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195-213
STATE OF ALASKA ALASKA ~AND GAS CONSERVATION COMMI ION ~~~~~~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Plugged ~ Abandoned ^ Suspended zonnc zs.~os 2awc zs.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. ofCompletions Zero 1b. ~ • ~ Developme~~~ ~loratory ^ Service ~S~ratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: 9/23/2009 12. Permit to Drill Number: 195-213 309-289 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 01/23/1996 13. API Number: 50-029-21556-01-00 4a. Location of Well (Govemmental Section): Surface: ' ' 7. Date T.D. Reached: 09/29/1996 14. Well Name and Number: PBU D-28A 1496 FNL, 1692 FEL, SEC. 23, T11 N, R13E, UM Top of Produciive Horizon: 2613' FSL, 1850' FEL, SEC. 14, T11 N, R13E, UM g. KB (ft above MSL): 78.66 GL (ft above MSL): 41.71' 15. Field / Pool(s): Prudhoe Ba Field / Prudhoe Ba Y Y Total Depth: 3804' FSL, 2075' FEL, SEC. 14, T11N, R13E, UM 9. Plug Back Depth (MD+7~/p~: 11320' 9035' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 653458 y_ 5959492 Zone- ASP4 1: Total Depth (MD+'1~/D): 11866' 9027' ~f!6. Property Designation: ADL 028285 TPI: x- 653213 y- 5963597 Zone- ASP4 Total Depth: x- 652962 Y- 5964784 Zone- ASP4 11 • SSSV Depth (MD+ND): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ~ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071 j: GR, RES, DIR / FE 22. Re-Dril!/Latera! Top Window MDlND: 10075' (D-28A) 8555' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETfING DEPTH ND HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTfOM SIZE CEMENTING RECORD PULLEQ " x 20" Ins la d Cond or urFace 110' S rf 11 ' 2" Concrete 7 17-1 P rm " 4 9- /" 47# L- Surface 88 ' S rf 84 7' 12-1/4" 57 Clas 'G' 7" 9# L- 9' ' 82 ' -1/2" 4 lass'G' - / " 1 11, ' 24. Open to production or inj,ection? ,,.,,,._Q_Yes ~ No 25. TueiNC Recorto If Yes, IISt @8CI1 If1t@N8I Op@Il (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD I ND 4-1/2", 12.6#, L-80 9538' 9480' / 8177' MD ND MD ND 26. ACID, FRACTURE,'CEMENT SQUEEZE, ETC. , ~~y~s~~ ~~ ~ f ~~~y~~~ DEPTH INTERVAL (MD AMOUNTAND KIND OF MATERIAL USED ~~ ~ e~ r ~~~~s~~ ~' 11320' SetWhipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOI~ SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate • OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORR~: 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ~ No Sidewall Core(s) Acquired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+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 Form 10-407 Revised 07/2009 CONTINUED ON REVERSE ~ /D,13°O y '~ ~ Submit Original Only ~ ~/~'~~ 29. GEOLOGIC MARKERS (List all formations and m encountered): 30. RMATION TESTS NAME MD ND 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. Sadlerochit 10046' 8537' None Zone 3 10281' 8705' Zone 2C 10396' 8797' Zone 26 10430' 8825' Zone 2A 10640' 8981' Zone 1 B 10742' 9027' Formation at Total Depth (Name): 31. List ofAttachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certiy that the foregoing is true and correct to the best of my knowledge. ' D ~~ • Title: Drilling Technologist Date: ( Signed: Terrie Hubble 1 PBU D-28A 195-213 309-289 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Iog on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-APtemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. MuRiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemerttal recorcJs for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 7, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding fortnation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only • • D-28A & D-28AL1, Well History (Pre Rig Sidetrack) Date Summary 6/4/2009 T/I/0=2450/ 125/0 Temp=S/I MIT-IA passed to 3000 psi, MIT-OA passed to 2000 psi. Pressured up IA to 3000 psi w/ 15.9 bbls crude. MITIA lost 60 psi in 15 minutes and 20 psi in second 15 minutes for a 30 minute loss of 80 psi. Bled IAP (10 bbls all fluid). 6/8/2009 WELL FLOWING ON ARRIVAL. DRIFT W/ 3.84" NO-GO CENT TO 2158' SLM / 2118' MD. WELL LEFT S/I. DSO NOTIFIED. JOB NOT COMPLETE CALLED OFF TO ASSIST COIL. 6/9/2009 WELL S/I ON ARRIVAL. BRUSHED SVLN C~ 2158' SLM. SET 4-1/2" DSSSV PLUG BODY @ 2158' SLM. SET P-PRONG Q 2154' SLM. BLED TBG DOWN FROM 2200 PSI TO 500 PSI, GOOD TEST. WELL LEFT S/I, JOB COMPLETE. 