertical 9035.06 measured 10318 true vertical 9036.88 Length 79 2493 67 8985 376 783 825 Size 20" 91.5# H-40 13-3/8" 72# L-80 3-1/2" 9.3# L-80 9-5/8" 47# L-80 7" 29# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 Measured depth: 9600 - 9625 True Vertical depth: 9004.28 - 9014.97 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): feet feet feet feet MD 33 - 112 32 - 2525 8678 - 8745 31 - 9016 8680 - 9056 8745 - 9528 9528 - 10353 9655 - 9705 9024.39 - 9030.79 06-23B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) TVD 33 - 112 32 - 2525 8217.7 - 8278.05 31 - 8515.84 8219.51 - 8550.31 8278.05 - 8960.79 8960.79 - 9035.06 5-1/2" 17# L-80 4-1/2" 12.6# N-80 5-1/2" Baker SAB Packer 3-1/2" Baker KB Top Packer Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl 147 56 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Sign~ Form 1 - 9995 None Burst Collapse 1490 470 4930 2670 10160 10530 6870 4760 8160 7020 13450 13890 28 - 8657 8657 - 8755 8644 8678 RBDMS BFl AUG 192005 Tubing pressure 712 1374 ~ce V\ŒPL D Title Data Mgmt Engr Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 11830 5 400 4267 2 500 15. Well Class after proposed work: ExpIaatay ~cp I B1I: RI 16. Well Status after proposed work: 01 RI <?as D W/\G D Date 8/15/2005 S .. . . IW~Ç~11.!fy;p~T·ËI >i¡¡j~tÆft~;';;. ;T-.~~~~~y .'~.;;;-1~iffi12:_~t~!~0_ 7/2/2005 PERFORATED 9600'-9625' WITH 2" HSD 6SPF 60 DEG PHASED PJ2006 CHARGES. TIED INTO SLB MEMORY CNL LOG DATED 15-JUNE-2004. TOOL STOPPED DUE TO DOG LEG AT 9600', ABLE TO SHOOT AT STOP DEPTH. 7/8/2005 T/IIO = 1660/1640/460. Temp = Hot. TIFL PASSED. (DSO call-in high lAP & OAP 7/5/05). Well flowing. OA pressure didn't require bleeding. Shut in wing to stack out TBG. Stacked out at 2460 psi. IA FL @ 5167'. Bled IA for 30 minutes. IA psi dropped to 1020 and tubing remained at 2460 psi. IA FL remained at 5167'. Monitored for 1 hour, IA FL no change. Final WHP's = T/I/O= 2460/1020/270. REeE/~:-- . STATE OF ALASKA .. p".., .~t!ð ALASKA OIL AND GAS CONSERVATION cof'BSSI<ìtJ At Rf 1t 2óu{j REPORT OF SUNDRY WELL OPERATfbtJJ9',CofJ"Co rage Stimulate 0 OtherD WaiverD Time ExtensionD Re-enter Suspended WellD Total Depth measured 10353 feet true vertical 9035.1 feet Effective Depth measured 10318 feet true vertical 9036.9 feet ~~ 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (It): 74.00 8. Property Designation: ADL-028311 11. Present Well Condition Summary: Casing Conductor Liner Li ner Liner Liner Production Surface Perforation depth: Length 79 376 67 783 825 8985 2493 Repair WellD Pull Tubing 0 Operation Shutdown 0 Pluq PerforationsD Perforate New Pool D Perforate [K] 4. Current Well Class: Development 00 5. Permit to Drill Number: 204-0870 6. API Numbe 50-029-20808-02-00 Exploratory D StratigraphicD ServiceD 9. Well Name and Number: 06-23B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Plugs (measured) None Junk (measured) None Size 20" 91.5# H-40 7" 29# L-80 3-1/2" 9.3# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 33 112 33.0 112.0 1490 470 8680 - 9056 8219.5 - 8550.3 8160 7020 8678 - 8745 8217.7 - 8278.1 10160 10530 8745 - 9528 8278.1 - 8960.8 9528 - 10353 8960.8 - 9035.1 13450 13890 31 - 9016 31.0 - 8515.8 6870 4760 32 - 2525 32.0 - 2525.0 4930 2670 Measured depth: 10000 -10050,10050 - 10075, 10075 -10100,10100 - 10150, 10150 -10310 True vertical depth: 9035.62 - 9034.31, 9034.31 - 9033.98, 9033.98 - 9034.04, 9034.04 - 9034.33, 9034.33 - 9037.07 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 5-1/2" 17# L-80 4-1/2" 12.6# N-80 @ 28 @ 8657 8657 8755 3-1/2" Baker KB Top Packer 5-1/2" Baker SAB Packer @ 8678 @ 8644 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ßc. 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ Signature Form 1 0-404 Revised 4/2004 Oil-Bbl 249 241 Representative Dailv Averaae Production or Iniection Data Gas-Met Waler-Bbl Casing Pressure 18.8 26 650 21.5 0 1200 Tubing Pressure 836 865 ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A DevelopmentOO Service D Title Production Technical Assistant 564-4657 Date 4/13/05 . . 06-238 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/16/05 Perforate 10100'-10150' 4 SPF 02/17/05 Perforate 10050'-10075' 4 SPF FLUIDS PUMPED BBLS 174 60/40 Methonal 260 1 % KCL 434 TOTAL Page 1 T.REE:; . . WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = FMC GEN 3 FMC AXELSON 74' . 06-238 I SdTES: 4600' 93 @ 10332' 9421' 8800'SS . 2099' 13-318" CSG, 72#, L-80, ID = 12.347" I ST MD 1VD 1 2929 2929 2 4763 4757 3 6120 6023 4 7211 6914 5 7829 7450 6 7906 7518 7 8243 7820 8 8312 7882 9 8535 8087 10 8607 8153 Minimum ID = 2.375" @ 8678" KB LNR TOP PKR 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I 8657' 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.990" 8754' 8745' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8741' ÆRFORA TION SUMMA RY REF LOG: SWS CNL OS/24/00 ANGLEATTOPÆRF: 90 @ 10000' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 10000 - 10310 0 06/15/04 2" 4 10050 - 10150 0 02/17/05 -15-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" GAS LIFT MANDRELS DEV TYPE VLV LATCH o MMIG DOME RK 12 MMIG SO RK 32 MMIG DMY RK 32 MMIG DMY RK 28 MMIG DMY RK 27 MMIG DMY RK 25 MMIG DMY RK 24 MMIG DMY RK 23 MMIG DMY RK 24 MMIG DMY RK PORT DATE 16 06/21/04 20 06/21/04 o OS/23/04 o o o OS/23/04 o o o OS/23/04 o 5-1/2" BAKER PBR ASSY I 9-5/8" X 5-1/2" BAKER SAB A<R I 5-1/2" X 4-1/2" XO I KB LNR TOP A<R, ID = 2.375" 3.781" BKR DEPlOYMENT SLV, ID = 3.0" 3-1/2" HES X NIP, ID = 2.813" I 4-1/2" CAMCO DB-6 NIP, ID = 3.813" (BEHIND CT LNR) 3-1/2" X 3-3/16" XO, ID = 2.80" I 4-1/2" TUBING TAIL (BEHIND CT LNR) MILLOUT WINDOW 9056' - 9063' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 9870' 12-7/8" LNR, 6.5#, L-80, .0058 bpf,ID=2,441" I 10636' 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2,441" H DATE 10/22/82 OS/24/00 06/15/04 06/21/04 03/02/05 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION KAK CTD SIDETRACK (06-23B) GJB/KAK GLV C/O JLG/TLH ADÆRF (02/17/05) DATE REV BY COMMENTS 3-3/16" X 2-718" XO, ID = 2,440" I PRUDHOE BAY UNIT WELL: 06-23B ÆRMIT No: 2040870 API No: 50-029-20808-02 SEC 2, T10N, R14E, 4325.36' FEL & 2175.84' FNL BP Exploration (Alaska) . . cX& i-tJ~7 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 28, 2004 RE: MWD Formation Evaluation Logs: 06-23B, AK-MW-3112076 1 LDWG formatted Disc with verification listing. AùPI#: 50-029-20808-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-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 . . ~f)1--og T WELL WG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 28, 2004 RE: MWD Formation Evaluation Logs: 06-23B PB 1, AK-MW-3112076 1 LDWG formatted Disc with verification listing. API#: ?r-'f09 20808-70 , vz,,,.~ 101 Ð1.. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION 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-#! . STATE OF ALASKA . ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: !HI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 !HI Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/16/2004 204-087 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/8/2004 50- 029-20808-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 6/13/2004 PBU 06-23B 4577' SNL, 1008' WEL, SEC. 02, T10N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2655' SNL, 102' WEL, SEC. 02, T10N, R14E, UM 74' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2559' SNL, 883' WEL, SEC. 02, nON, R14E, UM 10318 + 9037 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 685970 y- 5941299 Zone- ASP4 10353 + 9035 Ft ADL 028311 TPI: x- 686827 y- 5943245 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 686044 y- 5943321 Zone- ASP4 (Nipple) 2099' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey !HI Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL 22. CASING, liNER AND CEMENTING RECORD i~~f1~G > ::5FTTIN§ ;J~McJ 5E1'T1NG 1I;ì"'!'tiT\ID ~fi~ ..» . '~;:-~" Wr.........-- ··.··.···GRAPe:.··. JOÞ tjOTTOM I:$OTTQM >i ,'i· 1""1::1'<1"'1" lOP 20" 91.5# H-40 Surface 79' Surface 79' 30" 1990# Poleset 13-3/8" 72# L-80 Surface 2525' Surface 2525' 17-1/2" 2400 sx Fondu, 400 sx PF 'C' 9-5/8" 47# L-80 / S0095 Surface 9016' Surface 8516' 12-1/4" 500 sx Class 'G', 50 Bbls PF 'C' 7" 29# L-80 8697' 9056' 8235' 8550' 8-1/2" 325 sx Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# / 6.2# / 6.5# L-80 8678' 10353' 8218' 9035' 4-1/4" x 3-314" 102 sx Class 'G' 23. Perforations op'en to Production (MD + TVD of Top and 24.. - ...... i.' i.' Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 5-1/2", 17#, L-80 8657' 8644' MD TVD MD TVD 4-1/2", 12.6#, N-80 8754' 10000' - 10310' 9036' - 9037' 25' .J~ç¡b,·"'··· CËMËt-.I,.",· ",,;"¡Í,>. i.i..i.... .,'.,'. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 22, 2004 Flowing Date of Test Hours Tested PROPUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO 7/1/2004 6 TEST PERIOD -+ 137 4,679 3 82.73 34,170 Flow Tubing Casing Pressure CALCULATED -+ Oll-Bsl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) Press. 333 400 24-HoUR RATE 548 18,716 13 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 emr,'.::! ¡ON ()~'G\NAL ~~T~.. ~ - j, Ii'"'l"//' 'Y/ ,~T Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~' ~ç G 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9039' 8536' None Zone 48 9136' 8616' Zone 3 9364' 8823' Zone 2C 9448' 8898' Zone 28 9533' 8964' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 0 Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: Thomas McCarty, 564-4378 P8U 06-238 Well Number 204-087 Permit No. / A roval 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 fonm 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 fonm 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 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/5/2004 04:30 - 04:45 0.25 MOB P PRE Rig released from 02-06B @ 04:30Hrs on 6/5/2004. Prep to move rig off well. 04:45 - 05:00 0.25 MOB P PRE PJSM for moving rig off well. 05:00 - 06:30 1.50 MOB P PRE Pull rig off well. Clean up location. 06:30 - 07:00 0.50 MOB P PRE Held pre-move safety meeting. 07:00 - 14:00 7.00 MOB P PRE Move rig from 02-06B to 06-23. Conduct pre-operations pad inspection. 14:00 - 14:30 0.50 MOB P PRE Lay 8 matting boards & 2 composite boards in front of 06-23 well. Check WHP - Opsi with a closed SSV. 14:30 - 14:45 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for backing rig over well. 14:45 - 15:00 0.25 MOB P PRE Back rig over well & set down. ACCEPT RIG @ 15:00 HRS ON 06/05/2004. 15:00 - 17:30 2.50 RIGU P PRE PJSM with Peak crew on CT reel swap. P/U & lower reel to Peak double drop trailer. Replace reel drive bushing & bolts. Off Critical Path Operations: - N/U BOPE, grease tree valves & open up SSV. 17:30 - 00:00 6.50 BOPSU P PRE Perform initial BOPE function/pressure test. AOGCC test witness waived by John Crisp. Off Critical Path Operations: - Spot trailers & tanks & continue replacing reel drive bolts. - Swap seats and valves on SPM pump. 6/6/2004 00:00 - 02:00 2.00 RIGU P PRE Continue to spot reel Slip and cut drilling line. 02:00 - 04:45 2.75 RIGU P PRE Connect and test coil/wire rope connection. Spool coil to injector head. 04:45 - 07:00 2.25 FISH P DECOMP RU and test Baker coil connector. - Pull 30k Pump coil volume. Pressure test coil connector to 3500 psi. Pressure test hardlines to 3500 psi. Install dart catcher. Load wiper dart. Launch & chase with 2% KCL. Dart hit @ 57.8bbls. PT CTC to 3500 psi. 07:00 - 07:30 0.50 FISH P DECOMP Open up well & observe 200psi WHP. Attempt to bleed off to tiger tank - observe 2ndary 3" line to tiger tank on choke manifold plugged. Bleed off well to tiger tank thru primary line via MM out. Flow check well for 30m ins - stable. Meanwhile held pre-operations safety meeting. Reviewed well plan, potential hazards (H2S monitoring/response) & fishing BHA M/U procedures. 07:30 - 08:15 0.75 FISH P DECOMP M/U liner retrieval BHA # 1 with Baker 4" GS spear, up/down jar, 1 jt of PH6 tbg & MHA (OAL - 45.45'). Stab injector on well. 08:15 - 10:00 1.75 FISH N SFAL DECOMP Break open & attempt to unplug 3" line to tiger tank on choke manifold - plugged up with hard cmt. Review situation with ANC team. Decide to fix plugged line during summer shut-down after this well. Should still be able to operate with only one primary downstream line to tigger tank. Tag out plugged choke manifold line. 10:00 - 11 :40 1.67 FISH P DECOMP RIH with BHA #1 to 8600' taking FP contaminant fluid to tigger tank. Up wt check = 33k, Down Wt = 19k. Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N1 Spud Date: 10/1/1982 End: 6/6/2004 11 :40 - 13:50 2.17 FISH P DECOMP Circulate out gassy FP contaminant fluid @ 2.0bpm & 1400psi. 13:50 - 14:00 0.17 FISH P DECOMP Continue RIH BHA#1 to TOF tagged @ 8698'. Flag CT (EOP @ 8652.9'). 14:00 - 14:10 0.17 FISH P DECOMP P/U & confirm liner engagement with 36k up wt. 14:10 - 16:05 1.92 FISH P DECOMP POOH with liner fish pumping across the wellhead with 70psi WHP. 16:05 - 17:00 0.92 FISH P DECOMP OOH. Flowcheck well - stable. PJSM. SIB injector. LID BHA #1 & recovered 100% of cut liner assembly consisting of BKR deploy sub, X/O & 14.5 jts of 2-7/8" FL4S tbg. NORM tested recovered pipe - OK with max reading of 1-2 microRem/hr. 17:00 - 17:15 0.25 CLEAN P DECOMP Held PJSM & HNHM for M/U under-reaming BHA#2. 17:15 - 17:50 0.58 CLEAN P DECOMP M/U under-reaming BHA #2 with 3-5/8" DB under-reamer, Baker mud motor, 1 jt of PH6 tbg & MHA (OAL - 54.26'). Stab injector on well. 17:50 - 20:00 2.17 CLEAN P DECOMP RIH to 8800' MD with under-reaming BHA #2 without pumping. - Correct depth -10' (-1' for EOP flag, -9' for tag). 