6/10/2009 T/I/O = 630/50NAC. Temp = SI. OART (eval IAxOA). ALP = 340 psi. AL SI C~ casing valve and skid. AL system is down. Tbg FL C~ 2010'. IA FL @ 42'. OA FL near surface. Pressured up IA from 50 psi to 1000 psi using gas from D-22 Tbg. Out of time, no monitor. Tags placed on IA & OA. McAvoy wellhead with internal checks. Final WHPs = 630/1000/VAC. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 6/11/2009 T/I/O = 750/880/VAC. Temp = SI. OART (day 1). AL connected, SI C~ casing valve. ALP = 300 psi. TP increased 120 psi, IAP decreased 120 psi, OAP unchanged overnight. SV, WV = Shut. SSV, MV - Open. IA & OA = OTG. NOVP. 6/12/2009 T/I/0= 780/840/VAC. Temp= SI. OART (day 2). AL SI C~ CSG. ALP= 270 psi. TP increased 30 psi, IAP decreased 40 psi, OAP unchanged, ALP decreased 30 psi overnight. SV, WV = C. SSV, MV - O. IA, OA = OTG. NOVP. 6/13/2009 T/I/0= 780/810/VAC. Temp- SI. OART (day 3). TP unchanged, IAP decreased 30 psi, OAP unchanged overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 6/14/2009 T/I/0=780/780Nac. Temp=Sl. OART (day 4). AL SI and blinded C~3 casing valve. ALP=200 psi. IAP decreased 30 psi overnight. TP and OAP unchanged. tA FL 120'. Removed OART tags from IA and OA. SV, W V= closed. SSV, MV =o pen. IA, OA = OTG. NOVP. 6/14/2009 T/I/0=780/780/Vac. SI. Bleed T and IAP to 0 psi (pre-PPPOT/CTD screen). AL SI and blinded C~ casing valve. ALP=200 psi. TBG FL 2010', will need UR to bleed. IA FL C~3 120'. Bled IAP from 780 psi to 0 psi in 1.5 hrs (all gas). Post bleed IA FL rose 60'. Monitor for 30 mins. Post monitor IAP increased to 0+. TP and OAP unchanged. Final WHP's = 780/0/Vac. SV, WV - closed. SSV, MV = open. IA, OA = OTG. NOVP. 6/15/2009 T/I/O = 790/10NAC. Temp = SI. Bleed T and IAP to 0 psi (pre-PPPOT/CTD screen). ALP = 200 psi. AL SI C~ casing valve. TP increased 10 psi & IAP increased 10 psi overnight. Tbg FL C«~ 2010'. IA FL C~ 42'. Bled IAP from 10 psi to 0 psi in 2 mins (all gas). Bled TP from 790 psi to 0 psi in 50 mins. Monitored for 30 mins. TP increased to 8 psi & IAP increased to 3 psi. Final WHPs = 8/3/VAC. SV, WV = Closed. SSV, MV = Open. IA & OA - OTG. NOVP. 6/16/2009 T/I/0=0+/0+/0, Temp=Sl. PPPOT-T (PASS), CTD screen. PPPOT-T: Opened slotted bleeder screw to verify 0 psi in test void, bled to 0 psi. Removed internal check and installed external Alemite check. Functioned LDS (standard), all moved freely (2"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 6/16/2009 T/I/O = 140/10/VAC. Temp = SI. Bleed T and IAP to 0 psi (pre-PPPOT/CTD screen). ALP = 200 psi. AL SI @ casing valve. Tbg FL C 2010'. IA FL C«? 42'. Bled IAP from 10 psi to 0 psi in 2 mins. Bled TP from 140 psi to 0 psi in 1 hour 45 mins. Monitored for 30 mins. TP increased to 8 psi & IAP increased to 3 psi. Final WHPs = 8/3NAC. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. Page 1 of 2 • • D-28A & D-28AL1, Well History (Pre Rig Sidetrack) Date Summary 6/20/2009 T/I/0=100/60/Vac Temp=Sl Assist Slickline, Load Tbg (CTD Screen) Pumped 5 bbis meth, 30 bbls diesel down Tbg to load. Final WHPs = 100/60/Vac. WV, SV, SSV = Shut. MV, IA, OA = Open. 6/21/2009 WELL S/I ON ARRIVAL, SSV DUMPED. (Ctd screening) PULLED 4 1/2" "PX" PLUG FROM SVLN Q 2,158' SLM. NOTIFIED PAD OP. OF VALVE POSITIONS. RETURNED WELL TO THE PAD OP. OK TO POP. 8/26/2009 Per Rig Pressure test to 5000 PSI Master to Wing (Passed ) Down on Swab to 5000 PSI (Passed) 8/30/2009 Rig up unit. Attempt to perform weekly BOP test, Swab valve would not hoid, MU additional swab to top of tree. 8/31/2009 Continue rigging up unit after RU crew stacked swab valves. Conduct BOP test. Good test. MU BOT BHA w/18' - 3.63" dummy drift. RIH to 11350 without any restrictions. Pooh. RIH w/ IGS smart tool to 10700. Log up/down C~ various pump rate and pipe speeds. Could only get data on down passes after multiple attempts. Pooh. FP well w/ 37 bbls 50/50 meth. Job complete. 9/8/2009 T/I/O = 0/0/0 Pulled old swab valve and put on a new Cameron FLS swab valve . P/T to 5,000# PASS. 9/14/2009 WELL S/I ON ARRIVAL. RAN 3.805" GAUGE RING, 4-1/2" BRUSH TO SVLN C~? 2163' SLM W/ NO RESTRICTIONS. SET 4-1/2" DSSSV PLUG BODY (4 x 3/16" eq-ports, 3 sets of pkg) IN SVLN C 2163' SLM. OBTAINED CONTROL / BALANCE LINE INTEGRITY, BOTH LINES BLED TO Opsi. SET P- PRONG IN DSSSV PLUG BODY C«~ 2163' SLM (top of prong C~ 2160' slm). BLED TBG DOWN FROM 1850 psi TO 850 psi. HOLDING DIFFERENTIAL. RDMO,LEFT WELL SHUT IN,PAD OP NOTIFIED. 9/15/2009 T/I/0=200/0/0. 875# on tubing at arrival. Bled tubing to 200#. Set 6-3/8" CIW J TWC #419 thru tree, pre tree c/o & flow ~ine removal for Nordic. 1-2' ext used, tagged C~ 108". Would not bleed off. Pulled TWC & attempted to set CIW J BPV #422, but could not find anti-rotational slot in profile. Possibly hydrates? 9/15/2009 T/I/0=200/100/0 MIT T to 3000 psi (Pre CTD & tree Replacement) Pump 34 bbls crude down tbg to pressure up. MIT T passed 3rd attempt. Lost 140 psi 1st 15 min, 60 psi nd 15 min. FWHP's = 100/100/0 SV, SSV, WV, MV = S/I; IA, OA = OTG tags hung pad op notified. 9/15/2009 T/I/0=150/100/0. Set 6-3/8" CIW J TV11C #417 thru tree. Pre tree C/O. Pre Nordic 2. 1-2' ext used, tagged C~3 108". No problems. 9/17/2009 T/I/O = 100/100/0 Removed 6" Mcevoy tree and replaced with New Cameron 6" FLS with Baker C actuator. PT to 5k (PASS). Pulled Cameron type "J" TWC, tagged C~ 118" using one 2' extension. 9/18/2009 ARRIVE ON LOC WELL S/I. R/U EQUIPMENT RIH W/ 3.7 BG.W/ 2 1/2 JDC PULLED PRONG FROM 2160' SLM (2188' MD). PULL 3.813" DSSSV PLUG & PRONG FROM SVLN C~ 2162 SLM (2188' MD). JOB COMPLETED TURN WELL OVER TO DSO. 9/19/2009 T/I/O=SSV/60/0. Temp=Sl. W HPs, bleed IAP to 0 psi (CTD). No F/L, or AL. IA FL near surface. Bled IAP from 60 psi to 0 psi in 10 min. Monitor 30 min. Final WHPs=SSV/0+/0+. SV, WV, SSV, MV = Closed. IA & OA = OTG. NOVP. 9/20/2009 T/I/0= 1900/0/0 Temp= SI Load and Kill (Pre CTD). Pumped 5 bbls 60/40 meth, 290 bbls seawater followed by 40 bbls 60/40 meth for freeze protect. Final WHPs Vac/20/0. WV, SV, SSV = Shut; MV, IA, OA = Open. Page 2 of 2 i • BP EXPLORaTION Operatic~:ns Summary Report Legal Well Name: D-28 Common Well Name: D-28 Spud Date: 3/2/1986 Event Name: REENTER+COMPLETE Start: 9/2/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Gode NPT Phase Description of Operations 9/21/2009 12:30 - 14:00 1.50 MOB P PRE PREP TO MOVE OFF, SECURE BOP STACK, TIE OFF CSH AND RD HAND-Y-BERM 14:00 - 14:30 0.50 MOB P PRE MOVE OFF WELL AND SET DOWN 14:30 - 16:00 1.50 MOB P PRE TRANSFER BOP STACK TO BRIDGE CRANE 16:00 - 17:30 1.50 MOB P PRE SCOPE DOWN DERRICK AND SECURE 17:30 - 18:00 0.50 MOB P PRE CREW CHANGE OUT AND PJSMS FOR MOVING RIG TO D-PAD 18:00 - 20:00 2.00 MOB N WAIT PRE WAIT ON SECURITY FOR RIG MOVE 20:00 - 20:15 0.25 MOB P PRE PJSM WITH SECURITY FOR RIG MOVE 20:15 - 22:30 2.25 MOB P PRE MOVE FROM C-PAD TO D-PAD VIA K-PAD ROAD UNDER TWIN TOWERS TO SPINE ROAD 22:30 - 00:00 1.50 MOB P PRE MOVE PIPE BUNKS AND RIG MATS SO THAT RIG CAN MAKE IT AROUND CORNER OF PAD 9/22/2009 00:00 - 00:20 0.33 MOB P PRE PJSM FOR CUTTING AND LD HERCULITE (WINDS +40 MPH) 00:20 - 04:00 3.67 MOB P PRE CUT AND LD HERCULITE FOR CELLAR, LD RIG MATS 04:00 - 04:15 025 MOB P PRE PJSM FOR BACKING ONTO WELL 04:15 - 06:00 1.75 MOB P PRE VERIFY 0 PSI ON WH AND BACK RIG ONTO WELL 06:00 - 06:15 0.25 MOB P PRE ACCEPT RIG ~ 06:00 PJSM FOR NU OF BOPE & PU REEL INTO REEL HOUSE 06:15 - 13:00 6.75 BOPSU P PRE NU BOPE PU REEL INTO REEL HOUSE 13:00 - 14:00 1 AO BOPSU P PRE FILI. STACK & SHELL TEST. 14:00 - 22:00 8.00 BOPSU P PRE TEST BOPE PER AOGCC REGS, 250PSI/3500PSI. CHUCK 22:00 - 22:30 0.50 BOPSUi~ P 22:30 - 00:00 1.50 BOPSUF~ P 9/23/2009 100:00 - 01:15 I 1.251 BOPSUFI P 01:15 - 01:30 0.25 RIGU P 01:30 - 04:15 2.75 RIGU P 04:15 - 05:00 0.75 BOPSU P 05:00 - 0520 0.33 RIGU P 05:20 - 07:15 I 1.921 RIGU I P 07:15 - 09:15 2.00 RIGU P 09:15 - 10:00 0.75 STWHIP P 10:00 - 11:00 1.00 RIGU P SCHEVE WAIVED WITNESS TO TEST - PASS. GREASE VALVES AS NEEDED. PRE PJSM W/ DSM REGARDING PULLING BPV. PRE RU DSM LUBRICATOR. PT 250PSI/2000PSI. BLEED OFF WHP & OPEN WELL - 70PSI. ATTEMPT TO PULL 6" CIW BPV. PRE CONTINUE TO PULL 6" CIW BPV W/ SUCCESS AFTER ADDING 2' EXTENSION. RD DSM PRE PJSM REGARDING STABBING COIL. PRE PU INJECTOR. RD PULL BACK WINCH. RU STABBING WINCH CABLE. PULL TEST GRAPPLE. REMOVE SHIPPING BAR. PULL COIL ACROSS & STAB INTO INJECTOR. CUT 10FT OF COIL TO FIND WIRE. INSTALL BOOT ON WIRE. STAB ONTO WELL. FILL COIL REVERSE SLACK INTO COIL. PRE PT PACKOFFS & INNER REEL VALVE PER AOGCC REGS 250PSI/3500PS! - PASS. PRE PJSM REGARDING RU COIL CUTTER & CUTTING/HANDLING COIL. BLOW BACK COIL W/ AIR WHILE PERFORMING PJSM - 106BLS RECOVERED. PRE RU COIL CUTTER. CUT 362' OF COIL & FIND WIRE. TEST WIRE. CREW CHANGE. LD CUTTER PRE INSTALL CTC. PT 35K, 3500 PSI. INSTALL BHI UQC AND TEST WEXIT BRING BTT TOOLS TO FLOOR. INSTALL 2 RA TAGS IN WS PRE STAB ONTO WELL. OPEN UP TO WELL AND HAD 100 PSI WHP. BEGIN BH