20:00 - 21 :00 1.00 CLEAN P DECOMP Ream with 7" underreamer to 9100 MD at 2.8 bpm/2.85 bpm; 2500 psi. - Open underreamer. - 19k SO / 33k PU. - Pump 15 bbls biozan pill. - Underreamer opens to 6.101", ID of 29# 7" is 6.184". - Stacking up at every collar (averaging 38' joints): 8844', 8882',8920',8960',8998',9038', and 9077' MD. - Reaming at 18 fpm, slowing down before collars. - Minimizing stackup to 6k. POOH to 8700' MD, pumping 2.8/2.88 bpm; 2300 psi. No sign of collars. - Shut pumps off and ensure entry into tubing tail. 21 :00 - 22:15 1.25 CLEAN P DECOMP Ream with 7" underreamer to 9100 MD at 2.8 bpm/2.85 bpm; 2500 psi. - Open underreamer. - 19k SO / 33k PU. - Pump remaining 15 bbls biozan pill. - Confirmed collar location at 8844' and 8882' MD. - Reaming at 18 fpm, slowing down to get past collars to minimize potential tool damage. - Drop 3/4" ball to open circ sub (50.1 bbls). 22:15 - 00:00 1.75 CLEAN P DECOMP Pump OOH at 3.0 / 2.65 bpm, 200 psi. LD BHA. 6/7/2004 00:00 - 01 :00 1.00 EVAL P WEXIT PJSM. RU slickline sheaves and equipment. Pickup PDS Caliper logging tools. 01 :00 - 01 :45 0.75 EVAL P WEXIT RIH to 9100' SLM. 01 :45 - 02:45 1.00 EVAL P WEXIT POOH with Caliper log. Logging out of the hole from 9100 to 8600' SLM. 02:45 - 04:00 1.25 EVAL P WEXIT Lay down tools. Download data. Rig down slickline. 04:00 - 06:30 2.50 WHIP P WEXIT PJSM. Rig up E-line sheaves and equipment. Verify POS and CCL tools Insert RA tags into whipstock. RA PIP tag to TOWS = 10'. Printed: 6/22/2004 10:14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/7/2004 04:00 - 06:30 2.50 WHIP P WEXIT Calibrate POS tool to HS & orient whipstock 20degs LOHS. Pick up weight bar, POS, CCL and whipstock BHA. CCL to TOWS = 17.3'. 06:30 - 07:45 1.25 WHIP P WEXIT RIH with HD- swivel, POS tool, wt bar, setting tool, & Baker Gen II 4-1/2" x 7" whipstock (OAL - 40'). RIH to @ 9090' ELM. 07:45 - 08:00 0.25 WHIP P WEXIT P/U wt @ 9100' = 2.8k. Log up hole to 8670' ELM. Tie-into SWS Jewelry Log 2/8/2000. Subtract 6' from ELMD. RBIH to 9100' ELM. Log back up to CCL depth of 9032.7' (TOWS @ 9050' ELM). 08:00 - 08:20 0.33 WHIP P WEXIT Set W/S with good wt loss indication & tray orientation of 2.2degs LOHS. Log off, tag W/S, log off again & confirmed W/S setting depth. 08:20 - 09:15 0.92 WHIP P WEXIT POOH Eline & W/S setting tools. 09:15 - 09:30 0.25 WHIP P WEXIT L/O SWS Eline tools & RID SWS. 09:30 - 10:00 0.50 STWHIP P WEXIT M/U slick cementing BHA with nozzle, PH6 stinger X/over to circ sub & disconnect. M/U injector. 10:00 - 11 :40 1.67 STWHIP P WEXIT RIH with cementing BHA#3 to 8800'. PUH clean into TT. Continue RIH & lightly tag WS pinch pt @ 9070'. P/U to up wt & correct CTD to the ELMD of 9055ft. P/U 10' to 9045' & flag pipe. 11 :40 - 12:00 0.33 STWHIP P WEXIT RU SLB Cementers & prime up. 12:00 - 12:15 0.25 STWHIP P WEXIT PJSM with all personnel concerning cementing operations. 12:15 - 13:15 1.00 STWHIP P WEXIT Flush/PT lines to 4k. Mix & pump 10bbls 15.8ppg class 'G' cmt slurry & 5bbls of water behind @ 2.0/2.0bpm & 1600psi. Chase with bio-KCL water @ 2.85/2.85bpm & 2450psi. Pump out 1 bbl of cmt past nozzle & lay-in 9bbls of cmt 1:1 to TOC @ 8770'. 13:15 - 13:30 0.25 STWHIP P WEXIT POOH to safety @ 8200' 13:30 - 14:00 0.50 STWHIP P WEXIT Shut-in well with 100psi WHP & W.O.C. to swap out. 14:00 - 14:30 0.50 STWHIP P WEXIT RBIH @ 50fpm circ @ 2.95/2.95bpm & 1550psi jetting down to 9045'. Make 2 more up/down passes washing tbg profiles. 14:30 - 16:40 2.17 STWHIP P WEXIT POOH jetting uphole chasing contaminated cement OOH & washing tbg profiles @ 2.9bpm. 16:40 - 17:00 0.33 STWHIP P WEXIT OOH. LID Cement nozzle BHA. 17:00 - 17:15 0.25 STWHIP P WEXIT M/U swizzle stick & jet BOP stack. UO swizzle stick & SIB injector. Flush choke manifold lines. 17:15 - 17:35 0.33 STWHIP P WEXIT M/U window milling BHA #4 with a 3.80" HC DWM, diamond string reamer, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg. M/U injector. 17:35 - 19:30 1.92 STWHIP P WEXIT RIH with BHA #4. - Tag pinch point at 9054.5'. (included -10' depth correction) 19:30 - 00:00 4.50 STWHIP P WEXIT Mill window. TOW at 9054.5' MD. - Flag EOP at 8970' MD. - 36k PU / 20k SO - Pump 100 bbls 2ppb Biozan. - 1750 psi free spin. - 2.72 / 2.88 bpm. - Milling pressure at 1950 psi with 1-3k WOB - Ditch magnets at shaker. 6/8/2004 00:00 - 00:45 0.75 STWHIP P WEXIT Mill through window at 9061.8' MD into open hole to 9072' MD. - 2.66/2.78 bpm. - 1400 psi free spin. - Milling pressure at 1550 psi with 1-3k WOB - Ditch magnets at shaker. Printed; 6/22/2004 10;14;30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/8/2004 00:00 - 00:45 0.75 STWHIP P WEXIT EOP flag at 8970' TOWS at 9050' MD TOW at 9054.4' MD BOW at 9061.8' MD 00:45 - 02:20 1.58 STWHIP P WEXIT Backream window. Shut down pumps and run through window. Tag bottom. Repeat backream through window. - Window in good condition. - Swap well over to Flo Pro drilliing fluid. 02:20 - 04:15 1.92 STWHIP P WEXIT POOH with milling BHA at 110 fpm. - 2400 psi - 2.8 / 2.7 bpm - 33k PU - Replacing injector pins as needed. 04:15 - 05:00 0.75 STWHIP P WEXIT LD BHA #4. - Mill wear to 3.76 no-go (3.77 go). - Reamer showed minimal wear. 05:00 - 05: 15 0.25 DRILL P PROD1 Held PJSM. Reviewed drilling BHA M/U procedures. 05:15 - 06:15 1.00 DRILL P PROD1 Rehead & M/U DS CTC. Pull & pressure test. M/U build section BHA #5 with new HYC DS1 003-3/4" x 4-1/4" bicenter bit, 1.69deg bend motor, MWD & orienter. M/U injector. 06:15 - 08:15 2.00 DRILL P PROD1 RIH with BHA #5. SHT MWD & orienter - OK. RIH to flag. Correct CTD by -14'. Run thru window with pumps down. RIH circ @ min rate & tag btm @ 9072'. Check TF - @ 60L. Establish freespin @ 2.6bpm/3400psi. P/U WI = 32k, S/O WI = 19k. PVT = 335bbls. lAP = 31psi, OAP = 88psi. 08:15 - 12:45 4.50 DRILL P PROD1 Commence driling build section. Drill to 9135' with 45-60L TF, 2.6/2.6bpm, 3200/3500psi, 3k WOB & 15fph ave ROP. 12:45 - 12:50 0.08 DRILL P PROD1 PUH to 9095' for tie-in log. 12:50 - 13:15 0.42 DRILL P PROD1 Log up GR & tie-in RA Pip tag into the Geology PDC log - add l' to PI P tag depth. Revised window depths are: TOWS = 9051' TOW = 9056' RA PIP Tag = 9061'. BOW = 9063' BOWS = 9069'. 13:15 - 13:25 0.17 DRILL P PROD1 Orient TF to 140L. 13:25-15:10 1.75 DRILL P PROD1 Drill to 9200' with 140-160L TF, 2.6/2.6bpm, 3300/3600psi, 2k WOB & 60fph ave ROP. 15:10 - 16:50 1.67 DRILL P PROD1 Drilling 159L TF at 70 fph. Q = 2.67/2.83bpm & P = 3250/3596 psi. Oriented 2 click twice 16:50 - 17:20 0.50 DRILL P PROD1 Drilling 97L TF at 70 fph. Q = 2.57/2.783 bpm & P = 3250/3596 psi. Oriented 2 click twice 17:20 - 17:35 0.25 DRILL P PROD1 Wiper trip tp window. 17:35 - 17:40 0.08 DRILL P PROD1 RIH and tagged bottom, Oriented TF to 60 L 17:40 - 18:20 0.67 DRILL P PROD1 Drilling 63L TF at 80 fph. ROP @ 89 tto 45 fph. Q = 2.68/2.83 bpm & P = 3250/3757 psi. oriented TF perodically to adjust to plan curve. Getting close to Z3 18:20 - 18:43 0.38 DRILL P PROD1 Drilled at 45L and hole angle BR are high 18:43 - 19:14 0.52 DRILL P PROD1 Orient TF around to reduce BR's Printed: 6/22/2004 10: 14:30 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/8/2004 19:14 - 19:41 0.45 DRILL P PROD1 Drilling at 103L Q= 2.65/2.81 bpm. Vp = 331 bbl; Pp 3250/3525 psi; ROP 30 to 40 fph Adjust TF to keep it at 90L 19:41 - 22:16 2.58 DRILL P PROD1 Drilling at 103L to 45L Q= 2.65/2.81 bpm. Vp = 331 bbl; Pp 3250/3525 psi; ROP 30 to 40 fph Adjust TF to keep it at 90L. Z-3 drill at 9373 ft 22:16 - 23:00 0.73 DRILL P PROD1 Drilling Z-III at 30L to 45L Q= 2.65/2.84 bpm. Vp = 3211 bbl; Pp 3250/3468 psi; ROP 20 to 35 fph 23:00 - 23:33 0.55 DRILL P PROD1 Wiper trip to window after drilling 150ft, Clean 23:33 - 00:00 0.45 DRILL P PROD1 Drilling with 18L TF Q = 2.6/2.78 bpm, P = 3200/3450psi. Close to being out Z-3 Drilled through Z3/Z2 transition. ROP increased to 80 fph. 6/9/2004 00:00 - 00:49 0.82 DRILL P PROD1 Drilling at 7L TF in Z-II , Vp = 317 bbl. ROP = 120 fph; Q= 2.61/2.77 bpm; P 3275/ 3830 psi. Oriented to HS at 9487 ft. Need 19 to 20 deg /100' BR to land Getting BR at <15 deg/100 00:49 - 02:30 1.68 DRILL P PROD1 POOH for Bit and bend change Note: Inspect and change out some carter pin on injector head chains 02:30 - 03:20 0.83 DRILL P PROD1 BHA Handling, changed out bit and orienter. Set motor bend at 2.00 deg. Offset @ 77.5 deg 03:20 - 06:00 2.67 DRILL P PROD1 RIH. Tag up on window. Check TF, 160L. Orient to 30L. Tag window. Orient to 6L. Run through window to 9,110'. Correct -10' based on tagging window. Log up from 9,100' to 9,081' to tie in to RA marker, -3' correction. RIH. Tag bottom at 9,531 '. Orient to 40L. 06:00 - 09:00 3.00 DRILL P PROD1 Drill from 9,531' to 9,700'. 09:00 - 10:15 1.25 DRILL P PROD1 Wiper trip to window. 10:15 - 10:55 0.67 DRILL P PROD1 Orient to 60L. 10:55 - 13:50 2.92 DRILL P PROD1 Drill at 2.6/2.6 bpm 3,150/3,550 psi. ROP 40-50 fph. Continue building angle and looking for 22N marker and HOT (26N marker not present). Drilled through 22N which came in 13' high to prog. Build angle to 89 deg. No HOT in 9,750' sample. Discuss with Anc. geo and decide to trip for lateral BHA. Target sand will be below the 22N and above the MHO, prognosed at 8,980'. 13:50 - 15:10 1.33 DRILL P PROD1 Wiper trip to window and CBU sample. No MHO or HOT in 9,778' sample. 15:10 - 17:00 1.83 DRILL P PROD1 POOH. 17:00 - 18:30 1.50 DRILL P PROD1 Change motor bend to 1.04 deg. Break bit. Grade 3-3-BT-A-X-NA-WT -BHA. 18:30 - 20:18 1.80 DRILL P PROD1 RIH 20: 18 - 20:45 0.45 DRILL P PROD1 Tie-in to RA Marker (-4 ft correction) 20:45-21:16 0.52 DRILL P PROD1 MAD pass with Res tool while RIH @ 25 fpm / 1500fph. Tagged 9778 ft 21:16 - 22:05 0.82 DRILL P PROD1 Orient TF to 170 L, Mud Swap 22:05 - 22:44 0.65 DRILL P PROD1 Drilling from 9778 ft to look for HOT at 8980 ft TVD at 173L Q = 2.76/2.90 bpm; P = 3615/3776 psi, Mud Swap taking place 22:44 - 22:53 0.15 DRILL P PROD1 Orient TF 22:53 - 23:30 0.62 DRILL P PROD1 Drilling from 9815 ft w/ 80L TF. Looking for HOT at 8980 ft TVD Q = 2.67/2.81 bpm; P = 3300/3647 psi, Mud Swap finished, taking fluid to pits Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/9/2004 22:53 - 23:30 0.62 DRILL P PROD1 Having some trouble keeping Sperry's tool on, having to cycle pump 23:30 - 23:45 0.25 DRILL P PROD1 Orient TF to 90L 23:45 - 00:00 0.25 DRILL P PROD1 Drilling w/73L TF; Q = 2.76/2.90 bpm; P = 3300/3876 psi. ROP inc to 154 fph, HOT? Taking 25ft sample to locate HOT 6/10/2004 00:00 - 00:10 0.17 DRILL P PROD1 Drilled to 9922' Some BHA stacking 00:10 - 00:50 0.67 DRILL P PROD1 Wiper trip to window Fluid transfer complete at 0040 hrs 00:50 - 01 :18 0.47 DRILL P PROD1 Orient TF at 9920 ft to 170L 01 :18 - 01 :55 0.62 DRILL P PROD1 Drilling at 170L to 132L TF. Q= 2.72/2.90bpm; P = 3300/3800 psi. Vp= 329 bbl Projected TVD at 8980 ft Stacking. PU tight at 9900 ft, pulled 60k (26k over) pulled free. Shale 01 :55 - 02:07 0.20 DRILL P PROD1 Work tight area,. clean up from 9945 ft to 9845 ft 02:07 - 02:30 0.38 DRILL P PROD1 Drilling at 152L TF. Q= 2.72/2.90bpm; P = 3300/3800 psi. Vp= 332 bbl Projected TVD at 8980 ft. WOB 7k to 8k ROP = 90 fph 02:30 - 02:42 0.20 DRILL P PROD1 Orient TF to 70 R 02:42 - 04:00 1.30 DRILL P PROD1 Drilling at 50R to 90R TF. Q= 2.72/2.90bpm; P = 3300/3998 psi. Vp= 318 bbl Sticky drilling. Survey at 9992' MD = 8981 TVD 04:00 - 04:45 0.75 DRILL P PROD1 Wiper trip after drilling 150', Circulate up Geo samples While RIH, tagged 9711' TF at 150R, PUH and went through. Shale 04:45 - 05:15 0.50 DRILL P PROD1 Orient TF to build 5'TVD 05:15 - 05:25 0.17 DRILL P PROD1 Drilling at 9L TF. Q= 2.72/2.90bpm; P = 3350/3998 psi. Vp= 330 bbl PU weight 32k and 17k down 05:25 - 05:44 0.32 DRILL P PROD1 Orient TF to 60R 05:44 - 05:50 0.10 DRILL P PROD1 Drilling 67R to 90R TF 05:50 - 06:00 0.17 DRILL P PROD1 Orient TF to 88L 06:00 - 06:50 0.83 DRILL P PROD1 Drilling at 88L TF Q= 2.63/2.77bpm; P = 3350/3900psi, Vp = 327bbl 06:50 - 07:05 0.25 DRILL P PROD1 Orient TF to 180 deg. 07:05 - 08:15 1.17 DRILL P PROD1 Drill to 10,164'. Stacking wt. 08:15 - 08:45 0.50 DRILL P PROD1 Wiper trip to 9,800', above shales. No over pulls or motor work. 08:45 - 10:50 2.08 DRILL P PROD1 Drill to 10,247'. Got back into sand. Drilling 95 fph. Build angle to 91.5 degrees inclination. Obtain on bottom drilling data and off bottom data to compare w/ tractor test. 10:50 - 11 :15 0.42 DRILL C PROD1 Wiper trip to 9,810'. Obtain more PU/SO and pressure data for tractor test. PU=31,500K, SO=17,OOO Ibs at 9,800', 10 fpm. 11:15-13:50 2.58 DRILL C PROD1 POOH in to tubing tail. RIH to 9,035' to flush cuttings from 7" casing. POOH pumping at 2.6 bpm. 13:50 - 15:30 1.67 DRILL C PROD1 Down load RES tool and LD same. LD orienter. Change out MWD probe. Check bit, 1-2-CT-G-X-NA-NO-BHA. Hang BHA from tugger. 15:30 - 16:00 0.50 DRILL C PROD1 RU hard line and hoses for tractor test. 16:00-16:15 0.25 DRILL C PROD1 PJSM for testing the Welltec tractor. 16:15 - 19:00 2.75 EVAL C PROD1 Circulate fluid through hoses prior to connecting to tractor. Fill up system w/ mud and PT surface test system to 2,500 psi. Surface test Welltec tractor at various flow rates to determine Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/10/2004 16:15-19:00 2.75 EVAL C PROD1 the repeatability of the flow rate required to open and close the tractor arms. Parameters Max Q = 2.6bpm Arms open Close arms, bring Qp down to 1.5bpm, arms retract The arms are still closed at 2.00 bpm The arms start opening at 2.2 bpm 19:00 - 19:20 0.33 EVAL C PROD1 PJSM on RD Tractor and making ready to RIH 19:20 - 20:00 0.67 EVAL C PROD1 Blow down tools, RD test hoses and tractor 20:00 - 20:55 0.92 EVAL C PROD1 PU Tractor BHA Set BHA at 92.35 ft 20:55 - 21 :11 0.27 EVAL C PROD1 RIH w/ BHA to test tractor to 500 ft Test Tractor at 2.00 bpm, good pulses, Oriented 3 click to test orienter 21:11 - 21:22 0.18 EVAL C PROD1 POOH and look at orienter scribe line to confirm clicks Confirmed 3 clicks at 20 deg/click 21 :22 - 22:05 0.72 EVAL C PROD1 RIH to 4500 ft to conduct test #2 22:05 - 23:30 1.42 EVAL C PROD1 Test tool at 4500 ft; Q=2.02 bpm. Orient TF from 155L 3 clicks TF at 122L RIH at 1 Of pm and 2 bpm. Inc Qp to 2.7 bpm to check tractor travel force Wt down 8000 # at 9.7fpm 2.6 bpm the load cell would inc to 10200# and then fall off to 8300# Stopped Coil, inc Qp from 0 to 2.9 bpm, no inc in wt cell from tractor. With wt at 13500#, inc Qp from 0 to 2.9 bpm the load cell didn't change. SD pump, RIH at 10 fpm inc Qp from 0 to 2.9 bpm. Load cell @ 8200# came up to 9300 # and then dropped off as before. Q=2.6 bpm P= 3463 psi. Stopped at 4723' -PUH to 4400 ft, RIH, check tool at various running speeds and flow. -Checked TF, function to confirm oriented again TF1 - 93L after 3 click TF=20L. 23:30 - 00:00 0.50 EVAL C PROD1 RIH to check tool in 7" casing at 8850' 6/11/2004 00:00 - 00:15 0.25 EVAL C PROD1 Tested tractor in 7" casing (6.184" ID) Increased Qp to 2.7 bpm load cell inc from 18.5k to 20.5k and repeated. 