KILL BY PUMPING SLACK FORWARD AT Printed: 10/5/2009 1027:59 AM ~ • BP EXPLORATIUN Page 2 ~; Operations Summary Report Legal Well Name: D-28 Common Well Name: D-28 Spud Date: 3/2/1986 Event Name: REENTER+COMPLETE Start: 9/2/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of dperations 9/23/2009 10:00 - 11:00 1.00 RIGU P PRE 3.0/2500 W/ PUMP #2 WHILE PUMP DOWN KILL LINE W/ PUMP #1 C~ 3.05/2400. PUMP 300 BBLS 2% KCL W/ MAX WHP AT END OF 660 PSI 11:00 - 12:00 1.00 STWHIP P WEXIT SAFETY MTG WHILE CHK FOR FLOW. MU BTT 4-1/2" X 7" WS/PKR ASSY TO BHI MWD ASSY ___ 12:00 - 14:30 2.50 STWHIP P WEXIT RIH W/ WS ASSY. FILL HOLE W/ 50 BBLS KCL DN BS THEN SWAP TO CT PUMPING THRU EDC 0.75/170 W/ NO RETURNS. SI CHOKE AFTER LOSING 30 ADDITIONAL BBLS AND WELL IS STILL TAKING 0.80/150 WITH ONLY CHARGE PUMP PRESSURE ON CT 14:30 - 15:00 0.50 STWHIP P WEXIT LOG GR TIE-IN DOWN FROM 10900', CORR -31.5' 15:00 - 15:15 0.25 STWHIP P WEXIT RIH TO SET DEPTH AT 11336' 15:15 - 15:40 0.42 STWHIP P WEXIT CLOSE EDC. PRESSURE CT TO 2000 PSI W/ 3.5 BBLS AND WS SET. STACK 4.9K ON WS TO 11337.7' AND HELD, BUT NOTED THAT TF MOVED FROM 145R TO 185R. PULLED UP HOLE CLEAN AT 46K LEAVING TOWS AT 11320' ELMD ~U~ of~' t,,/t~;p sft ~ 15:40 - 16:15 0.58 STWHIP P WEXIT CIRC REMAINDER OF FW FROM PITS 1.85/750 WHILE BACKING IN TRUCK W/ BIOZAN. WELL IS STILL ON VAC. START BIOZAN AND BRING RATE UP TO 2.47/1300 AND TOOK 45 BBLS TO GET RETURNS OF 0.7 BPM. FILL CT W/ 60 BBLS BIOZAN 16:15 - 18:50 2.58 STWHIP P WEXIT POOH FILLING BS W/ CHARGE PUMP W/ 2 PPB BIOZAN. PJSM WHILE POH REGARDING LD BHA. 18:50 - 19:25 0.58 STWHIP P WEXIT SEND PERSON UP DERRICK TO REMOVE ICE. 19:25 - 19:50 0.42 STWHIP P WEXIT POP OFF WELL. LD WS SETTING BHA. REMOVE HOT & RECONFIGURE TOOLS FOR MILLING OPS. 19:50 - 20:30 0.67 STWHIP P WEXIT MU WINDOW MILLING BHA. STAB ONTO WELL. POWER UP & CHECK TOOLS. 20:30 - 22:40 2.17 STWHIP P WEXIT RIH. 22:40 - 22:50 0.17 STWHIP P WEXIT LOG DOWN FOR TIE-IN FROM 10,970FT (-31 FT CORR) W/ 50% LOSSES. 22:50 - 23:15 0.42 STWHIP P WEXIT CONT RIH. WT CK AT 11,300ft = 52K. DRY TAG AT 11,321ft W/ 5K. 23:15 -00:00 0.75 STWHIP P WEXIT TIME MILL WINDOW ~ 1FPH FROM 11,319.7FT 2.76PM IN/ 2.25 BPM OUT USING KCL W/ 2PPB BIO , FS 1,945psi. 9/24/2009 00:00 - 01:00 1.00 STWHIP P WEXIT CONTINUE TO TIME MILL WINDOW H FROM 11,320.5FT 2.686PM IN/ 2.40 BPM O SING KCL W/ 2PPB BIOZAN, FS 1,945psi W/ 1 OPSI MW & 1.5-2.65KLBS WOB. 01:00 - 06:00 5.00 STWHIP P WEXIT CONTINU IME MILL WINDOW Q 1 FPH FROM 11, . T .66BPM IN/ 2.68 BPM OUT, SWAPPING TO GEOVIS W/ 2.5-2.9KLBS WOB. 02:15AM - ALL SWAPPED OVER TO GEOVIS. LOST 1.5K# WOB & 150PSI MW AT 11,323.5FT. 06:00 - 08:15 2.25 STWH WEXIT 11325.6' 2.61/2.56/2460 w/ O.80k wob. MILL TO 11328' 08:15 - 08:50 0.58 IP P WEXIT DRILL OPEN HOLE TO 11328' 08:50 - 09:30 . STWHIP P WEXIT DRESS WINDOW, DRY TAG 09:30 - 12: 2.50 STWHIP P WEXIT POH CIRC THRU MILL 2.6/2200 12:0 :45 0.75 STWHIP P WEXIT LD AND LOAD OUT MILLING BHA. MILL AND SR WERE BOTH 3.79" Printed: 10/5/2009 1027:59 AM KB. ELEV = 78.7' BF. ELE1/ = 42J1' KOP = 4282' Max Angle = '.2 ~ 12449` Datum MD = 10496' DatumTVb= 8800' SS ~ ~~~} ~IC1~~~~3C~ SAF TES: WELL ANGLE> 70° @ 10742'. I 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2670' Minimum ID = 2.30"' ~ 1~210' I(iSlt~@ TQP Q~ ~~~E~ ~TOPOF 4-1/2" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" TOPOF7" LNR ~~ 9639 9-5l8" CSG, 47#, L-80, ID = 8.681" 9882' ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10076' 3.70" BKR LNF2 DEPLC}YMENT SLV . ID = 2.3t7" 1020D" ~o TOC 102Q~° ~4-112" rr~onobore packer w hipafocl~ 11320' PERFORATION SUMMARY REF LOG: BNI MUIICYGR C'3N 9I30IfJ9 ANGLEATTOP PERF: 91.5° @ 11850' Note: I~fer to R~oduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz L1ATE 2" 6 1185Q-12150 O 1 Dl~ft79 2" 6 12200-12390 O 10f€~tQ9 2" 6 12460-"~ 29Qfl ~ 1{}/03l09 2" B 1294C~-93t157 C7 10/03109 2188' ~4-1/2" HES HXO SSSV NIP, ID= 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE V W LATCH PORT ~TE 5 3087 3087 1 HES TB DMY RM 0 03/26/O6 4 5293 5217 33 HES TB DMY RM 0 03/26/06 B DMY RM 0 03/26/06 7667 6880 43 HES T 2 9201 7975 41 HES TB DMY RA 0 1 9398 8120 45 HES TB DAAY RM 0 03/26/O6 9469' 4-1/2" HES X NIP, ID = 3.813" 9480' 9-5/8" X 4-1 /2" TNV HBBRT PKR, ID = 4:00" 9504~ 4-1l2" HES X NIP, ID = 3.513" 9526' 4-1/2" HES XN NIP, M ILLL~ ID = 3.80" 9530~ 9-5/8" X 7" BKR HMC LNR PKR 9538~ 4-1/2" WLEG, ID=3.958" 9528~ ELMD TT LOGGED 04/23/96 9660~ 7" X 4-1/2" XO, ID = 3.958" 9639' 7" LNR i-IGR ~ TSGR 993~' 7" MILLOUT WINDOW (D-28A) 10075' - 10125' KB packer iD: 2.36°' 10184` XtJ -j 17887' ~ 9-3116° x 2-7i8° crrt'd & perf'd '~3~pp' ~~~ _.. ~ , ~ F~T 13t357` • ~ ~ ~ ~` --------------------- ~_ 11391~ BKRKBPKR ---------"------^--- 2-7/8" SLTD LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" BKRVUQ1 PKR, ORIENTING KEY 80~. LEFf OF HIGH SIDE PBTD I~ 11 4-1 /2" LNR, 12.6#, L-S0, .0152 bpf, ID = 3.958" a4TE REV BY COMMENTS DATE REV BY CAMMENTS PRUDHOE BAY UNIT 03/18l86 ORIGINAL COM PLETION 03/26/O6 RPH/PJC WANER SFTY NOTE DELE1'ED WELL: D-28B 02/26/97 HITLO SIDETRACK COM PLETION 03/26/06 TEUPJC GLV GO PERMff No: 05/19/04 SRBIKAK SET IBP, ADPERF 10/15/08 DAAS/PJC PULL IBR' FISH IN HOLE (10/10/0 8) API No: 50-029-21556-Q2 05/28/04 LWB/KAK GLM ND DEPfH CORRECTION 10l02109 Norr9~ 2 CT[~ SI[~Et'12ACK fcsr more pii... SEC 23, T11 N, R13E, 1496' FNL & 1692' FEL 05/29/04 DAWKAK GLV GO 07/11/04 MDGKAK ADPERFS BP E~cpioration (Alaska) ~ ~ `~'~-~ ~`' y ( ~ ~ _ ~ k ~ ° -~ s -' ' ~ € ~p ,, ~ ~ t ~ ~ ~ F 4 ~, ~ ~ h ~ ~ ~~ H ~ ~ ~ ~, ~ ~ ~ ° ~ ~ f @ t ~ t n P e ~ ~ ~ ~ ~ ~ ~P ~ a~ ~ o ~~~ ~ F ~ ~ ~ F f ~ ~ ~ ~ ~F~ ~ ~" „r,~ ~} k ~ ~ ~ ~ ~, ~ ~ ~; ~ ~ `r SEAN PARNELL, GOVERNOR ~,~s c ~ .~ ~ ~.x ~ ,_ _. ~, ~~ a.~ ~!~ ~~ ~, ~ ~s ~a ~ k AL1~SSli DIL AKD ~z~S ,~ CO1~TS~RQATI011T CODII-iISSIOI~T " 333 W. 7th AVENUE, SUITE 100 ~t~ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP E~loration (Alaska) Inc. ~'\~ P.O. Box 196612 JC. ~ Anchorage, AK 99519-6612 ~ ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-28A Sundry Number: 309-289 Dear Mr. McMullen: ~Y,Ar,,r~,~~~t~~~ ~~;~; '~ W ~~7~~ 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 fo~ rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. %~ Cha.ir DATED thi~`'° day of August, 2009 Encl. _ ~~" _ ~~ STATE OF ALASKA 0 g.. ~~ ALA~OIL AND GAS CONSERVATION COM ON ~,1/ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~.~~~~~~~y~ ~,~ '-i ~ % ~. ,3 1 ~l L i.J 17.J ~:.1~s~.a.3.k ~;s . ~~tF+ _ . ,. '~~~.t~.~~".~`E'ta;s 1. Type of Request: ~ Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensiun •~ ^ Alter Casing ^ Repair Wetl ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Puli Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 195-213 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21556-01-00_ 7. If perForating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU D-28A- Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028285 ~ 78.66 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11866 - 9027 - 11773 9026 None Yes, depth Unknown a in Len th Size MD TVD Burs olla se Structural n ctor 110' 0" x 20" 11 ' 11 ' Surface 2670' 13-3/8" 2 70' 2670' 49 0 267 Intermediate Pr ct' n 2' 9-5/ " 2' 497' 7 47 Liner 436' 7" 9639' - 10075' 8284' - 5 5' 7240 410 Liner 2336' 4-1/2" 9530' - 11866' 8211' - 9027' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10680' - 11650' 9003' - 9027' 4-1/2", 12.6# L-80 9538' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW HBBP-T Packer Packers and SSSV MD (ft): 9480' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 7, 2009 ^ Oil ^ Gas ^ Plugged ~ Abandoned 17. Verbal Approval: Date: ^ N/AG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name John ulJ~n Title Engineering Team Leader Prepared By NamelNumber: Signature _ Phone 564-4711 Dat ~~ 9 Sondra Stewman, 56a-4750 ` Commission Use Onl Sundry Number: _ ~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity t~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ S`~~ P~- ~° ~ 1 cs ~ x s~a s4 A~~~ T~ ~~ ~ Subsequent Form Required: ~ p- ~-~ APPROVED BY ~~~/ A roved B: COMMISSIONER THE COMMISSION Date -'~~ Form 10-403 Revised 06/2006 ~ oRi~~~A~ ~;~ _ °_ ~ ~ ~~.~ ~s~c ~~ a 2~09 Submit In Duplicate ~..~- ~.~~/~ L~ ' ~.