00:15 - 00:25 0.17 EVAL C PROD1 RIH to tie-in at 9182' 00:25 - 00:52 0.45 EVAL C PROD1 Tie-in coming up 9180' to 9155' (Corrected -14') 00:52 - 01 :07 0.25 EVAL C PROD1 RIH to 9800' to test tool with previsious collected data 01 :07 - 01 :30 0.38 EVAL C PROD1 Testing WellTech Tractor @ 2.7 bpm inc wt 1300# 01 :30 - 01 :32 0.03 EVAL C PROD1 RIH 01 :32 - 01 :44 0.20 EVAL C PROD1 Log from 10225 to 10250' w/ GR 01 :44 - 01 :48 0.07 DRILL C PROD1 -Drill with WellTech Tractor. Inc Qp to 2.5 bpm P= 3530/3805 psi TF climbed to 54L -Need 90L 01 :48 - 02:03 0.25 DRILL C PROD1 Orient TF around while PUH. Qmax = 2.0 bpm, arms stayed closed. 02:03 - 02:30 0.45 DRILL C PROD1 Drilling w/ tractor at 99L TF, Q= 2.53/2.65bpm, P3530/3955 psi. Vp = 285 bbl WOB = 22001b. ROP started at 56 fph. Consistent WOB curve. On-btm P is steady at 3944 psi 02:30 - 02:31 0.02 DRILL C PROD1 Red Qp to 2 bpm, PUH , clean orient 1 click to drill at 90L 02:31 - 02:43 0.20 DRILL C PROD1 Drilling w/ tractor at 60L TF, Q= 2.47/2.68bpm, P3530/4035 psi. Vp = 285 bbl WOB = 115 to 500 lb. ROP started at 56 fph and inc to 154 Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/11/2004 02:31 . 02:43 0.20 DRILL C PROD1 fph. Consistent WOB curve. On-btm P is steady at 3923 psi 02:43 - 02:45 0.03 DRILL C PROD1 PU to oriented 1 click to keep it at 90L PU wt = 36k 02:45 - 03:15 0.50 DRILL C PROD1 Drilling w/ tractor at 90 to 30L TF, Q= 2.63/2.84bpm, P3530/3975 psi. Vp = 285 bbl WOB = 115 to 500 lb. ROP=40 to 100 fph. Little reactive torque with tractor in BHA 03:15 - 03:36 0.35 DRILL C PROD1 PU to orient TF 3 click 37.5k Reactive torque acting like a fault area 03:36 - 03:57 0.35 DRILL C PROD1 Drilling w/ tractor at 88L to 11 OL TF, Q= 2.63/2.84bpm, P3530/3975 psi. Vp = 285 bbl 03:57 - 03:59 0.03 DRILL C PROD1 Orient TF to above 90L to build TVD as per GEO 8976' TVD looks ratty and he wants to build higher to 8973' TVD 03:59 - 05:24 1.42 DRILL C PROD1 Drilling w/ tractor at 45L to 90 L TF, Q= 2.63/2.84bpm, P=3530/3960 psi. Vp = 285 bbl ROP = 53 to 80 fph w/ 300 to 1100 Ib WOB. Trying to build up to 8973' TVD as per Geo Drilling shale at 10380 ft. Tractor drill shale with constants WOB and pump pressure. Averaged 45 fph with tractor BHA 05:24 . 05:26 0.03 DRILL C PROD1 Took survey on bottom. Unable to get azimuth 05:26 - 08:00 2.57 DRILL C PROD1 POOH with tractor BHA. Pump at 2 bpm so tractor arms remain closed and POOH 1 for 1. 08:00 - 09:00 1.00 DRILL C PROD1 LD tractor. Minimal wear on tractor tool wheels. Change MWD probe and pulser. Inspect bit and motor. Bit 1-2-BT-G-X-NA-ER-BHA. Errosion of matrix on gauge pads of bit and around face of diamonds. 09:00 - 09:45 0.75 DRILL C PROD1 PU RES tool and down load to tool. MU orienter. 09:45 - 12:00 2.25 DRILL C PROD1 RIH. 12:00 - 12:20 0.33 DRILL C PROD1 Tie in to RA marker. Correct -14.5'. 12:20 - 13:00 0.67 DRILL C PROD1 RIH. Set down at 9,725', 22N shale. PU and went through. Tag at 10,402'. 13:00 - 14:50 1.83 DRILL C PROD1 MAD pass w/ RES tool from 10,402' to 10,240'. RIH. 14:50 - 18:15 3.42 DRILL P PROD1 Tag bottom. Orient. Drill at 2.7/2.7 bpm, 3,500/3,720 psi. Drill to 10,470' and started losing at 0.3 bpm. Pit vol at 18:15, 246 bbls. 18:15 - 19:00 0.75 DRILL P PROD1 Drill 148L TF at 2.59 /1.95 bpm, Pp = 3,450 / 3,720 psi. losing at 0.6 bpm. Pit vol at 18:35hrs, 240 bbls. 19:00 hrs losing at 0.6 bpm 19:00 - 20:20 1.33 DRILL P PROD1 Wiper trip to window (Slow)Vp after wiper = 180 bbl 20:20 - 20:30 0.17 DRILL P PROD1 Drill 148L TF at 2.65 / 2.48 bpm, Pp = 3,450 / 3,809 psi. Return rate increased following wiper trip 20:30 - 20:45 0.25 DRILL P PROD1 Orient TF around to 180 20:45 - 21 :30 0.75 DRILL P PROD1 Dril1177L to 162L TF at 2.57 / 2.51 bpm, Pp = 3,450 / 3,809 psi. ROP = 40 to 50 fph Get 2 click after tagging bottom Unable to get BHA to drop hole angle. Drilling with negative string wt in shale. Geo gave us a ceiling of 8963 ft TVD to be leveled out 21 :30 - 21 :55 0.42 DRILL P PROD1 Orient TF around to 133L 21 :55 - 22:44 0.82 DRILL P PROD1 Drill 136L TF at 2.60 / 2.51 bpm, Pp = 3,450/3,772 psi. ROP = 36 fph Get 1 click Drilling break at 10,580 ft/8965'TVD. Started Mud swap at 2218 hrs. Unable to get WOB 22:44 - 23:29 0.75 DRILL P PROD1 Wiper trip to 9400' to get new mud around. Increased KlaGard from 8 to 12ppg Tagged at 9725 ft w/ HS TF. Unable at this time to get past. Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N1 Spud Date: 10/1/1982 End: 6/11/2004 23:29 - 00:00 0.52 DRILL P PROD1 Orient TFaround to 70 L Tried TF at 11 ORand 180, tagged at 9720 ft, PUH and oriented. At 9700 ft, turned 90R to 90L 6/12/2004 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Working to get past 9725' Oriented around 1-1/2 time and still unable to get pas!. Talk with town Engineer and decide to set oriention at 70 L to try and drill past with BC bit Geology is looking at alternative path. 00:30 - 01 :00 0.50 DRILL N DPRB PROD1 Orient TF to 70 L 01 :00 - 01 :45 0.75 DRILL N DPRB PROD1 Worked down to 9732' at 67L and then PU oriented 1 click to 45 L. Worked down to 9765 ft PUH clean Acts like drilling sand below 22N Shale 01 :45 - 02:06 0.35 DRILL C PROD1 POOH to setup for sidetrack. Unable to get past 22N shale, but a geologic sidetrack has already been discussed so this is not detramental. The plan is to sidetrack off an aluminum billet and drill the lateral section above the 22N shale, like the original geological plan, not below the 22N shale like in this first lateral. 02:06 - 03:47 1.68 DRILL C PROD1 Tie into RA Maker at 9061' Corrected +3 ft PUH and painted EOP Flag at 8900' w/ 90 ft BHA on 03:47 - 05:00 1.22 DRILL C PROD1 OOH, LD Drilling BHA, Download Res tool 05:00 - 06:00 1.00 STKOH C PROD1 WO Weatherford Filled hole, 14 bbl. Taking 4 bph to fill hole 06:00 - 06:45 0.75 STKOH C PROD1 MU Weatherford Aluminum billet and setting tool. 06:45 - 09: 10 2.42 STKOH C PROD1 RIH to 8,900' EOP flag. Correct depth -12.2'. Establish circulation prior to running through window. 0.7 bpm, 934 psi. PU=32K, SO=20K. Run in to open hole at 38 fpm, 0.7 bpm, 938 psi. Confirm sidetrack depth of 9,630' with geologist 9,575'. SO=12K. Looks like we are pushing some cuttings ahead of us. Slow running speed to 10-15 fpm. Got weight back at 9,620'. 60 deg hole angle in this area. RIH to 9,651'. PU=36K. Place top of AI billet at 9,630'. 09:10 - 09:55 0.75 STKOH C PROD1 Position reel to drop 5/8" steel ball. Drop ball and circulate ball down. Ball on seat at 52.5 bbls. Pressure up to 3,800 psi. PU to 33K and sheared off billet 09:55 - 11 :30 1.58 STKOH C PROD1 POOH. 11 :30 - 11 :45 0.25 STKOH C PROD1 LD WFD setting tools. 11 :45 - 12:30 0.75 STKOH C PROD1 PU sidetrack BHA w/ Hughes STR335G 3.74" bit, 2.0 deg motor, Dir/GR. 12:30 - 14:25 1.92 STKOH C PROD1 Pit vol.=275 bbls. RIH. Tie in to RA marker logging up, +3'. 14:25 - 14:45 0.33 STKOH C PROD1 RIH. Orient Tag AI billet at 9,630'. 14:45 - 17:30 2.75 STKOH C PROD1 Time drill off AI billet at 35L, 2.7 bpm, 2,900/3,100 psi. KOP at 9,630'. Drill at 35L-45L at high ROP, 140-190 fph. Compare surveys to old hole, definetly sidetracted. Drill to 9,700'. Pull above billet and RIH 5 times. Slight bobble pulling up hole. Smooth RIH. Take on bottom survey. 17:30 - 19:03 1.55 STKOH C PROD1 POOH pumping 2.7 bpm. 19:03-21:10 2.12 STKOH C PROD1 Change out BHA, Install Res tool and uploaded. Surface tested orienter OK 21:10- 22:39 1.48 STKOH C PROD1 RIH Tie-in at RA marker 22:39 - 23: 14 0.58 STKOH C PROD1 Tie-in at RA marker, (Corrected -14 ft) 23:14 - 23:30 0.27 STKOH C PROD1 RIH TF at 16L 23:30 - 23:39 0.15 STKOH C PROD1 RIH tagged billet, with HS TF, PU 44k (1 Okover) 23:39 - 00:00 0.35 STKOH C PROD1 Orient TF to 50L Only getting 10deg /click 6/13/2004 00:00 - 00:15 0.25 STKOH C PROD1 Final worked 4-1/8" BC bit into 3.74" pilot hole. Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/13/2004 00:15 - 00:40 0.42 STKOH C PROD1 W/R out 3.74" pilot hole with 3-3/4"-4-1/8"BC bit at 45L 5-6 fpm Q= 2.5/2.57bpm Stall at 9683'. Tagged at 9699' 00:40 - 00:50 0.17 STKOH C PROD1 MAD pass up for Geo from 9699' to 9650' 00:50 - 01 :18 0.47 STKOH C PROD1 Orient TF to 90R 01:18 - 01:47 0.48 DRILL C PROD1 Drilling 90R TF, P=2950/3200 psi; Qp =2.73/2.71bpm Vp = 328bbl at 0119hrs WOB = 1300 #. ROB= 150 fph 01 :47 - 02:40 0.88 DRILL C PROD1 Orient TF around to 45R. Having to work the BHA uphole to get oriented 02:40 - 04:13 1.55 DRILL C PROD1 Drilling 37R to 66RTF, P=2950/3200 psi; Qp =2.73/2.71bpm Vp = 326b bl at 0243hrs WOB = 3000 #. ROB= 80 to 100 fph 04:13 - 04:34 0.35 DRILL C PROD1 Drilling 120RTF, P=2950/3200 psi; Qp =2.73/2.71bpm Vp = 324 bbl at 0333hrs WOB = 3000 #. ROB= 80 to 100 fph 04:34 - 05:35 1.02 DRILL C PROD1 Wiper trip to window, Pulled little tight through billet. Fixed reel, banging. Worked through billet, RIH. Billet a tough area 05:35 - 05:48 0.22 DRILL C PROD1 Drilling 168L TF, P=2950/33067 psi; Qp =2.73/2.71bpm Vp = 320b bl at 00535hrs WOB = 4150 #. ROB= 80 to 100 fph 05:48 - 06:00 0.20 DRILL C PROD1 Orient TF around to 90 to 100 R 06:00 - 08: 10 2.17 DRILL C PROD1 Drilling 69L TF, P=2950/33067 psi; Qp =2.73/2.71 bpm Vp = 319b bl at 00600hrs WOB = 4150 #. ROB= 80 to 100 fph 08:10 - 11 :00 2.83 DRILL C PROD1 Wiper trip to window. Pull through billet oriented 40L, pulled smooth. Tie in log, +1.5'. Pull into tubing tail pumping 2.7 bpm. RIH. Orient to 40 before going through window. RIH and orient to 10L above billet. Run throught billet pumping .75 bpm, went through with no probem. RIH, tag bottom. Orient. 11 :00 - 13:30 2.50 DRILL C PROD1 Drill at 2.7/2.7 bpm, 2,900/3,200 psi. Slow ROP. Weight not drilling off. No reactive torque. Bit is probably hammered. Last sample showed 40% chert. 13:30 - 15:50 2.33 DRILL C PROD1 POOH to check bit. 15:50 - 16:45 0.92 DRILL C PROD1 Break bit. 16:45 - 18:15 1.50 DRILL C PROD1 RIH 18:15 - 18:30 0.25 DRILL C PROD1 Tie-in Corrected (+2 ft) 18:30 - 19:05 0.58 DRILL C PROD1 RIH, tagged billet and PU 1st and went through, RIH Tagged bottom at 10026' 19:05 - 19:10 0.08 DRILL C PROD1 OrientTF to 140L 19:10 - 19:20 0.17 DRILL C PROD1 Drilled 10027' to 10043 at 160L ROP = 150 fph, Qp = 2.60/2.65bpm, Pp= 2700 / 3100 psi. 19:20 - 19:25 0.08 DRILL C PROD1 Orient to 90L 19:25 - 20:35 1.17 DRILL C PROD1 Drilled 10043' to 10175' at 104L to 66L TF ROP = 150 fph, Qp = 2.60/2.65bpm, Pp= 2700 / 3100 psi. 20:35 - 21 :55 1.33 DRILL C PROD1 Wiper Trip to window. Seen billet 1 time, PU and RIH 21 :55 - 00:00 2.08 DRILL C PROD1 Drilled from 10175' to 10350' at 90Lto 75L TF Maintaining 8960' TVD ROP = 150 to 110 fph, Qp = 2.60/2.65bpm, Pp= 2700 / 3100 psi. Vp = 292 bbl TD well at 00:00 hrs 6/14/2004 00:00 - 00:55 0.92 DRILL P PROD1 Wiper trip to Tie-in bbl 00:55 - 01 :18 0.38 DRILL P PROD1 Tie-In at RA Marker at 9115' (Corrected +5 ft) 01: 18 - 01 :51 0.55 DRILL P PROD1 RIH to confirm TD Pumping 4%L T liner pill down CT while RIH Tagged at 10353 It MD 01 :51 - 01 :58 0.12 DRILL P PROD1 Circulate Survey up on bottom 01 :58 - 03:52 1.90 DRILL P PROD1 POOH, Pulled clean through the billet and window Painted flag Printed: 6/22/2004 10:14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: 6/14/2004 01 :58 - 03:52 1.90 DRILL P PROD1 at 8700' and 7300' EOP 03:52 - 05:30 1.63 DRILL P PROD1 OOH. Handle BHA. Down load Res Tool 05:30 - 06:00 0.50 CASE P RUNPRD Cut off DS CTC Install BOT CTC and pull test 35k. PT to 3500psi 06:00 - 07:45 1.75 CASE P RUNPRD Clear rig floor and off load MWD tools. PJSM. Load Dart and determine CT volume, dart hit at 58.9 bbls. 07:45 - 08:30 0.75 CASE P RUNPRD RU to run liner. PJSM on running liner. 08:30 - 11 :45 3.25 CASE P RUNPRD Run 2 7/8" x 3 3/16" liner. MU injector. 11 :45 - 13:40 1.92 CASE P RUNPRD Run liner in hole on CT. Correct to 7,300' EOP flag, -16.5' correction. PU=36,500 Ibs at 8,980'. SO=22,000 Ibs. Run liner into open hole. Go through window and billet with no problem. Land liner on bottom, tag at 10,350'. 13:40 - 14:10 0.50 CASE P RUNPRD Drop 5/8" steel ball. Circulate ball down. Ball on seat at 46 bbls. Pressure up to 3,900 psi to shear CTLRT and release from liner. PU and confirm release, PU=28,400 Ibs. 14:10-17:00 2.83 CASE P RUNPRD Displace well to 2% KCI. 17:00 - 17:15 0.25 CASE P RUNPRD PJSM for cement job. 17:15 - 17:30 0.25 CEMT P RUNPRD Batch mix cement. Cement up to weight at 17:30 hrs. 17:30 - 18:25 0.92 CEMT P RUNPRD Pump 3 bbls of water. PT cement lines to 4,000 psi. Pump 21 bbls of 15.8 ppg gas block cement. Shut inner reel valve and wash up lines. Launch wiper dart. Displace with 28 bbls of biozan, continue displacing with KCI. Pick up liner wiper dart at 59.0 bbls pumped. Shear liner wiper plug at 3,250 psi. Continue displacing and bump plug on calculated volume. Vol = 69.9 bbl CIP=18:25. 18:25 - 19:45 1.33 CEMT P RUNPRD Pressured up to 400 psi Unstung from deployment sleeve. POOH displaving CT volume 19:45 - 20:45 1.00 EVAL P LOWER1 MU 1-11/16" Motor and mill, 2jts 1-1/4" CSH 20:45 - 21 :00 0.25 EVAL P LOWER1 PJSM on running MCNL 21 :00 - 22:19 1.32 EVAL P LOWER1 RIH with 1-114" CSH and MCNL 22: 19 - 23:58 1.65 EVAL P LOWER1 MU MHA and CT, RIH Cement at 600 psi compressive strength at 6900 ft (4 hrs) 23:58 - 00:00 0.03 EVAL P LOWER1 Log down at 30 fpm and pumping 25 bbl perf pill 6/15/2004 00:00 - 00:35 0.58 EVAL P LOWER1 RIH logging at 30 fpm and tagged at billet area at 9625'. PUH and increased rate 1.6 bpm RIH to 9640 ft and pulled back through 00:35 - 01 :11 0.60 EV AL P LOWER1 RIH logging at 1.5 bpm Tagged at 10332' 01: 11 - 01 :40 0.48 EV AL P LOWER1 POOH logging at 60 fpm 01 :40 - 02:38 0.97 EV AL P LOWER1 POOH at 1.7 bpm. Cement at 7 hrs = 1700 psi compressive strength 02:38 - 02:50 0.20 EVAL P LOWER1 OOH, stand injector back, make ready to POOH with CSH 02:50 - 03:00 0.17 EVAL P LOWER1 PJSM on handling CSH 03:00 - 04:05 1.08 EVAL P LOWER1 POOH standing back CSH Cement at 2000 psi compressive strength at 0400 hrs 04:05 - 04:14 0.15 EVAL P LOWER1 PJSM on handling MCNL Source 04:14 - 04:25 0.18 EVAL P LOWER1 LD MCNL and check data integrity 04:25 - 05:20 0.92 EVAL P LOWER1 PT Casing to 2000 psi. IA = 180 psi and OA = 80 psi No change P1 = 2025psi 6 min P1 = 1234 psi P2 = 2032psi 6 min P2 = 1328 psi P3 = 2036psi 6 min P3 = 1337 psi 10 min = 1022 psi Test Failed Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 6/4/2004 6/16/2004 N1 Spud Date: 10/1/1982 End: MCNL Data: TOL at 8691 ft PBTD at 10318.5 ft 05:20 - 06:15 0.92 PERFO LOWER1 Load out MCNL tools and bring in perf guns 06:15 - 06:45 0.50 PERFO LOWER1 PJSM for PU perf guns. 06:45 - 07:45 1.00 PERFO LOWER1 PU 15 perf guns. MU firing head. 07:45 - 08:30 0.75 PERFO LOWER1 RIH w/ CSH from mast. 08:30 - 08:45 0.25 PERFO LOWER1 MU injector. 08:45 - 10:45 2.00 PERFO LOWER1 RIH. 10:45 - 11 :00 0.25 PERFO LOWER1 Tag at 10,331'. PU and confirm tag. PU to up wt. and correct depth to 10,318.5', PBTD from MCNL log. 11 :00 - 11 :50 0.83 LOWER1 Drop 5/8" steel ball. Circulate ball down at 2.3 bpm, 3,000 psi. Getting cement contaminated KCI back. Slow rate to 1 bpm w/ 50 bbls away. Ball on seat at 57.7 bbls. Pit Vol=235. IA=55, OA=73 psi. Move guns up hole at 10 fpm and pressure up to fire guns. Guns fired at 2,750 psi. Perforated w/ 2.0", 6 SPF, 2006PJ from 10,310' - 10,000'. 11 :50 - 13:41 1.85 PERFO P LOWER1 POOH pumping down CT at .4 bpm until out of the liner. Set trips to 2000 psi and increased Qp to clean out containmented cement. 3 bbllong on hole fill 13:41 - 14:00 0.32 PERFO P LOWER1 OOH, PJSM on handling CSH, monitor well. 14:00 - 14:10 0.17 PERFO P LOWER1 Stand back injector, make ready to POOH and LD CSH 14:10 - 16:00 1.83 PERFO P LOWER1 POOH and laying down CSH 16:00 - 16:10 0.17 PERFO P LOWER1 PJSM on handling perf guns 16:10 - 17:00 0.83 PERFO P LOWER1 POOH LD guns, all fired 17:00 - 17:45 0.75 PERFO P LOWER1 RIH with CSH to LD 17:45 - 19:00 1.25 PERFO P LOWER1 POOH LD 1-1/4" CSH. Took 2 bbl to fill hole. 19:00 - 19:45 0.75 PERFO P LOWER1 PJSM liner packer MU. RU floor 19:45 - 20:15 0.50 PERFO P LOWER1 RI H with liner top packer to 1850'. 20:15 - 22:45 2.50 PERFO N RREP LOWER1 Power outage. Initial investigation. The 24volt control system shorted causing a total SCR system shut down. Unable to start gen3 use all compressed air. Call for compressor and electrician. Circuit breaker on #2 motor will not latch appears it is not getting the 24v feed from control system. (still under investigation). 22:45 - 00:00 1.25 LOWER1 RIH with packer utilizing gen #2 for DC and gen #3 for AC loading. 6/16/2004 00:00 - 00:40 0.67 LOWER1 Sting into tie back. Note pressure increase and stack 10 K at 8709' uncorrected. Attempt to test backside to 2000 psi. No Test. At 1400 psi pressure on coil side noted. Pressure dropped to 600 psi in 8 minutes. Drop 5/8 ball. 00:40 - 01 :40 1.00 LOWER1 Circulate ball at 1.9 bpm at 650 psi. Sting into tieback. PU 2' wait for ball to drop. 01 :40 - 02:30 0.83 DFAL LOWER1 Attempt to pressure to 2500 .5 bpm at 570 psi. Note 1 for 1 returns. suspect rupture disc failure. Seen pressure rise to 700psi and gradual decrease in pressure to 300 psi at total in volume of 55 bbl. Washout of rupture disc?? Continue to circulate to 64 bbl. Five over coil volume. 02:30 - 03:45 1.25 PERFO DFAL LOWER1 POH to surface. 03:45 - 04:45 1.00 PERFO LOWER1 Unable to redress ruppture disc at site. Ship packer off to Baker for redress. PU test seals 04:45 - 07:38 2.88 PERFO LOWER1 RIHWt check at 8600 ft = 29.5k up Tagged at 8702', set 10k down and lined out to PT annulus Printed: 6/22/2004 10: 14:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07:50 - 09: 10 09:10 -10:35 10:35 . 12:42 12:42 - 15:30 15:30 - 15:38 15:38 - 17:05 17:05 - 17:49 17:49 - 18:30 18:30 - 19:00 19:00-19:15 19:15-21:00 21 :00 - 22:30 06-23 06-23 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 6/4/2004 Rig Release: 6/16/2004 Rig Number: N1 Spud Date: 10/1/1982 End: LOWER1 LOWER1 PT CT annulus/Liner Lap. IA/OA = 90/65 1000 psi 1 min P = 150psi P = 2000 psi 0740 hrs 6 min lost 1250 psi IA steady at 200 psi and OA steady at 122 psi Released pressure POOH to PU KB Packer. While POOH, skim of oil on pits Stand inject back, RD seal assembly and RU KB Packer w/ 10' 2-7/8" extension RIH with KB Packer BHA Wt check at 8600 ft ( Wt up = 28.5 k up) Tagged at 8704' with locator sub. 8711.2 with 10k down. PUH, out of seals, to drop 5/8" ball Lanuch 5/8" ball. Pumped 45 bbl and SD, Stung into deployment sleeve. Set down at 8711.2' PU 2 ft. Allow ball to fall. Set KB Packer. PT annulus to 2000 psi and lost 700 psi in 6 min. IA increased 470 psi First time the IA pressure has been over 200 during pressure testing of liner lap. Retested to 2000 psi lost 1400 psi in 13 min, checked IA fluid content "gas" Bleed small amount gas off, 10 sec throught 1/2" hose, to bleed trailer and got fluid to surface. Retest to 2000 psi, IA inc from 200 to 400 psi 8 min P CT A = 989 psi Rested from 989psi to 2000 psi, IA inc 400 psi to 688 psi 10 min the CT ann @ 992 psi and the IA at 721 psi Retest again to check IA. Inc the CT annulus pressure from 992 psi to 1500 psi and the IA rose from 688 psi to 800 psi, direct communications Released at 3650 psi PUH at 32.5k POOH POOH with BOT running tool Top of Packer at 8678 ft Min ID at 2.372" packer area LD BOT KB running tool and MU MHA and nozzle. PT lubricator to 2500 psi RIH to FP POOH FP at 50% PJSM for N2 blow down. N2 blow down. ND BOP. Release Rig at 2230 hrs 6-16-2004 2.12 LOWER1 LOWER1 0.13 1.45 LOWER1 LOWER1 LOWER1 0.68 WHSUR P 0.50 WHSUR P 0.25 WHSUR P 1.75 WHSUR P 1.50 WHSUR P POST POST POST POST POST Printed: 6/22/2004 10: 14:30 AM . . 24-Jun-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 6-238 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: 9,630.58' MD 0.00' MD 10,353.00' 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 Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 '/l ( D' j, . ,,~ JJMJ Date-!.1J)"J ,l\j'\t\-{ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ? Ù "1- ~D{ Attachment(s) - Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 06 06-23B 14 June, 2004 Job No. AKMW3112076, Surveyed: Survey Report e 16 June, 2004 Your Ref: API 500292080802 Surface Coordinates: 5941299.11 N, 685969.85 E (70014' 40.4979" N, 148029' 51.9969" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy4275 Surface Coordinates relative to Project H Reference: 941299.11 N, 185969.85 E (Grid) Surface Coordinates relative to Structure Reference: 612.12 S, 1278.67 E (True) Kelly Bushing E/evation: 74.00ft above Mean Sea Leve/ Kelly Bushing Elevation: 74.00(t above Project V Reference Kelly Bushing Elevation: 74.00ft above Structure Reference spa............y-suir"! DFUL.L.tNG seRVlc::es A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_EOA DS 06 - 06-23B Your Ref: AP/ 500292080802 Job No. AKMW3112076, Surveyed: 14 June, 2004 BPXA 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) (0/100ft) 9630.58 68.910 272.640 8943.04 9017.04 1923.05 N 823.00 E 5943241.88 N 686745.15 E -755.38 Tie On point 9666.03 79.360 262.800 8952.74 9026.74 1921.62 N 789.02 E 5943239.61 N 686711.22 E 39.740 -721.48 9704.06 88.460 260.730 8956.77 9030.77 1916.20N 751.64 E 5943233.27 N 686673.98 E 24.532 -684.31 9734.61 87.930 264.430 8957.73 9031.73 1912.26 N 721.37 E 5943228.59 N 686643.81 E 12.229 -654.19 9767.64 89.690 270.780 8958.42 9032.42 1910.88N 688.39 E 5943226.39 N 686610.88 E 19.945 -621.28 e 9799.19 90.130 274.480 8958.47 9032.47 1912.33 N 656.88 E 5943227.06 N 686579.34 E 11.810 -589.74 9832.21 90.840 281.530 8958.19 9032.19 1916.92N 624.20 E 5943230.85 N 686546.56 E 21 .458 -556.92 9873.87 88.900 285.760 8958.28 9032.28 1926.75 N 583.73 E 5943239.67 N 686505.86 E 11 .170 -516.13 9928.32 87.310 295.100 8960.09 9034.09 1945.72 N 532.79 E 5943257.38 N 686454.47 E 17.390 -464.56 9980.91 89.410 292.750 8961.59 9035.59 1967.04 N 484.74 E 5943277.51 N 686405.91 E 5.991 -415.80 10033.77 92.250 293.690 8960.83 9034.83 1987.87 N 436.18 E 5943297.14 N 686356.84 E 5.659 -366.53 10065.47 90.570 289.630 8960.05 9034.05 1999.57 N 406.73 E 5943308.10 N 686327.12 E 13.857 -336.70 10100.60 89.430 283.990 8960.05 9034.05 2009.72 N 373.12 E 5943317.43 N 686293.26 E 16.379 -302.75 10137.51 89.870 281.880 8960.27 9034.27 2017.98 N 337.14 E 5943324.80 N 686257.10 E 5.839 -266.51 10177.71 88.810 276.770 8960.73 9034.73 2024.49 N 297.49 E 5943330.33 N 686217.30 E 12.981 -226.66 10213.12 87.840 269.190 8961.77 9035.77 2026.33 N 262.17 E 5943331.29 N 686181.94 E 21.572 -191.29 10246.77 88.550 269.900 8962.83 9036.83 2026.07 N 228.54 E 5943330.20 N 686148.33 E 2.983 -157.69 10279.73 89.870 268.660 8963.29 9037.29 2025.65 N 195.59 E 5943328.97 N 686115.40 E 5.494 -124.77 10309.81 90.930 263.380 8963.07 9037.07 2023.56 N 165.59 E 5943326.14 N 686085.46 E 17.903 -94.87 10332.48 93.300 262.210 8962.24 9036.24 2020.72 N 143.12 E 5943322.75 N 686063.07 E 11.657 -72.51 10353.00 93.300 262.210 8961.06 9035.06 2017.95 N 122.82 E 5943319.47 N 686042.84 E 0.000 -52.32 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 Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 272.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10353.00ft., The Bottom Hole Displacement is 2021.68ft., in the Direction of 3.483° (True). 16 June, 2004 - 10:30 Page 2 of 3 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 06 - 06·23B Your Ref: API 500292080802 Job No. AKMW3112076, Surveyed: 14 June, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9630.58 10353.00 9017.04 9035.06 1923.05 N 2017.95 N 823.00 E Tie On point 122.82 E Projected Survey e Survey tool program for 06-238 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9000.00 0.00 9000.00 8502.00 10353.00 8502.00 BP Conventional Gyro (06-23) 9035.06 MWD Magnetic (06-23BPB1) e 16 June, 2004· 10:30 Page 3 of 3 DrillQuest 3.03.06.002 . . 24-Jun-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 6-238 P81 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: 9,000.00' MD 9,051.00' MD 10,603.00' 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 /6 \ ) v0 4ò "1 Please call me at 273-3545 if you have any questions or concerns. Regards, Signed· ~ I () j)~ William T. Allen Survey Manager ~ \.) vl- Ò y » Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 06 06-23BPB1 e Job No. AKMW3112076, Surveyed: 16 June, 2004 Survey Report 16 June, 2004 Your Ref: API 500292080870 Surface Coordinates: 5941299.11 N, 685969.85 E (70014' 40.4979" N, 148029' 51.9969" W) Grid Coordinate System: NAD27 A/aska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 941299.11 N, 185969.85 E (Grid) Surface Coordinates relative to Structure Reference: 612.12 S, 1278.67 E (True) Kelly Bushing Elevation: 74.00ft above Mean Sea Leve/ Kelly Bushing Elevation: 74.00ft above Project V Reference Kelly Bushing Elevation: 74.00ft above Structure Reference 5pE!í'í'~-5U'" DRILLING S.ERVIC:ES A Halliburton Company Survey Ref: svy4274 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 06 - 06-23BPB1 Your Ref: API5002920BOB70 Job No. AKMW3112076, Surveyed: 16 June, 2004 BPXA 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) (0/100ft) 9000.00 30.000 49.000 8428.00 8502.00 1760.34 N 927.07 E 5943081.79 N 686853.20 E -865.07 Tie On Point MWD Magnetic 9051.00 30.640 49.000 8472.02 8546.02 1777.23 N 946.50 E 5943099.15 N 686872.21 E 1.255 -883.90 Window Point 9080.25 33.840 43.140 8496.76 8570.76 1788.07 N 957.70 E 5943110.26 N 686883.14 E 15.284 -894.72 9120.79 38.230 35.820 8529.55 8603.55 1806.49 N 972.78 E 5943129.05 N 686897.76 E 15.153 -909.14 e 9152.09 36.470 30.770 8554.44 8628.44 1822.34 N 983.21 E 5943145.16 N 686907.79 E 11.285 -919.01 9184.55 31.290 23.560 8581.39 8655.39 1838.38 N 991.52 E 5943161.39 N 686915.71 E 20.175 -926.76 9218.64 24.780 23.380 8611.46 8685.46 1853.06 N 997.90 E 5943176.23 N 686921.72 E 19.098 -932.62 9252.01 18.900 13.360 8642.44 8716.44 1864.76 N 1001.93 E 5943188.02 N 686925.46 E 20.805 -936.24 9285.81 14.590 352.440 8674.82 8748.82 1874.31 N 1002.63 E 5943197.59 N 686925.93 E 21.732 -936.61 9316.32 16.440 329.940 8704.25 8778.25 1881.87 N 999.96 E 5943205.08 N 686923.08 E 20.492 -933.68 9346.43 21.180 317.110 8732.75 8806.75 1889.55 N 994.12 E 5943212.61 N 686917.05 E 20.808 -927.57 9377.22 25.750 306.570 8761.00 8835.00 1897.62 N 984.96 E 5943220.45 N 686907.68 E 20.100 -918.13 9407.60 26.280 297.950 8788.31 8862.31 1904.70 N 973.71 E 5943227.26 N 686896.27 E 12.557 -906.64 9438.54 30.410 289.340 8815.55 8889.55 1910.51 N 960.26 E 5943232.73 N 686882.68 E 18.752 -893.00 9472.75 35.420 281.610 8844.27 8918.27 1915.38N 942.36 E 5943237.16 N 686864.66 E 19.086 -874.94 9505.04 40.170 280.370 8869.78 8943.78 1919.14 N 922.94 E 5943240.44 N 686845.15 E 14.897 -855.40 9536.41 45.700 275.630 8892.75 8966.75 1922.07 N 901.79 E 5943242.84 N 686823.94 E 20.403 -834.16 9567.66 53.530 270.000 8912.99 8986.99 1923.16 N 878.05 E 5943243.35 N 686800.18 E 28.550 -810.40 9600.45 61.870 268.420 8930.49 9004.49 1922.77 N 850.36 E 5943242.27 N 686772.51 E 25.757 -782.74 9630.58 68.910 272.640 8943.04 9017.04 1923.05 N 823.00 E 5943241.88 N 686745.15 E 26.603 -755.38 9661.91 74.620 276.680 8952.84 9026.84 1925.48 N 793.36 E 5943243.58 N 686715.46 E 21.954 -725.68 e 9692.05 78.400 285.300 8959.88 9033.88 1931.08N 764.63 E 5943248.47 N 686686.60 E 30.501 -696.77 9726.87 79.630 286.700 8966.52 9040.52 1940.50 N 731.77 E 5943257.07 N 686653.52 E 5.297 -663.60 9756.58 84.640 281.960 8970.58 9044.58 1947.77 N 703.27 E 5943263.64 N 686624.85 E 23.108 -634.87 9800.21 89.600 281.350 8972.78 9046.78 1956.57 N 660.61 E 5943271.39 N 686581.98 E 11 .454 -591.92 9829.42 87.840 279.410 8973.43 9047.43 1961.83 N 631.89 E 5943275.94 N 686553.14 E 8.966 -563.03 9871.83 87.140 271.660 8975.29 9049.29 1965.92 N 589.75 E 5943278.98 N 686510.91 E 18.331 -520.78 9901.20 89.070 267.250 8976.26 9050.26 1965.64 N 560.40 E 5943277.98 N 686481.58 E 16.382 -491 .46 9925.34 88.990 266.020 8976.67 9050.67 1964.22 N 536.31 E 5943275.97 N 686457.53 E 5.105 -467.43 9957.44 86.170 268.140 8978.02 9052.02 1962.59 N 504.28 E 5943273.54 N 686425.56 E 10.987 -435.48 16 June, 2004 - 10:19 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 06 - 06-23BPB1 Your Ref: API 500292080870 Job No. AKMW3112076, Surveyed: 16 June, 2004 BPXA 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) 9992.19 87.140 269.900 8980.05 9054.05 1961.99 N 469.60 E 5943272.09 N 686390.90 E 5.775 -400.84 10024.74 89.250 274.660 8981.08 9055.08 1963.29 N 437.10 E 5943272.59 N 686358.38 E 15.989 -368.32 10061.83 91.540 277.650 8980.82 9054.82 1967.26 N 400.23 E 5943275.65 N 686321.42 E 10.154 -331.33 10091.52 95.770 279.770 8978.93 9052.93 1971.75 N 370.96 E 5943279.41 N 686292.04 E 15.929 -301.92 10124.68 94.360 279.940 8976.00 9050.00 1977.40 N 338.41 E 5943284.26 N 686259.37 E 4.283 -269.20 e 10160.68 90.310 279.240 8974.54 9048.54 1983.39 N 302.95 E 5943289.37 N 686223.77 E 11.416 -233.55 10195.34 86.610 276.950 8975.47 9049.47 1988.27 N 268.66 E 5943293.40 N 686189.37 E 12.552 -199.11 10225.33 89.340 272.540 8976.53 9050.53 1990.75 N 238.80 E 5943295.14 N 686159.46 E 17.285 -169.18 10255.69 91.140 271.940 8976.40 9050.40 1991.94 N 208.47 E 5943295.58 N 686129.10 E 6.250 -138.82 10281.24 89.560 267.890 8976.24 9050.24 1991.90N 182.92 E 5943294.91 N 686103.57 E 17.014 -113.29 10313.28 91.140 263.500 8976.05 9050.05 1989.49 N 150.98 E 5943291.72 N 686071.70 E 14.561 -81.46 10344.30 90.970 261.040 8975.48 9049.48 1985.32 N 120.25 E 5943286.79 N 686041.08 E 7.948 -50.89 10385.70 90.660 254.210 8974.89 9048.89 1976.46 N 79.84 E 5943276.93 N 686000.90 E 16.513 -1 0.82 10422.86 94.100 251.920 8973.34 9047.34 1965.64 N 44.33 E 5943265.25 N 685965.67 E 11.117 24.30 10458.83 92.160 258.090 8971.38 9045.38 1956.36 N 9.66 E 5943255.11 N 685931.23 E 17.956 58.63 10494.69 91.720 255.450 8970.16 9044.16 1948.16 N 25.23 W 5943246.05 N 685896.56 E 7.459 93.20 10525.95 94.270 254.210 8968.53 9042.53 1939.99 N 55.36 W 5943237.14 N 685866.64 E 9.068 123.03 10552.90 92.950 252.450 8966.83 9040.83 1932.27 N 81.12 W 5943228.79 N 685841.08 E 8.153 148.51 10585.27 90.400 252.450 8965.89 9039.89 1922.52 N 111.97 W 5943218.28 N 685810.48 E 7.878 178.99 10603.00 90.400 252.450 8965.76 9039.76 1917.17 N 128.87 W 5943212.52 N 685793.71 E 0.000 195.70 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. e Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 272.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10603.00ft., The Bottom Hole Displacement is 1921.50ft., in the Direction of 356.154° (True). 16 June, 2004 - 10:19 Page 3 of 4 Dri/lQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 06 - 06-23BPB1 Your Ref: API5002920BOB70 Job No. AKMW3112076, Surveyed: 16 June, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9000.00 9051.00 10603.00 8502.00 8546.02 9039.76 1760.34 N 1777.23 N 1917.17 N 927.07 E 946.50 E 128.87 W Tie On Point Window Point Projected Survey e Survey tool program for 06-23BPB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9000.00 0.00 9000.00 8502.00 10603.00 8502.00 BP Conventional Gyro (06-23) 9039.76 MWD Magnetic (06-23BPB1) e 16 June, 2004 - 10:19 Page 4 of 4 DrillQuest 3.03.06.002 TREE = WELLHEAD = A crUA TOR = KB. ELEV = BF. ELEV - KOP= Max An Ie = Datum MD = Datum TVD = FMC GE3IJ 3 FMC AXELSON 74' 06-238 I SAFETY NOTES: 4600' 10332' 9421' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.375" @ 8678" KB LNR TOP PKR 15-1/2" TBG-FC, 17#, L-80, .0232 bpf, [) - 4.892" I 8657 3-1/2" LNR, 8.81 #, L-80, .0087 bpf, ID = 2.990" 8745' 4-1/2"1BG-PC, 12.6#, N-80, 8754' .0152 bpf, [) = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" ÆRFORA TON SUrvtvlARY RIT LOG: SWS CNL OS/24/00 A NGLE AT TOP PERF: 90 @ 10000' Note: Refer to Production DB for historical perf data SIZE SFr INlERVAL Opn/Sqz DATE 2" 6 10000 - 10310 0 06/15/04 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9870' 12-718" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" H 10636' DATE 10/22/82 OS/24/00 06/15/04 06/21104 RBI BY COrvtvlE3lJTS ORIGINAL COM PLETION SIŒTRACK COMPLETION CTD SIDETRACK (06-238 GJBlKAK GLV 00 DAlE REV BY . 2099' 5-112' CAMOO BAL-O SSSV NIP, ID - 4.562" GA S LIFT MA. NDRELS ST rvD TVD ŒV TYPE VLV LATa-; PORT DATE 1 2929 2929 0 rvtvIlG 00 M E RK 16 06/21/04 2 4763 4757 12 rvtvIlG SO RK 20 06/21/04 3 6120 6023 32 rvtvIlG av1Y RK 0 OS/23/04 4 7211 6914 32 rvtvIlG av1Y RK 0 5 7829 7450 28 rvtvIlG av1Y RK 0 6 7906 7518 27 rvtvIlG av1Y RK 0 OS/23/04 7 8243 7820 25 rvtvIlG av1Y RK 0 8 8312 7882 24 M'v1IG av1Y RK 0 9 8535 8087 23 MMIG av1Y RK 0 OS/23/04 10 8607 8153 24 M'v1IG av1Y RK 0 5-1/2" BAKER PBR ASSY I 9-518" X 5-1/2' BAKER SAB PKR I 8657' 5-1/2" X 4-1/2' XO 8678' KB LNRTOPPKR, [) =2.375" 8693' 3-1/2" HES X NIP, ID - 2.813" 4-1/2" CAMCO DB-6 NIP, ID = 3.813" (Be-JIND cr LNR) 8745' 3-1/2" X 3-3/16" XO, ID = 2.80" 8755' 4-1/2" TUBING TAIL (Be-JIND CT LNR) 8800' emMA TED TOP OF CEMENT 8741' ELMO IT LOGGED 09/17187 (Be-JIND CT LNR) MlLLOUT WINooW 9056' - 9063' 3-3/16" X 2-7/f!' XO, ID = 2.440" COMrvENTS PRLOI-OE BAY LNIT WELL: 06-23B PERMrr f\b: 2040870 A R f\b: 50-029-20808-02 SEC 2, T1 ON, R14E, 4325.36' FEL & 2175.84' FNL BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL Al'O) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 06-23B BP Exploration (Alaska) Inc. Permit No: 2Q4..087 Surface Location: 4577' FNL, 1008' WEL, SEC. 02, TlON, R14E, UM Bottomhole Location: 2779' FNL, 1521' WEL, SEe. 02, TlON, R14E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659 7 (pager). BY ORDER 0I!JI.!E ~~SSION DATED thisJPtGy Of~04 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. VJGA- 5 , ~s {2..004- . STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION C MISSI.Q.~C E··'VED PERMIT TO DRILL Kt: m 20 MC 25.005 MAY 192004 o Drill a 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: 4577' FNL, 1008' WEL, SEC. 02, nON, R14E, UM Top of Productive Horizon: 2622' FNL, 144' EWL, SEC. 01, T10N, R14E, UM Total Depth: 2779' FNL, 1521' WEL, SEC. 02, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685970 y- 5941299 Zone- ASP4 16. Deviated Wells: Kickoff Depth 18... Casing program Size Casina Weiaht 4-1/4" x 3-3/4" 3-3/16" x 2-7/8" 6.2# /6.5# rb. Current Well Class 0 Exploratory a Development Oil 0 1'1ultiple ZQ,RR o Stratigraphic Test 0 Service I\f !./ilqvMt~tn\!3~n£J t,)1JijI1iØ~ ' 5. Bond: IBI Blanket 0 Single Well 11. Well ~fI~fl'Jumber: S/z.o Bond No. 2S100302630-277 PBU 06·23B 6. Proposed Depth: 12. Field / Pool(s): MD 11020 TVD 8973ss Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool '---- ADL 028311 8. Land Use Permit: 13. Approximate SpUd Da1i~ June P'20~4 14. Distance to Nearest Property: 21,000' 9. Acres in Property: 2560 9068 ft 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 74' feet 06-01 is 952' away at 10286' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle 91 0 Downhole: 3270 psig Surface: 2390 rpsig $ê~ing .º~pth Top·/· . ·8òttôm Grade CouDlina Length MD TVD MD TVD L-80 TCII/STL 2340' 8680' 8145' 11020' 8973 Hole fr.f (includina staoe data) 121 sx Class 'G' ,/ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft):1 10638 9004 None 10531 9015 I ~"",;nn Lenoth Size· . I MD Junk (measured): None . TVD Strllctllr::!1 Conductor 79' 20" 1990# Poleset SlJrf::!r.p. 2525' 13-3/8" 2400 sx Fondu, 400 sX PF 'C' Intermediate 9016' 9-5/8" 500 sx Class 'G', 50 Bbls PF 'C' PrnnlJr.tinn Liner 823' 7" 325 sx Class 'G' Liner 1954' 2-7/8" 94 sx LARC 79' 2525' 9016' 79' 2525' 8516' 8697' - 9520' 8684' - 10638' 8235' - 8941' 8223' - 9004' Perforation Depth MD (ft): 9602' - 10530' 20. Attachments IBI Filing Fee, $100 IBI BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 9000' - 9015' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty ;' Title CT Drilling Engineer Prepared By Name/Number: Sianature /¿. ---"... /CA" ~ Phone 564-4378 Date S- Úc9/V'~ Terrie Hubble, 564-4628 ./" '. # -' . . Permit To Drill I API Number: Permit Approval. \' ~'\\ see cover.letter for Number: .2.;; (.! - ~ t¡: 71 50- 029-20808-02-00 Date: \ ~ \ j G ~ other reqUirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required' , 0 Yes .a No Hydrogen Sulfide Measures MYes 0 No Directional Survey Required )(rYes 0 No Other: n ~ t- 'B" Y E +0 ÐO f ~ ~ p e -ý C.. o. '5 I (;.. 000 . ~DrovedBY1 ~k/ Form 10-401 ~sed 12~ U 7< ILJ II\J A L Date: Contact Thomas McCarty, 564-4378 .-..... BY ORDER OF THE COMMISSION \ '\1 #, # ~~~~~'bte Dat~ . . BP 06-23B Sidetrack Summary of Operations: Well 06-23A is scheduled for a through tubing sidetrack with SLBlNord~I-ifl early June. This ~ be the second CTD sidetrack from this wellbore. The existing well will be plugged with a"e(B¥set at appro x 9160'. The existing 2-7/8" liner will be cut at approx 9120' and retrieved. The sidetrack, 06-23~11 exit out of the existing 7" liner from a mechanical whipstock. The well targets Zone 2 reserves. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1) Slickline - Drift/Caliper tubing and liner. Dummy gas lift valves. Pressure test IA to 2500 psi. 2) Eline - Set CIEP at approx. 9145' (8552'TVDss), cut 2-7/8" liner at approx. 9120'. 3) Coil- Latch onto 2-7/8" liner, pick up and confirm free. CTD Sidetrack Summary 1) MIRU CTD rig. 2) Pull 2-7/8" liner, Run Thru tubing whipstock set in 7" liner at approx. 9068' (8487'TVDss), cement whipstock in place. 3) Mill 3.8" window off of whipstock. 4) Drill 4-114" x 3'?ij5" 0 en hole sidetrack to 11020' planned TD with MWD/gamma ray. 5) Run 3-3/16" x 2-7/.1" er completion. Top ofliner will be at 8680' md (8145'TVDss) in 4 Yz" tubing tail. Cement liner wi 25.. Is of 15.8 ppg cement, plan to bring cement top to 8800'md. 6) Run MCNL, Pe te. 7) RDMO. / Mud Program: · Phase 1: 8:~~g seawater / · Phase ~?pg used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / · A 3-3/16" x 2-7/8" solid cemented liner completion from 8680' to TD at 11020'. The liner cement volume is planned to be -25 bbls of 15.8 ppg class G. Perforate liner as per Asset instructions, planned interval length is 300'. Parent Well Casinas Burst (psi) Collapse (psi) 9%" 47#, L-80 6870 4760 7" 29#, L-80 8160 7020 NA NA Sidetrack Casinas 3-3/16" 6.2#, L-80, TCII- Prod LNR 8520 7660 2Ys" 6.5#, L-80, STL - Prod LNR 10570 11170 / / 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 92deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 06-23B will be approximately 952' ctr-ctr away from well 6-01 at 10286'md · 06-23B will be approximately 21,000' from the unit boundary, (Prudhoe Bay Unit) . . Logging · MWD Gamma Ray log will be run over all of the open hole section. · Resistivity log will also be run in the OH section. · A CNUGR/CCL cased hole log will be run after the liner has been cemented. Hazards / · Drill site 6 is considered an H2S pad, there have been measurements above looppm on offset wells. The latest - measurement on 06-23A on 2/1/2001 was 2ppm All H2S monitoring equipment will be operational. · Loss circulation is considered a low risk, no faults are prognosed in the polygon. Reservoir Pressure · Res. press. is estimated to be 3270psi at 88oo'ss (7.2 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2390 psi. / TREE:; W8.LHEAD = ACTUA TOR = KB. 8.EV = BF. 8.EV = KOP= Max Angle = Datum MD = DatumTVD= . . I SAÆTY NOTES: 06-23A / FMC GEN 3 FMC AX8.S0N 74' ? 4600' 99 @ 10312' 9439' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.38" @ 8695' 3-112" X 2-7/8" XO 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I TOPOF 4-1/2" TBG-PC I 8657' 8657' TOPOF 2-7/8" LNR I TOPOF 7" LNR I 8697' 4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8754' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORA TION SUMMARY REF LOG: SWS CNL OS/24/00 ANGLE AT TOP PERF: 57 @ 9602' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9602 - 9612 0 01/07/04 1-11/16" 4 9623-9648 0 11/16/01 2" 4 9684 - 9694 0 01/07/04 1-11/16" 4 9710 - 9740 0 11/16/01 2" 4 9840 - 10000 0 OS/26/00 2" 4 10050 - 10200 0 OS/26/00 1-11/16" 4 10291 -10331 0 08/08/01 1-11/16" 4 10364 -10404 0 08/08/01 1-11/16" 4 10490 -10510 0 08/15/00 1-11/16" 4 10510 -10530 0 09/24/00 . 2099' -15-1/2" CAMCO BAL-O SSSV NIP, ID - 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 2929 2929 0 MMIG RK 2 4763 4757 12 MMIG RK 3 6120 6023 32 MMIG RK 4 7211 6914 32 MMIG RK 5 7829 7450 28 MMIG RK 6 7906 7518 27 MMIG RK 7 8243 7820 25 MMIG RK 8 8312 7882 24 MMIG RK 9 8535 8087 23 MMIG RK 10 8607 8153 24 MMIG RK -1 5-1/2" BAKERPBRASSY I -1 9-5/8" X 5-1/2" BAKER SAB A<R I 8657' -1 5-1/2" X 4-1/2" XO I 8689' -1 3-1/2" DEPLOYMENT SLV, ID = 3.0" I 8695' -1 3-1/2" X 2-7/8" XO, ID = 2.380" I 8741' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" (BEHIND CT LNR), 4-1/2" TUBING TAIL (BEHIND CT LNR) 8.MDTTLOGGED09/17/87 I 8755' 8741' MILLOUT WINDOW 9517' - 9524' 10531' I 10638' I I 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" I DA TE REV BY COMMENTS 10/22/82 ORIGINAL COMPLETION 05/24/00 SIDETRACK COM PLETION 09/19/01 RN/TP CORRECTIONS 11/16/01 TMN/KAK ÆRFS 08/19/03 CMOITLP PERF ANGLE CORRECTION 01/20/04 MJAITLH ÆRFS (01/07/04) DA TE REV BY COMMENTS PRUDHOE BA Y UNIT W8.L: 06-23A ÆRMIT No: 2000370 API No: 50-029-20808-01 SEC 2, T10N, R14E, 4325.36' F8. & 2175.84' FNL BP Exploration (Alaska) TREE =' FMC GEN 3 2" 1-11/16" 4 2" 4 1-11/16" 4 211 4 2" 4 1-11/16" 4 1-11/16" 4 4 4 P¡¡''''''tltW<iiIlJ»'!th: TìeOft MD: W.e:UPATH DETAJ1.S P1an#2 06-2313 5{1{!;2$20MS02 ...., 90'60.0n -..-------.T.. LEGEND Rig: R6f.D:rl:UM: M ;\ Plan' Pian #2 (06-23/PJan#2 06-238) Created By: Digital Business CHent UserDa!e: 5/1812004 34, 231U11i11H!2 00:00 v,sJ5CtWtI Origm Origi" Angl.. +NI-$ +E!.W ...0 ~:::Wb REFER.ENCE INFORMATION -300 -250 -100 0 50 Vertical Section at 272.01r ObP . BP-GDB Baker Hughes INTEQ Planning Report . II.. II.ADA IUGIIIS ---"---"""""",-."""."".,..,.".,",",.,"" INl'KQ Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 06 06-23 Plan#2 06-23B Date: 5/18/2004 Time: 16:58:43 Co..ordinate(NE) Reference: Well: 06-23, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.OQN,O.00E,272.00Azí) Survey Calculation Method: Minimum Curvature Db: Oracje Field: Prudhoe Bay North Slope UNITED STATES I Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) L Sys Datum: Mean Sea Level Site: PB DS 06 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 5941880.59 ft 684674.88 ft Latitude: 70 14 Longitude: 148 30 North Reference: Grid Convergence: 46.529 N 29.224 W True 1.40 deg Well: 06-23 Slot Name: 23 06-23 Well Position: +N/-S -613.08 ft Northing: 5941299.11 ft Latitude: 70 14 40.498 N +E/-W 1280.41 ft Easting : 685969.85 ft Longitude: 148 29 51.997 W Position Uncertainty: 0.00 ft I Wellpath: Plan#2 06-23B 500292080802 Current Datum: 34: 23 10/1/1982 00:00 Magnetic Data: 5/18/2004 Field Strength: 57598 nT Vertical Section: Depth From (TVD) ft 37.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 06-23 9000.00 ft Mean Sea Level 25.33 deg 80.85 deg Direction deg 272.00 Height 74.00 ft Targets Name 06-23B Polygon2.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 06-23B T2.1 I 06-23B T2.3 I 06-23B T2.4 I 06-23B T2.5 l 06-23B T2.2 Annotation r-MD TVD ft ft 9000.00 8428.00 TIP 9068.00 8486.63 KOP 9088.00 8503.64 3 9138.00 8543.49 4 9288.00 8674.58 5 9727.99 8964.16 6 9852.99 8974.93 7 9942.99 8977.87 8 10077.99 8975.34 9 0.00 2085.57 651.85 5943400.00 686570.00 70 15 1.009 N 148 29 33.039 W 0.00 2085.57 651.85 5943400.00 686570.00 70 15 1.009 N 148 2933.039 W 0.00 2094.57 -118.21 5943390.00 685800.00 70 15 1.098 N 148 29 55.435 W 0.00 1954.97 -541.81 5943240.00 685380.00 70 14 59.725 N 148 30 7.754 W 0.00 1655.04 -549.21 5942940.00 685380.00 70 14 56.775 N 148 30 7.969 W 0.00 1794.64 -125.61 5943090.00 685800.00 70 14 58.148 N 148 29 55.650 W 0.00 1785.64 644.44 5943100.00 686570.00 70 14 58.059 N 148 29 33.256 W 8965.00 1925.31 740.93 5943242.00 686663.00 70 14 59.433 N 148 29 30.449 W 8973.00 1960.36 212.60 5943264.00 686134.00 70 14 59.778 N 148 29 45.814 W 8973.00 1890.60 -122.25 5943186.00 685801.00 70 14 59.092 N 148 29 55.552 W 8973.00 1805.32 -517.50 5943091.00 685408.00 70 14 58.253 N 148 30 7.046 W 8978.00 1932.74 521.03 5943244.00 686443.00 70 14 59.506 N 148 29 36.844 W ~ ObP e BP-GDB Baker Hughes INTEQ Planning Report . B.. IIAKEIt IIUGIIØ ÏÑTEii.----.·- Annotation 10267.99 8973.27 10 10417.99 8973.19 11 10592.99 8973.36 12 110767.99 8973.29 13 11020.00 8973.20 TO I ---------' Plan: Plan #2 Date Composed: 5/18/2004 Identical to Lamar's Plan #2 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 9000.00 30.00 49.00 8428.00 1760.34 927.07 0.00 0.00 0.00 0.00 9068.00 30.85 49.00 8486.63 1782.93 953.06 1.25 1.25 0.00 360.00 9088.00 32.65 49.00 8503.64 1789.83 961.00 9.00 9.00 0.00 0.00 9138.00 41.58 41.48 8543.49 1811.17 982.22 20.00 17.86 -15.04 330.00 9288.00 16.33 4.03 8674.58 1870.86 1017.49 20.00 -16.83 -24.97 200.00 9727.99 85.00 264.02 8964.16 1919.75 748.87 20.00 15.61 -22.73 259.00 9852.99 85.17 279.07 8974.93 1923.11 624.74 12.00 0.14 12.04 90.00 9942.99 91.09 270.03 8977.87 1930.23 535.20 12.00 6.58 -10.05 303.00 10077.99 91.05 286.23 8975.34 1949.26 402.02 12.00 -0.03 12.00 90.00 . 10267.99 90.19 263.45 8973.27 1965.18 213.96 12.00 -0.45 -11.99 268.00 10417.99 89.87 245.45 8973.19 1925.14 70.04 12.00 -0.21 -12.00 269.00 10592.99 90.02 266.45 8973.36 1882.89 -98.77 12.00 0.09 12.00 89.60 10767.99 90.02 245.45 8973.29 1840.65 -267.59 12.00 0.00 -12.00 270.00 ~020.00 90.02 275.69 8973.20 1799.84 -513.32 12.00 0.00 12.00 90.00 9000.00 30.00 49.00 8428.00 1760.34 927.07 5943081.68 686853.15 -865.07 0.00 TIP 9025.00 30.31 49.00 8449.61 1768.58 936.55 5943090.15 686862.42 -874.26 1.25 MWD 9050.00 30.63 49.00 8471.16 1776.89 946.12 5943098.70 686871.78 -883.53 1.25 MWD 9068.00 30.85 49.00 8486.63 1782.93 953.06 5943104.90 686878.57 -890.26 1.25 KOP 9075.00 31.48 49.00 8492.62 1785.31 955.79 5943107.35 686881.25 -892.90 9.00 MWD 9088.00 32.65 49.00 8503.64 1789.83 961.00 5943112.00 686886.34 -897.95 9.00 360.00 3 9100.00 34.75 46.89 8513.62 1794.29 965.94 5943116.58 686891.17 -902.73 20.00 330.00 MWD 9125.00 39.21 43.15 8533.59 1804.93 976.56 5943127.48 686901.52 -912.97 20.00 331.75 MWD 9138.00 41.58 41.48 8543.49 1811.17 982.22 5943133.85 686907.03 -918.42 20.00 334.74 4 9150.00 39.33 40.19 8552.62 1817.05 987.32 5943139.86 686911.97 -923.30 20.00 200.00 MWD 9175.00 34.70 37.04 8572.58 1828.79 996.72 5943151.83 686921.09 -932.29 20.00 200.99 MWD 9200.00 30.17 33.08 8593.68 1839.74 1004.44 5943162.97 686928.53 -939.62 20.00 203.50 MWD 9225.00 25.80 27.89 8615.75 1849.82 1010.42 5943173.19 686934.26 -945.25 20.00 206.85 MWD 9250.00 21.68 20.82 8638.63 1858.95 1014.61 5943182.42 686938.22 -949.12 20.00 211.43 MWD 9275.00 17.99 10.84 8662.15 1867.07 1016.98 5943190.59 686940.39 -951.20 20.00 217.91 MWD 9288.00 16.33 4.03 8674.58 1870.86 1017.49 5943194.39 686940.80 -951.57 20.00 227.31 5 9300.00 16.04 355.48 8686.10 1874.20 1017.47 5943197.73 686940.71 -951.44 20.00 259.00 MWD 9325.00 16.55 337.68 8710.11 1880.94 1015.85 5943204.43 686938.92 -949.58 20.00 267.22 MWD 9350.00 18.42 322.18 8733.97 1887.36 1012.07 5943210.75 686934.99 -945.59 20.00 284.30 MWD 9375.00 21.29 310.07 8757.49 1893.40 1006.17 5943216.65 686928.94 -939.48 20.00 299.10 MWD 9400.00 24.81 300.99 8780.50 1899.03 998.20 5943222.08 686920.83 -931.32 20.00 310.50 MWD 9425.00 28.76 294.14 8802.82 1904.19 988.21 5943226.99 686910.72 -921.15 20.00 318.87 MWD 9450.00 32.96 288.87 8824.28 1908.86 976.28 5943231.36 686898.67 -909.06 20.00 324.98 MWD 9475.00 37.35 284.69 8844.71 1912.98 962.50 5943235.14 686884.80 -895.15 20.00 329.51 MWD 9500.00 41.85 281.28 8863.97 1916.54 946.97 5943238.31 686869.19 -879.51 20.00 332.93 MWD 9525.00 46.44 278.43 8881.91 1919.50 929.82 5943240.85 686851.97 -862.26 20.00 335.56 MWD ObP e BP-GDB Baker Hughes INTEQ Planning Report . II.. Bf6ILn ìÑTÊÕ.---- Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 06 06-23 Plan#206-23B 9550.00 51.09 275.98 8898.38 1921.84 911.17 5943242.73 686833.27 -843.55 20.00 337.61 MWD 9575.00 55.79 273.84 8913.27 1923.55 891.17 5943243.94 686813.24 -823.50 20.00 339.22 MWD 9600.00 60.52 271.92 8926,46 1924.61 869.97 5943244,48 686792.02 -802.27 20.00 340.50 MWD 9625.00 65.27 270.18 8937.85 1925.01 847.73 5943244.33 686769.77 -780.03 20.00 341.51 MWD 9650.00 70.04 268.57 8947.35 1924.75 824.61 5943243.50 686746.67 -756.94 20.00 342.31 MWD 9675.00 74.83 267.05 8954.89 1923.83 800.80 5943242.00 686722.89 -733.17 20.00 342.92 MWD 9700.00 79.62 265.59 896Q.42 1922.27 776,48 5943239.83 686698.62 -708.92 20.00 343.38 MWD 9725.00 84,43 264.19 8963.89 1920.06 751.83 5943237.02 686674.03 -684.36 20.00 343.70 MWD 9727.99 85.00 264.02 8964.16 1919.75 748.87 5943236.64 686671.08 -681,41 20.00 343.90 6 9750.00 85.01 266.67 8966.08 1917.98 727.01 5943234.32 686649.28 -659.63 12.00 90.00 MWD 9775.00 85.02 269.68 8968.25 1917.18 702.12 5943232.92 686624,42 -634.79 12.00 89.77 MWD 9800.00 85.06 272.69 8970,4 1 1917.70 677.23 5943232.82 686599.51 -609.89 12.00 89.51 MWD 9825.00 85.10 275.70 8972.56 1919.52 652.39 5943234.03 686574.64 -585.00 12.00 89.25 MWD 9850.00 85.16 278.71 8974.68 1922.65 627.68 5943236.54 686549.86 -560.20 12.00 88.99 MWD 9852.99 85.17 279.07 8974.93 1923.11 624.74 5943236.93 686546.91 -557.24 12.00 88.73 7 9875.00 86.61 276.86 8976.51 1926.15 602.99 5943239,44 686525.10 -535,4 1 12.00 303.00 MWD 9900.00 88.26 274.34 8977.63 1928.59 578.14 5943241.26 686500.20 -510.48 12.00 303.16 MWD 9925.00 89.90 271.84 8978.03 1929.93 553.18 5943241.99 686475.22 -485,49 12.00 303.27 MWD 9942.99 91.09 270.03 8977.87 1930.23 535.20 5943241.84 686457.23 -467.51 12.00 303.31 8 9950.00 91.09 270.87 8977.74 1930.28 528.19 5943241.72 686450.22 -460.50 12.00 90.00 MWD 9975.00 91.09 273.87 8977.27 1931.32 503.22 5943242.14 686425.23 -435.51 12.00 90.02 MWD 10000.00 91.08 276.87 8976.79 1933.66 478.34 5943243.86 686400.30 -410.56 12.00 90.07 MWD 10025.00 91.07 279.87 8976.32 1937.30 453.61 5943246.89 686375.50 -385.72 12.00 90.13 MWD 10050.00 91.06 282.87 8975.86 1942.23 429.11 5943251.21 686350.88 -361.06 12.00 90.19 MWD 10075.00 91.05 285.88 8975,40 1948,43 404.90 5943256.82 686326.53 -336.65 12.00 90.24 MWD 10077.99 91.05 286.23 8975.34 1949.26 402.02 5943257.58 686323.63 -333.75 12.00 90.30 9 10100.00 90.95 283.59 8974.96 1954.92 380.76 5943262.71 686302.24 -312.30 12.00 268.00 MWD 10125.00 90.84 280.60 8974.57 1960.16 356.32 5943267.34 686277.68 -287.70 12.00 267.95 MWD 10150.00 90.73 277.60 8974.22 1964.11 331.64 5943270.69 686252.91 -262.89 12.00 267.91 MWD 10175.00 90.62 274.60 8973.93 1966.76 306.79 5943272.73 686228.00 -237.96 12.00 267.87 MWD 10200.00 90.51 271.60 8973.68 1968.12 281.83 5943273.46 686203.02 -212.97 12.00 267.83 MWD 10225.00 90.39 268.60 8973,49 1968.16 256.83 5943272.89 686178.03 -187.99 12.00 267.80 MWD 10250.00 90.27 265.61 8973.34 1966.90 231.87 5943271.01 686153.10 -163.08 12.00 267.78 MWD 10267.99 90.19 263,45 8973.27 1965.18 213.96 5943268.85 686135.25 -145.25 12.00 267.76 10 10275.00 90.17 262.61 8973.25 1964.33 207.00 5943267.83 686128.31 -138.32 12.00 269.00 MWD 10300.00 90.12 259.61 8973.18 1960,47 182.30 5943263.36 686103.72 -113.77 12.00 269.00 MWD 10325.00 90.07 256.61 8973.14 1955.32 157.84 5943257.61 686079.39 -89.51 12.00 268.99 MWD 10350.00 90.02 253.61 8973.12 1948.89 133.69 5943250.59 686055,40 -65.59 12.00 268.98 MWD 10375.00 89.96 250.61 8973.13 1941.21 109.90 5943242.33 686031.81 -42.08 12.00 268.98 MWD 10400.00 89.91 247.61 8973.16 1932.30 86.54 5943232.84 686008.69 -19.06 12.00 268.98 MWD 10417.99 89.87 245,45 8973.19 1925.14 70.04 5943225.27 685992.37 -2.82 12.00 268.99 11 10425.00 89.88 246.29 8973.21 1922.27 63.65 5943222.25 685986.05 3,48 12.00 89.60 MWD 10450.00 89.90 249.29 8973.26 1912.82 40.50 5943212.23 685963.14 26.28 12.00 89.60 MWD 10475.00 89.92 252.29 8973.30 1904.60 16.90 5943203,43 685939.75 49.58 12.00 89.59 MWD 10500.00 89.94 255.29 8973.33 1897.62 -7.11 5943195.86 685915.93 73.33 12.00 89.59 MWD 10525.00 89.96 258.29 8973.35 1891.91 -31,44 5943189.55 685891.74 97.45 12.00 89.58 MWD 10550.00 89.98 261.29 8973.36 1887,48 -56.04 5943184.52 685867.26 121.88 12.00 89.58 MWD 10575.00 90.01 264.29 8973.36 1884.34 -80.84 5943180.77 685842.54 146.56 12.00 89.58 MWD 10592.99 90.02 266,45 8973.36 1882.89 -98.77 5943178.88 685824.66 164.42 12.00 89.58 12 10600.00 90.02 265.61 8973.35 1882,41 -105.77 5943178.22 685817.68 171.40 12.00 270.00 MWD 10625.00 90.02 262.61 8973.34 1879.84 -130.63 5943175.04 685792.89 196.16 12.00 270.00 MWD 10650.00 90.02 259.61 8973.33 1875.98 -155.33 5943170.57 685768.29 220.70 12.00 270.00 MWD 10675.00 90.02 256.61 8973.32 1870.83 -179.79 5943164.82 685743.97 244.97 12.00 270.00 MWD ObP . BP-GDB Baker Hughes INTEQ Planning Report . II.. IIA....... -'-",--._.,."-,",-"",.,-,.""--~,.".",,-,,,,,"- INfEQ Company: Field: Site: Well: Wellpatb: BP Amoco Prudhoe Bay PB DS 06 06-23 Plan#2 06-23B 8973.31 1864.40 -203.95 5943157.80 685719.98 268.89 12.00 270.00 MWD 10725.00 90.02 250.61 8973.30 1856.72 -227.74 5943149.54 685696.39 292,40 12.00 269.99 MWD 10750.00 90.02 247.61 8973.29 1847.81 -251.09 5943140.05 685673.26 315,42 12.00 269.99 MWD 10767.99 90.02 245.45 8973.29 1840.65 -267.59 5943132,48 685656.95 331.66 12.00 269.99 13 10775.00 90.02 246.29 8973.29 1837.78 -273.99 5943129,46 685650.62 337.96 12.00 90.00 MWD 10800.00 90.02 249.29 8973.28 1828.33 -297.13 5943119,44 685627.72 360.76 12.00 90.00 MWD 10825.00 90.02 252.29 8973.27 1820.11 -320.74 5943110.64 685604.32 384.06 12.00 90.00 MWD 10850.00 90.02 255.29 8973.26 1813.13 -344.74 5943103.07 685580.50 407.81 12.00 90.00 MWD 10875.00 90.02 258.29 8973.25 1807,42 -369.08 5943096.76 685556.32 431.93 12.00 90.00 MWD 10900.00 90.02 261.29 8973.24 1802.99 -393.68 5943091.73 685531.83 456.36 12.00 90.00 MWD 10925.00 90.02 264.29 8973.23 1799.85 -418.48 5943087.98 685507.12 481.04 12.00 90.01 MWD 10950.00 90.02 267.29 8973.22 1798.02 -443,4 1 5943085.53 685482.24 505.89 12.00 90.01 MWD 10975.00 90.02 270.29 8973.21 1797.49 -468.40 5943084.39 685457.27 530.84 12.00 90.01 MWD 11000.00/90.02 273.29 8973.21 1798.27 -493.38 5943084.55 685432.28 555.84 12.00 90.01 MWD 11020.00 90.02 275.69 8973.20 1799.84 -513.32 5943085.63 685412.31 575.82 12.00 90.01 TO 1 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 107 "Mastercard Check" DATE 05-19 --a.¡ $ IVo, ex) -~~'-"~AHS--- First National Bank Alaska Anchorage, AK 99501 '~/)3ß MEMO ( .' ,t~ . Ii ' }{! ilu ,¡ c ') /' V1-t-e . ': jitfe:(, . I: ¡. 2 5 2000 b 0 I: ~ ~ ¡. L.III b 2 2 7 III ¡. 5 5 b II- 0 ¡. 0 7 ~;~E:IVED t 1) 2004 Alaska Oil &" · t¡8,V Can~ C . . An"h ' - OlYlmwsion {, Drage . . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME flß¿¡ 06-2-315 PTD# 26tf-ö&'7 X Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new well bore segment of LATERAL existing weD , Permit No, API No. . (If API number Production. should continue to be reponed as last two (2) digits a function 'of the original API number. stated are hetween 60-69) above. PILOT BOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the piJot bole must be dearly differentiated In both name (name on permit plus PH) .' and API :Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 MC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to tbe spacing exception that may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught aod ] 0' sample intervals through target zones. o o Well bore seg Annular Disposal On Program DEV On/Off Shore 116.50 Well Name: PRUDliOE BA Y_UI'lJT 1>6-23B. 1-01L GeoArea 890 Unit DEV . Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Initial Class/Type 640150 II'LC Permit fee attached _Leasenumberapprowi"te n_ame_and ol!mb_er WeJI JQc"ted [n_a cl.efjnedpool_ Well JQc"ted proper distance from driJling unit WeJI JQc"ted proper distance_ from otber wells in_drilliog unjt b_oundary _ _Sufficient "creag,eaYail"ble Jfdeviated Operator onl}' affected party _Operator has_appropriate_ bond in JorCE\ Permit can be iSSl!ed wjthQut conserva.tion order Permit c_an be iSSl!ed wjthQut acl.mirJÏstratilleapprovaJ Can permit L_ _WE\II'~~~'~- ,. AJIW! 15-day wait .,,_ approved before in_ commeots >-(For # (put 10# onl}')_ _ (for lojectioo Order ,....w."d within area and_strat" .authorized by_ service well only) 1[4JlJile_arE\a_of reyiew jdeo!ified (For servjce wel dur"tioRof precproduc;tion less than 3 montbs_ Pre-produ_cecl. injector _U_niqµe well Administration js. weJlbQre plat included Date 5/25/2004 Appr RPC ~ Sidetrack. CTOU 5/20/20_04. Sidetrack. Max MW8,7. ppg . MS¡::> 2390 psk TE\st to_35QO psi NA NA NA NA Yes Yes Yes Yes _Yes NA Yes Yes .Yes Yes Yes .Yes NA Consistency. has beenjssµed_ for_ this project ACMP Finding of _C90du_ctor _S_urface _casing PJotects all_known USOWs string_provided _CMT vol adeql!ateto circulate_oncond_uctor & su_rfcSg _CMT v_ol adequateto tie-inJQngstring to surf csg CMT will coyer al knownpro_dµçtiye hQri~on_s C,T, B_&p_ermafrost C.asing dE\signs ad_eQuatE\ for _Mequ"te Jtare-drilt has a_ AdequSlte wellborE\ separatio_n proposed t tan_kage_or re_serve pit tOA03 for Slbandonment beeo apprQved meet reguJations_ Jtdiverter req_uirE\d, dQes _Drilliog flujd_prog,ram schematic & equipJistadequate in _comments) (put psig , (May 84) _operatjonshl!t(own_ to _Choke_manifold cQmpJies w/API R¡::>-5~\ WQrk will occ_ur without _BOPEs,_dothey meet reguJation _B_OPEprE\ss ratiog aPpropriate; test H2S gas probable Mechan[caLcoodition of weJls within 8.0R Yerifieq (for s_ervice we) only) Js presence Qf 118 19 I ~20 I 121 122 123 124 25 26 27 Date 28 5/25/2004 ,29 30 31 32 33 34 Engineering Appr WGA No_ NA NA NA _NA Permit can be iSSl!ed wlQ hydrogen_ s_ulfide meaSMres _Data_preseoted on_ pote_ntial oveJpres_sure _zones 35 36 37 38 39 Geology Date 5/25/2004 Appr RPC Seismic_analysjs Qf sbaJlow gas_zooes reports [exploratoryonlyJ. Date .(if off-shore) .weekly progress Engineering Commissioner Seabed _condjtioo survey CQnta_ct name/p/1QneJor Date: Sf <%/~ Geologic Commissioner bTJ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility e /J.ot/w' ()g 7 $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 28 07:43:16 2004 /A,qì-- Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Previous Reel Name...... .UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........ ...... ..UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments..... ........... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 6-23B 500292080802 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 27-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003112076 S. LATZ EGBEJIMBA/HO MWD RUN 2 MW0003112076 S. LATZ KOLSTAD/HILD MWD RUN 3 MW0003112076 S. LATZ KOLSTAD/HILD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0003112076 S. LATZ KOLSTAD/HILD MWD RUN 7 MW0003112076 S. LATZ KOLSTAD/HILD MWD RUN 8 MW0003112076 S. LATZ KOLSTAD/HILD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 10N 14E 702 1008 74.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SI~ (IN) SIZE (IN) DEPTH (FT) 4.125 7.000 9068.0 e # 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 AN OPEN-HOLE, ALUMINUM WHIPSTOCK IN THE 6-23B PB1 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 9631'MD/8943'TVDSS. 4. MWD RUNS 1,2,6 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUNS 7,8 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). UPHOLE (RUNS 1 & 2) MAD EWR4 DATA ACQUIRED WHILE RIH FOR RUN 3 WERE MERGED WITH RUN 3 MWD DATA. THESE UPHOLE RUN 3 DATA ARE INCLUDED FOR THE SAKE OF COMPLETENESS, AS THE RUN 3 DRILLED INTERVAL IS NOT PART OF THE 6-23B WELL- BORE. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN ON 15 JUNE 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 18 OCTOBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1,2,6-8 REPRESENT WELL 6-23B WITH API#: 50-029-20808-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10353'MD/8961'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP $ File Header Service name....... .... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type.. ..............~ Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 e and clipped curves¡ all bit runs merged. .5000 START DEPTH 9035.0 9063.0 9063.0 9063.0 9063.0 9063.0 9072 .5 STOP DEPTH 10309.0 10322.5 10322.5 10322.5 10322.5 10322.5 10353.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 9035.0 9036.5 9039.5 9041.5 9045.0 9053.5 9058.0 9060.5 9076.0 9079.0 9081. 5 9087.5 9092.0 9099.5 9104.5 9109.0 9116.5 9125.0 9130.5 9135.0 9141. 5 9145.5 9158.5 9163.0 9167.0 9180.5 9187.0 9192.0 9199.0 9203.0 9206.5 9212.0 9216.0 9218.5 9223.0 9225.5 9227.0 9230.5 9234.0 9238.5 9246.0 9249.5 9256.0 GR 9036.5 9038.0 9040.5 9043.0 9045.5 9054.5 9059.0 9060.5 9077.0 9079.5 9082.0 9088.0 9091.5 9098.0 9105.0 9108.0 9115.5 9124.5 9130.0 9134.5 9140.5 9145.0 9159.0 9163.0 9166.0 9180.0 9186.5 9192 . 0 9198.5 9202.0 9206.5 9212.0 9215.5 9218.0 9222.5 9225.5 9227.0 9230.5 9234.0 9239.0 9246.0 9250.5 9255.5 9264.5 9269.5 9272 . 0 9279.0 9293.5 9305.0 9309.5 9313.0 9317.5 9321. 0 9325.5 9332.0 9354.5 9358.0 9365.0 9367.0 9377.0 9381. 0 9388.5 9394.5 9400.0 9409.0 9419.5 9435.0 9437.0 9443.5 9459.5 9464.0 9484.0 9503.5 9510.5 9516.0 9521.0 9532.0 9547.5 9549.5 9554.0 9567.5 9574.5 9584.5 9590.5 9599.5 9606.0 9621.5 9623.0 9629.5 9631. 5 9637.5 9640.5 9647.0 9650.0 9666.0 9670.0 9675.0 9681.5 9692.5 9699.5 9711. 5 9715.5 9724.0 9746.0 9757.0 9796.0 9804.5 9813.5 9829.0 9830.5 9837.5 9263.0e 9269.5 9271 . 0 9278.0 9293.0 9305.5 9308.5 9313.0 9317.0 9320.5 9326.0 9332.5 9355.0 9358.0 9364.5 9367.5 9377.5 9381.0 9389.0 9395.5 9401. 5 9409.5 9419.0 9435.5 9436.5 9445.5 9459.0 9464.0 9483.5 9503.0 9509.0 9515.5 9520.0 9533.0 9547.0 9548.5 9553.5 9566.5 9574.5 9584.5 9589.5 9601. 5 9607.5 9622.5 9624.5 9629.5 9632.0 9636.5 9641.0 9647.0 9652.0 9669.0 9673.5 9676.5 9683.5 9694.5 9702.5 9715.5 9719.0 9726.5 9746.5 9757.0 9795.0 9803.0 9811.5 9827.0 9829.5 9835.5 e 9849.5 9868.5 9883.0 9898.5 9922.5 9969.5 9985.5 10000.5 10010.5 10058.5 10078.5 10084.0 10105.5 10112.0 10127.0 10136.5 10147.5 10165.0 10176.5 10188.0 10203.5 10223.5 10353.5 $ 9847.5- 9865.0 9881.0 9899.0 9921. 5 9971.5 9989.0 10003.5 10010.5 10061.5 10078.5 10084.0 10104.5 10112.5 10127.0 10136.0 10146.0 10165.0 10175.5 10188.0 10203.5 10223.0 10353.0 e # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 6 7 8 MERGE TOP 9036.5 9531.0 9063.0 9631.5 9700.0 10025.0 MERGE BASE 9531. 0 9631.5 9621.5 9700.0 10025.0 10353.0 # REMARKS: MERGED MAIN PASS. $ # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9035 10353.5 9694.25 2638 9035 10353.5 ROP MWD FT/H 0.34 657.72 80.6026 2563 9072.5 10353.5 GR MWD API 15.9 772.2 42.1535 2549 9035 10309 RPX MWD OHMM 1. 85 2000 17.0266 2520 9063 10322.5 RPS MWD OHMM 1.76- 168.07 22.7922 2520 e 9063 10322.5 RPM MWD OHMM 1. 88 179.42 26.9785 2520 9063 10322.5 RPD MWD OHMM 2.15 2000 45.928 2520 9063 10322.5 FET MWD HOUR 0.21 89.17 12.9463 2520 9063 10322.5 First Reading For Entire File.... ..... .9035 Last Reading For Entire File.... .......10353.5 File Trailer Service name........ .....STSLIB.001 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation. ... ...04/10/28 Maximum Physical Record..65535 File 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. 1 .5000 START DEPTH 9036.5 9073.5 STOP DEPTH 9500.5 9531.0 # 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: 09-JUN-04 Insite 7.75 Memory 9529.0 9072 . 0 9529.0 14 .6 40.2 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG011 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9068.0 # e 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..................O Data Specification Block Type. ....0 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 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code e Flo Pro 8.80 65.0 9.0 35000 6.0 .000 .000 .000 .000 .0 137.5 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9036.5 9531 9283.75 990 9036.5 9531 ROP MWD010 FT/H 0.85 217.41 53.9087 916 9073.5 9531 GR MWD010 API 16.28 772 .2 61.6058 929 9036.5 9500.5 First Reading For Entire File..... .... .9036.5 Last Reading For Entire File...... .... .9531 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .... .04/10/28 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF e File Header Service name... ......... .STSLIB.003 Service Sub Level Name. . . Version Number..... .... ..1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type.......... .... ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 9501. 0 9531.5 STOP DEPTH 9600.5 9631. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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: 09-JUN-04 Insite 7.75 Memory 9645.0 9529.0 9645.0 45.7 84.6 TOOL NUMBER TLGOll 4.250 9068.0 Flo Pro 8.80 65.0 9.0 35000 6.0 .000 .000 .000 .000 .0 142.0 .0 .0 $ e e # 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 .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 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9501 9631.5 9566.25 262 9501 9631.5 ROP MWD020 FT/H 15 95.19 61.2576 201 9531. 5 9631.5 GR MWD020 API 17.39 47.72 23.9747 200 9501 9600.5 First Reading For Entire File......... .9501 Last Reading For Entire File... ..... ...9631.5 File Trailer Service name....... .... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record..65535 File Type. ............ ...LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type....... ........ .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPM RPS RPX 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9063.0 9063.0 9063.0 9063.0 STOP DEPTH 9621.5 9621.5 9621. 5 9621.5 RPD $ 9063. _ 9621.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE EWR4 $ BOTTOM) TOOL TYPE ELECTROMAG. RESIS. # 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 value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 e 10-JUN-04 Insite 4.3 Memory 9622.0 9063.0 9622.0 86.2 95.8 TOOL NUMBER 171170 4.125 9068.0 Flo Pro 8.80 65.0 8.5 35000 5.0 .200 .000 .180 .250 65.0 141. 0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD030 OHMM 4 1 68 4 2 RPS MWD030 OHMM 4 1 68 8 3 RPM MWD030 OHMM 4 1 68 12 4 RPD MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR tt 1 68 20 e 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9063 9621.5 9342.25 1118 9063 9621. 5 RPX MWD030 OHMM 1. 85 113 23.5344 1118 9063 9621. 5 RPS MWD030 OHMM 1. 76 168.07 37.6807 1118 9063 9621. 5 RPM MWD030 OHMM 1. 88 179.42 45.5994 1118 9063 9621.5 RPD MWD030 OHMM 2.15 2000 84.9738 1118 9063 9621.5 FET MWD030 HOUR 13 .55 36.55 25.2134 1118 9063 9621.5 First Reading For Entire File. ..... ... .9063 Last Reading For Entire File... .... ... .9621.5 File Trailer Service name. ........... .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ... .04/10/28 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 GR ROP $ 5 header data for each bit run in separate files. 6 .5000 START DEPTH 9601.0 9632.0 STOP DEPTH 9669.5 9700.0 # 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: 12-JUN-04 Insite 7.75 Memory 9700.0 9645.0 9700.0 68.9 79.4 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTT. 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... ..0 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 Name Service Order DEPT ROP MWD060 GR MWD060 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code e TOOL NUMBER TLG011 3.750 9068.0 Flo Pro 8.60 65.0 9.3 25000 10.8 .000 .000 .000 .000 .0 141. 0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9601 9700 9650.5 199 9601 9700 ROP MWD060 FT/H 0.34 247.87 113 . 724 137 9632 9700 GR MWD060 API 18.86 75.48 33.9221 138 9601 9669.5 First Reading For Entire File.... ..... .9601 Last Reading For Entire File.... .......9700 File Trailer Service name. ........... .STSLIB.005 Service Sub Level Name. . . Version Number..... ..... .1.0.0 Date of Generation... ....04/10/28 Maximum Physical Record..~35 File Type.......... .... ..LO Next File Name..... ......STSLIB.006 e Physical EOF File Header Service name........ .... .STSLIB.006 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ... .04/10/28 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM FET RPD GR ROP $ 6 header data for each bit run in separate files. 7 .5000 START DEPTH 9622.0 9622.0 9622.0 9622.0 9622.0 9670.0 9700.5 STOP DEPTH 9994.0 9994.0 9994.0 9994.0 9994.0 9980.0 10025.0 # 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: 13-JUN-04 Insite 4.3 Memory 10025.0 9700.0 10025.0 87.3 90.8 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 TOOL NUMBER 78012 171170 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9068.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) Flo Pro 8.60 65.0 9.0 25000 7.8 MUD MUD MUD MUD AT MEASURED TEJltRATURE (MT): AT MAX CIRCULATING TERMPERATURE: FILTRATE AT MT: CAKE AT MT: .190 .000 .160 .200 _0 .0 69.0 69.0 # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9622 10025 9823.5 807 9622 10025 ROP MWD070 FT/H 0.38 657.72 88.8797 650 9700.5 10025 GR MWD070 API 15.9 59.77 31.8937 621 9670 9980 RPX MWD070 OHMM 3.88 2000 15.4411 745 9622 9994 RPS MWD070 OHMM 4.48 30.2 13.0355 745 9622 9994 RPM MWD070 OHMM 5 36.32 14.4558 745 9622 9994 RPD MWD070 OHMM 7.47 41.52 17.7448 745 9622 9994 FET MWD070 HOUR 0.25 89.17 4.68585 745 9622 9994 First Reading For Entire File......... .9622 Last Reading For Entire File.... .......10025 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record. .65535 File Type.. ............ ..LO Next File Name.......... .STSLIB.007 Physical EOF - File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...04/10/28 Maximum Physical Record..65535 File Type............... .LO Previous File Name.. .....STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 7 e header data for each bit run in separate files. 8 .5000 START DEPTH 9980.5 9994.5 9994.5 9994.5 9994.5 9994.5 10025.5 STOP DEPTH 10308.5 10322.0 10322.0 10322.0 10322.0 10322.0 10353.0 # 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 EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTRO MAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 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: 14-JUN-04 Insite 4.3 Memory 10353.0 10025.0 10353.0 87.8 93.3 TOOL NUMBER 78012 171170 3.750 9068.0 FIo Pro 8.60 65.0 9.0 24000 6.8 .170 .080 .180 .160 69.0 147.1 69.0 69.0 MATRIX DENSITY: HOLE CORRECTION (IN): e e # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type... ..0 Logging Direction.. .... .......... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.. ................ ...60 .1IN Max frames per record........ .....Undefined Absent value. ............... ... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9980.5 10353 10166.8 746 9980.5 10353 ROP MWD080 FT/H 0.77 425.17 108.239 656 10025.5 10353 GR MWD080 API 21.58 37.56 28.805 657 9980.5 10308.5 RPX MWD080 OHMM 4.67 24.5 7.7487 656 9994.5 10322 RPS MWD080 OHMM 5.17 22.2 8.74221 656 9994.5 10322 RPM MWD080 OHMM 5.61 21. 46 9.70076 656 9994.5 10322 RPD MWD080 OHMM 8.92 19.23 13.3512 656 9994.5 10322 FET MWD080 HOUR 0.21 11.2 1.34852 656 9994.5 10322 First Reading For Entire File.. ....... .9980.5 Last Reading For Entire File. ..... .....10353 File Trailer Service name.... ........ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.. ........ .~KNOWN 4IÞ Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name....... ........ .UNKNOWN Continuation Number..... .01 Next Reel Name.. ........ .UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Dri~ng Services LIS Scan Utility e ~tJf~og 7 $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 28 08:22:32 2004 # / ¡ t 9) Reel Header Service name....... ..... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number. ... ..01 Previous Reel Name.. .....UNKNOWN Comments............ .....STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ....UNKNOWN Continuation Number... ...01 Previous Tape Name... ....UNKNOWN Comments..... ........ ....STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 6-23Bpbl 500292080870 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 28-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003112076 S. LATZ EGBEJIMBA/HO MWD RUN 2 MW0003112076 S. LATZ KOLSTAD/HILD MWD RUN 3 MW0003112076 S. LATZ KOLSTAD/HILD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003112076 S. LATZ KOLSTAD/HILD MWD RUN 5 MW0003112076 S. LATZ KOLSTAD. HILD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 ION 14E 702 1008 MSL 0) 74.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT SItIÞ (IN) 4.125 SIZE (IN) DEPTH (FT) 7.000 9068.0 e # 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 6-23A WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 9056'MD/8476'TVDSS¡ THE BOTTOM WAS AT 9063'MD/8482'TVD. 4. MWD RUNS 1,2,4 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUNS 3,5 COMPRISED DIRECTIONAL¡ DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS¡ AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). UPHOLE MAD EWR4 DATA ACQUIRED WHILE RIH FOR RUN 3 WERE MERGED WITH RUN 3 MWD DATA. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN ON 15 JUNE 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 18 OCTOBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 5 REPRESENT WELL 6-23B PB1 WITH API#: 50-029-20808-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10603'MD/8966'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.... ...04/10/28 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 FET RPD RPM RPS RPX ROP $ e e 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9035.0 9063.0 9063.0 9063.0 9063.0 9063.0 9072 .5 STOP DEPTH 10559.0 10572 .5 10572.5 10572.5 10572.5 10572.5 10604.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 9035.0 9036.5 9039.5 9041. 5 9045.0 9053.5 9058.0 9060.5 9076.0 9079.0 9081.5 9087.5 9092.0 9099.5 9104.5 9109.0 9116.5 9125.0 9130.5 9135.0 9141. 5 9145.5 9158.5 9163.0 9167.0 9180.5 9187.0 9192.0 9199.0 9203.0 9206.5 9212.0 9216.0 9218.5 9223.0 9225.5 9227.0 9230.5 9234.0 9238.5 9246.0 9256.0 92 64.5 9269.5 9272 . 0 GR 9036.5 9038.0 9040.5 9043.0 9045.5 9054.5 9059.0 9060.5 9077 . 0 9079.5 9082.0 9088.0 9091. 5 9098.0 9105.0 9108.0 9115.5 9124.5 913 0.0 9134.5 9140.5 9145.0 9159.0 9163.0 9166.0 9180.0 9186.5 9192.0 9198.5 9202.0 9206.5 9212.0 9215.5 9218.0 9222.5 9225.5 9227.0 9230.5 9234.0 9239.0 9246.0 9255.5 9263.0 9269.5 9271.0 9279.0 9293.5 9305.0 9309.5 9313.0 9317.5 9321. 0 9325.5 9332.0 9354.5 9358.0 9365.0 9367.0 9377.0 9381. 0 9388.5 9394.5 9400.0 9409.0 9419.5 9435.0 9437.0 9443.5 9459.5 9464.0 9484.0 9503.5 9510.5 9516.0 9521.0 9532.0 9547.5 9549.5 9554.0 9567.5 9574.5 9584.5 9590.5 9605.5 9623.0 9628.5 9633.5 9640.5 9644.0 10604.0 $ 9278.0- 9293.0 9305.5 9308.5 9313.0 9317.0 9320.5 9326.0 9332.5 9355.0 9358.0 9364.5 9367.5 9377.5 9381.0 9389.0 9395.5 9401. 5 9409.5 9419.0 9435.5 9436.5 9445.5 9459.0 9464.0 9483.5 9503.0 9509.0 9515.5 9520.0 9533.0 9547.0 9548.5 9553.5 9566.5 9574.5 9584.5 9589.5 9606.0 9623.5 9628.5 9632.5 9639.5 9643.0 10603.0 _ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 5 MERGE TOP 9036.5 9531. 0 9779.0 10247.0 10400.0 MERGE BASE 9531. 0 9779.0 10247.0 10400.0 10603.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.................... ..-999 Depth Units.................... . e Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9035 10604 9819.5 3139 9035 10604 ROP MWD FT/H 0.17 2306.23 71.6756 3064 9072.5 10604 GR MWD API 16.28 772.2 55.4126 3049 9035 10559 RPX MWD OHMM 1. 85 113 15.6863 3020 9063 10572.5 RPS MWD OHMM 1. 76 168.07 21.2086 3020 9063 10572.5 RPM MWD OHMM 1. 88 179.42 24.4781 3020 9063 10572.5 RPD MWD OHMM 2.15 2000 39.4184 3020 9063 10572.5 FET MWD HOUR 0.24 36.55 12.5268 3020 9063 10572 .5 First Reading For Entire File......... .9035 Last Reading For Entire File.......... .10604 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation.. .....04/10/28 Maximum Physical Record..65535 File Type......... ..... ..LO Next File Name..... .... ..STSLIB.002 Physical EOF File Header Service name.. ......... ..STSLIB.002 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.. .....04/10/28 Maximum Physical Record..65535 File 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. 1 .5000 START DEPTH 9036.5 9073.5 STOP DEPTH 9500.5 9531. 0 # LOG HEADER DATA e 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.. ...0 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. ..0 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Name Service Unit DEPT FT Min 9036.5 Max 9531 09-JUN-04 Insite 7.75 Memory 9529.0 9072.0 9529.0 14 .6 40.2 TOOL NUMBER TLG011 4.125 9068.0 Flo Pro 8.80 65.0 9.0 35000 6.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 Mean Nsam 9283.75 990 e .0 137.5 .0 .0 First Reading 9036.5 Last Reading 9531 ROP MWDOI0 FT/H GR MWDOI0 API 0.85- 16.28 217.41 772 .2 53.9087 61.6058 916 929 ~073. 5 9036.5 9531 9500.5 First Reading For Entire File......... .9036.5 Last Reading For Entire File....... ....9531 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/10/28 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...... .04/10/28 Maximum Physical Record..65535 File Type............ ....LO Previous File Name... ....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9501.0 9531. 5 STOP DEPTH 9749.0 9779.0 # 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: 09-JUN-04 Insite 7.75 Memory 9779.0 9529.0 9779.0 45.7 84.6 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLGOll # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.250 9068.0 # 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: e Flo Pro 8.80 65.0 9.0 35000 6.0 e .000 .000 .000 .000 .0 142.0 .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. ....0 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 Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9501 9779 9640 557 9501 9779 ROP MWD020 FT/H 0.17 2306.23 61.932 496 9531.5 9779 GR MWD020 API 17.39 174.54 36.0183 497 9501 9749 First Reading For Entire File.. ....... .9501 Last Reading For Entire File. ... ... ....9779 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.004 Physical EOF File Header Service name......... ... .STSLIB.004 Service Sub Level Name. . .- Version Number....... ....1.0.0 Date of Generation.. .....04/10/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 4 _ header data for each bit run in separate files. 3 .5000 START DEPTH 9063.0 9063.0 9063.0 9063.0 9063.0 9749.5 9779.5 STOP DEPTH 10219.0 10219.0 10219.0 10219.0 10219.0 10205.0 10247.0 # 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 EWR4 $ BOTTOM) TOOL TYPE Dual GR Electromag. Resist. # 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): # 10-JUN-04 Insite 4.3 Memory 10247.0 9779.0 10247.0 86.2 95.8 TOOL NUMBER 78012 158428 4.250 9068.0 Flo Pro 8.80 65.0 8.5 35000 5.0 .200 .000 .180 .250 65.0 141.0 65.0 65.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): e e # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9063 10247 9655 2369 9063 10247 ROP MWD030 FT/H 0.67 738.03 93.8436 936 9779.5 10247 GR MWD030 API 24.39 117.42 51.9257 912 9749.5 10205 RPX MWD030 OHMM 1. 85 113 16.9956 2313 9063 10219 RPS MWD030 OHMM 1. 76 168.07 24.0692 2313 9063 10219 RPM MWD030 OHMM 1. 88 179.42 28.1144 2313 9063 10219 RPD MWD030 OHMM 2.15 2000 47.723 2313 9063 10219 FET MWD030 HOUR 0.24 36.55 14.0422 2313 9063 10219 First Reading For Entire File.... .... ..9063 Last Reading For Entire File.. ........ .10247 File Trailer Service name......... ....STSLIB.004 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record..65535 File Type.............. ..LO Next File Name......... ..STSLIB.005 Physical EOF File Header Service name.. ......... ..STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/10/28 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 GR ROP $ e 5 e header data for each bit run in separate files. 4 .5000 START DEPTH 10205.5 10247.5 STOP DEPTH 10371.0 10400.0 # 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..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units..... .... ..Feet Data Reference Point. ............ .Undefined Frame Spacing.................... .60 .1IN 11-JUN-04 Insite 7.75 Memory 10400.0 10247.0 10400.0 89.6 91.1 TOOL NUMBER TLGOl1 4.250 9068.0 Flo Pro 8.70 65.0 9.0 23000 6.6 .000 .000 .000 .000 .0 150.1 .0 .0 e Max frames per record.......... .Undefined Absent value............... .... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Nsam 1 1 1 Units FT FT/H API Size 4 4 4 MWD040 MWD040 Rep 68 68 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10205.5 10400 10302.8 390 10205.5 10400 ROP MWD040 FT/H 2.41 152.19 68.307 306 10247.5 10400 GR MWD040 API 30.35 126.34 62.3604 332 10205.5 10371 First Reading For Entire File.. .... ....10205.5 Last Reading For Entire File.......... .10400 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record..65535 File Type............... .LO Next File Name... ....... .STSLIB.006 Physical EOF File Header Service name......... ....STSLIB.006 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation..... ..04/10/28 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name.... ...STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 10219.5 10219.5 10219.5 10219.5 10219.5 10371. 5 10400.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: STOP DEPTH 10571.5 10571.5 10571. 5 10571. 5 10571.5 10558.0 10603.0 11-JUN-04 Insite VERS. : REAL-TIME) : DOWNHOLE SOFTWARE DATA TYPE (MEMORY OR TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR Electromag. Resist. # 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... ..0 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 4.3 Memory 10603.0 10400.0 10603.0 e 90.4 94.3 TOOL NUMBER 78012 158428 4.250 9068.0 Flo Pro 8.60 65.0 9.3 25000 10.8 .200 .090 .180 .250 65.0 147.1 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 e 'rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10219.5 10603 10411.3 768 10219.5 10603 ROP MWD050 FT/H 1.4 527.52 75.6996 406 10400.5 10603 GR MWD050 API 19.32 172 . 86 63.7133 374 10371.5 10558 RPX MWD050 OHMM 3.33 27.15 11.4281 705 10219.5 10571. 5 RPS MWD050 OHMM 4.07 26.57 12.0588 705 10219.5 10571. 5 RPM MWD050 OHMM 4.32 26.78 12.7405 705 10219.5 10571.5 RPD MWD050 OHMM 6.7 25.79 13.9017 705 10219.5 10571.5 FET MWD050 HOUR 0.35 28.72 7.55591 705 10219.5 10571.5 First Reading For Entire File..... .....10219.5 Last Reading For Entire File.. ..... ....10603 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .04/10/28 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.... ...... .STSLIB.007 Physical EOF Tape Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number.. ....01 Next Tape Name..... .... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... .... ........ .UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File