- ~u o~ ~J To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: August 18, 2009 Re: D-28A and D-28AL1 Sundry Approval • bp Well Construction: D-28 was drilled in 1986 to target an area in northem gravity drainage area of D-pad. The well was constructed with a 13-3/8" surface casing set to 2,670', a 9-5/8" production casing set at 9,882', with a 7" production liner to 11,165'. In January 1996 the D-28A sidetrack kicked-off of the 7" production liner from the window at 10,075' - 10,125'. In February 1997 a short lateral (AL1) was drilled out of the D-28A 4-1/2" completion to supplement production, the AL1 lateral was completed with 2-3/8" slotted liner. Production: A coiled tubing sidetrack multi-lateral (D-28AL1) was drilled in February 1997 to access the overlying non- isolated lower Zone 2 reservoir section. A flow-thru whipstock was set at ~11,446' in D-28A's original perf interval and the lateral was completed with a 2-7/8" slotted liner in both Zone 1 and Zone 2. D-28AL1's initial production quickly dropped and GOR increased. The lateral into Zone 2 is extremely close to faults that are likely conductive to gas. An IBP was set and adperfs were shot May 2004 to isolate the horizontal and access the NLOC in the heel. Since the adperfs the well continued to decrease in overall rate. This decline is attributed to tight lithology that is evident in the open-hole logs of the parent well D-28. Therefore, additional adperfs were shot July 2004 to access more prolific lithology. The July 2004 adperfs initially increased D-28's production; however declined rapidly afterwards. Therefore, in July 2005 an acid stimulation was pumped. The acid job provided a minimal increase in rate. Although the IBP and adperf served the desired purpose of making the well more competitive respecting the prevailing GC 1 MGOR at the time, the intervention significantly dropped off production. Attempts to stimulate the well resulted in very short term rate gains before the well returned to the pre-stimulation decline rates. In October 2008, the IBP set in May 2004 at 10,800' was pulled in an end of life wellwork attempt to gain production. The result of removing the IBP was a short term flush production gain which has quickly rose to GC1 marginal's and is no longer competitive. Well Integrity: In May 2002 the inner annulus pressure broke MOASP (maximum operating annulus surface pressure). Subsequently, a TIFL was performed which proved to be inconclusive. The well was left shut in while troubleshooting diagnostic work was performed. In September 2002 the outer annulus was pressured tested to 2400 psi and 3000 psi on two different occasions, both passed. Packoff testing of the tubing passed whereas inner casing packoff did not in October 2002. In November 2002, a TxIA communication waiver was granted allowing the well to be produced for slow TxIA communication. Per waiver requirements in September 2003, 2004, and 2005 NFT-IA tests were performed. The pad operator called in leaky lock down screws in October 2004, DHD confirmed gas leaking past one LDS on the tubing hanger and tightened the gland nut which stopped the leak. MTT-OA passed in October 2004 and July 2005. A caliper log was run January 2006 which indicated the tubing to be in good to fair condition with wall penetrations ranging from 20% to 24%. In March 2006 a MTT-IA to 3000 psi passed, at which time the TxIA waiver was canceled. In December 2008, DHD was sent to the well to evaluate possible TxIA communication, a MIT-IA passed to 3000 psi verifying competent tubing, packer, and production casing. Pre-rig MIT's were performed 6/4/09, the MTT-IA to 3000 psi and MIT-OA to 2000 psi passed. REASON FOR SIDETRACK: • • An IBP was set at 10,800' MD in D-28AL1 in May 2004 with the intent of isolating the horizontal, adding perforations and accessing the NLOC near the heal of the well. The IBP served the purpose of shutting off gas and reducing the well's short term GOR making it more competitive at GC1. The effect was short lived and came at the expense of reduced oil rates, in the Fall of 2008, the IBP was removed in the hopes of accessing low GOR oil in the tce of the well. The effect was short lived and the well quickly rose above MGOR's and currently has no value. Removing the IBP was an end of life wellwork option that panned out for the short term, however to yield a well with greater on time a CTD sidetrack is required. The proposed plan for D-28B is to drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around September 7, 2009. The existing perforations will be isolated by the liner primary cement job. The sidetrack, D-28B, will exit the existing 4-1/2" liner at 11,270'. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to begin August 14, 2009) 1. S Dummy GLV's and caliper DONE 2. W MTT-IA to 3000 psi DONE 6/04/09 3. C Dummy WS drift to 11350' (IBP element in the hole) 4. W AC-LDS; AC-PPPOT-T Done 6/16/09 5. W PT tree (MV,SV,WV) 6. O Bleed gas lift and production flowlines down to zero and blind flange 7. O Remove S-Riser, Remove wellhouse, level pad Rig Work: (scheduled to begin on September 7, 2009) l. MIRU and test BOPE to 250 psi low and 3500 psi high. /r 2. Set 4-1/2" Packer WS at 11,270' / 3. Mi113.8" window at 11,270' and 10' of rathole. Swap the well to Flo-Pro. 4. Drill Build: 4.125" OH, 460' (22 deg/100 planned) ~, ~~- 5. Drill Lateral: 4.125" OH, 1600' (12 deg/100 planned) 6. Run 3-3/16" x 2-7/8" solid liner leaving TOL at 10,180' 7. Pump primary cement leaving TOC at 10,180', 30 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNLJGR/CCL log 9. Test liner lap to 2000 psi. , 2a~~ - 0 o°S 10. Perforate lmer per asset mstructions (~ 1000 ) 11. Freeze protect well, RDMO ~/~r i~ y~ ~~'~ w ~' ~`~ ~r~rr~ ~z ;~ ~~;~i ~ Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Sean Mclaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble ~~,v L~;~ ~L/ y~+r, n ~ ~ lJ in/ ('~~ W, l ~ ~" .y `~t ~~'' i~lr' ~u~ry ('S Ct n /}`" / i; f t~1 v N~Ct`3/'~if~ itiQ l'~V`"~f ,,~T` ',~~Sti'' i1~'r ~ ~ ~s ,~, ~ ~ ~ ru ~ ~7 ~r~~ f r~ ~o ~~~ !,~s {,+2'~'v~ i'~r ~~~.~J (i~'il, d~lc.'~~r'~,a ~er ~~~r~ ~ `~ .vc?/~~;!?S ~, G~~~'~~ I~~ ~%'~ 7 t~. t7j1i57~F~ ~` c;~.`'", j ~~~,~~'~ `~~', ~ e ~ ~ ~ s~~ ,~' ~ 3a~-•~ ~ KB. ~~E1/ = 78.7' BF. ~LEV = 42.71' KOP = 4282' Nhau Ang~ = 101 aQ 11537' Datum MD = 10496' DatumTVD= 8800' SS 13-3/8" CSG. 72#, L-80, ID = 12.347" • D-2 8A L 1 S TES: WELL ANGLE> 70° (a~ 10742'. • Minimum ID = 2.37" @ 11391' TOP OF 2-7/8" SLOTTED LINER 2188' ~--~4-1/2" HES FDCO SSSV N~, ID = 3.813" GAS LFT MANDRH.S ST W~ ND DEV TYPE VLV LATCH PORT QNTE 5 3087 3087 1 HES TB DMY RM 0 03/26/06 4 5293 5217 33 HES TB DMY RM 0 03J26/06 3 7667 6880 43 HES TB DMY RM 0 03/26/06 2 9201 7975 41 HES TB DMY RA 0 1 9398 8120 45 HES TB DMY RM 0 03/26/O6 ~' ~ M1/2" h~,S X NIP, ID = 3.813" 9480' (-{ 9-5(8" X 4-112" TNV HBBRT PKR, ID = 4.00" 9~ 4-1/2" FIES X N~, ~= 3.813" 4-1/2" HES XN NIP, MILLL~ ID = 3.80" ~ TOP OF 4-1 /2" LI~d2 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" LNR 29#~ L-80, .0371 bpf, ~= 6.184" I TOP OF 7" LI~2 I 9-5l8" CSG, 47#, L-80, ID = 8.681" 7" LNR 29#, L-80, .0371 bpf, ~= 6.184" P9ZFORATION SUMMARY R~ LOG: SPBZRY SUN NNVD/GR ON 01 /29/96 ANGLE AT TOP P@~F: 60° @ 10680' Note: Refer to Production DB for historical perf data SIZE SPF AYT@2~/AL Opn/Sqz DATE 2-7/8" 6 10680 - 10705 O 07/11/04 2-7/8" 6 10716 - 10738 O 05/18/04 2-3/4" 4 10910 - 11110 O 02/05/96 2-3/4" 4 11270 - 11650 O 02/05/96 TOP OF 2-7/8" SLTD LI~ BKR WQ1 PKR, ORIBYfING KEY 80°, LH= T OF HIGH SIDE 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 9530' ~ 9-5/8" X 7" BKR 1-~AC LI~ PKR 9538' 41/2" WLEG, ID = 3.958" 9528' ~MD 7'7' LOGGm 04l23/96 9550' 7" X 4-1/2" XO, ID = 3.958" 17" LNR HGR i 9878' - j nnAwcfft JOpvrJ 7° MILLOUT WINDOW (D-28A) 10075' - 10125' ? ~ FISH - IBP ~BuB~ff (10I10/08) 11391' a~ -cs ~R ~` 4-1/2" MILLOUT WBVDOW (D-28AL1) 11425' - 11437' ~ ~ ~ ~ ~ ~ ~` ~- ------------------- ~----------------------~ a4TE 03/18/86 REV BY CONquENTS OWGINAL COMPLETION DATE 03/26/06 REV BY RPWPJC CON~IABVTS WAN~2 SFTY NOTE DE1.ET~ 02126/97 L SIDETRACKCaIAPLETION 03/26/O6 TEUPJC GLV GO 05/19l04 SRB/KAK SET IBP, ADPEFiF 10/15/08 DMS/PJC PULL ~P/ FISH IN F~IE (10/10/0~ 05/28/04 LWB/KA GLM ND OEPTH CORRECTION 05/29/04 DAV/KA GLV GO 07/11/04 MDClKA ADPBiFS 2-7/8" SLTD LNR, 6.16#, L-S0, .0058 bpf, ID = 2.37" PRUDHOE BAY UNIT W~L: a28AL1 PBiMff No: ~1970140 API No: 50-029-21556-60 SEC 23, T11 N, R13E, 1496' FNL. 8~ 1692' F~ BP 6cploration (Alaska) ~ I KB. ~~-1/ = 78.7' BF. ELEV = 42.71' KOP = 4282' x Angle = 101 @ 11537' Datum MD = 10496' Datum ND = 8800' SS 13-3l8" CSG, 72#, L-80, ID = 12.347" • ~~~~~ ~roposed CTD Sidetrack Minimum ID = 2.30" @ 10180' ITOP OF 4-1/2" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~TOP OF 7" LNR ~-1 9639' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9882~ 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 10075~ 3.70" BKR LNR DEPLOYMINT SLV, ID = 2.30" ~-j 101 TOC y 7p~ ~ 4-1/2" rtnnobore w hipstock ~ PERFORATION SUMMARY R~ LOG: SPERRY SUN MWD/GR O 1 l29/96 ANGLE AT TOP PERF: 60° @ 0680' Note: Refer to Roduction DB for hi orical perf data SIZE SPF INTERVAL pn/Sqz DATE 2-7/8" 6 10680 - 10705 O 07/11/04 2-7/8" 6 10716 - 1073 O 05/18/04 2-3l4" 4 10910 - 111 0 O 02J05/96 2-3/4" 4 11270 - 1 50 O 02/05/96 ~ 46° 91° ~ SAFF~[~OTES: W ELL ANGLE > 70° @ 10742'. ~ 2~$~-~4-1/2" HES HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS iT MD ND DEV TYPE VLV LATCH PORT DATE 5 3087 3087 1 HES TB DMY RM 0 03/26/06 4 5293 5217 33 HES TB DMY RM 0 03/26/O6 3 7667 6880 43 HES TB DAA1' RM 0 03/26/06 2 9201 7975 41 HES DAAY RA 0 1 9398 8120 45 TB DMY RM 0 03/26/O6 9469~ 4- " HES X NIP, ID = 3.813" 948~~ 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 4.00" 9504~ 4-1 /2" HES X NIP, ID = 3.813" 26' 4-1/2" HES XN NIP, M ILLLm ID = 3.80" 9530~ 9-5/8" X 7" BKR HMC LNR PKR 9538~ 4-1/2" WLEG, ID = 3.958" g528~ ELMD TT LOGGm 04l23/96 9550' 7" X 4-1/2" XO, ID = 3.958" 9639'~ 7" LNR HGR - TSGR 9931' 7" MILLOUT WINDOW (D-28A) 10075' - 10125' I XO I I 3-3/16" x 2-7/8" crrt'd & perf'd ~ I 13330' II cr 2~ti ~ S~-zs-~~ . ~ ~- ~ ~ ~ ~ ~` ------------------- ~ ~---------------------~ 2-7/8" SLTD Lt~2, --~ 6.16#, L-80, .0058 bpf, ID = 2.37" 11391 ~ I-I BKR KB PFCR BKR WD-1 PKR, ORIBVTING KEY 80°, LEFf OF HIGH SIDE 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 03/18186 ORIGINAL COM PLETION 03/26/06 RPWPJC WANB~ SFTY NOTE DELETm WE1L: D-28B 02/26/97 HITLO SIDETRACKCOMPLEfION 03/26/06 TE1/PJC GLV GO P92M(TNo: 05/19/04 SRB/KAK SEf IBP; ADPERF 10/15/OS DMS/PJC PULL IBP/ FISH IN HOLE (10/10/0 8) API No: 50-029-21556-02 05/28/04 LWB/KA GLM ND DEPTH CORRECTIO 06/18/09 MSE PROPOSm CTD SIDETRACK SEC 23, T11 N, R13E, 1496' FNL 8 1692' FEL 05l29/04 DAV/KA GLV GO 07/11l04 MDGKA ADPERFS BP Exploration (Alaska) Page 1 of 1 ~ ~ Schwartz, Guy L (DQA) From: McLaughtin, Sean M (Sean.McLaughlin@bp.com] Sent: Tuesday, August 25, 2009 10:21 AM To: Schwartz, Guy L (DOA) Subject: RE: D-28B Sidetrack (PTD# 209-089) Attachments: D-28B. jpg Guy, The revised D-28B schematic is attached, I needed to update my files as well. Like we spoke about there is little value to an independent CIBP run. We will run a packer on the bottom of the whipstock (single run system). This packer will not give much pressure isolation but my act a a soft bottom for the liner cement and help to hold the cmt in place until it sets. Regards, Sean From: Schwartz, Guy l (DOA) [mailto:9uy.schwariz@alaska.gov] Sent: Tuesday, August 25, 2009 10:iS AM To: McLaughiin, Sean M Subject: D-28B Sidetrack (PTD# 209-089) Sean, As per our conversation please confirm that the 4.5" CIBP shown on the proposed completion is not going to be set just below the whipstock. As you mentioned with open perforations above and below the whip sockiClBP setting depth it wouid not isolate the old welibore while drilling the new lateral. The P& A for the old welibore(s) will be accomplished with the cementing of the new 2 7/8" liner up into the casing to 10180' md. 1 will make a notation on the schematic for our file. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 8/2512009 Kt3. tLtV = /8. /' BF. ELEV = 42.71' D ~ ~ ~ _ SA OTES: WELL ANGLE> 70° ~ 10742'. KO P= 4282' Max Angle = 101 @ 11537~ ~ Q~ ~~ 5 t n.~ Proposed CTD Sidetrack Datum MD = 10496' ~ ~'Z ~ ~ ~`t Datum ND = 8800' SS 2~$$' 4-1/2" HES HXO SSSV NIP, ID = 3.813" ~ GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 13-3/8" CSG, 72#, L-80, ID = 12.347" 2670~ 5 3087 3087 1 HES TB DMY RM 0 03/26/( 4 5293 5217 33 HES TB DMY RM 0 03/26/( 3 7667 6880 43 HES TB DMY RM 0 03/26/( 2 9201 7975 41 HES TB DMY RA 0 1 9398 8120 45 HES TB DMY RM 0 03/26!( 9469~ 4-1/2" HES X NIP, ID = 3.813" Minimum ID = 2.30" ~ 10180' TOP OF LIN ER 9480~ 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 4.00" 9504~ 4-1 /2" HES X NIP, ID = 3.613" 9526~ 4-112" HES XN NIP, M ILLLm ID = 3.80" TOP OF 4-1 /2" LNR 9530' 9530~ 9-5lS" X 7" BKR HMC LNR PKR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9538' 9538~ 4-1/2" WLEG, ID = 3.958" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9550' gg2g' ELMD TT LOGGED 04/23/96 9550~ 7" X 4-1 /2" XO, ID = 3.958" TOP OF 7" LNR 9639~ 9639' 7" LNR HGR 9-5/8" CSG, 47#, L-80, ID = 8.681" 9882~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10075~ 70" BKR LNR DEPLOYMENT SLV, ID = 2.30" ~ 10180' TOC ~ ~~7~p 4-1/2" monobore packerwhipstoc~ 11270~ ~~ ~ ^ ~ PERFORATION SUMMARY REF LOG: SPERRY SUN MWD/GR ON 01129/96 ANGLE AT TOP PERF: 60° @ 10680' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10680 - 10705 O 07/11 /04 2-7/6" 6 10716 - 10738 O 05/1 S/04 2-3/4" 4 10910 - 11110 O 02/05l96 2-3/4" 4 11270 - 11650 O 02/05/96 0 91° ~ TSGR 9931' 7" MILLOUT WINDOW (0.28A) 10075' - 10125' xo ~ 11600' ~ 3-3/16" x 2-718" crrt'd & perf'd 13330' . ` • ~ ~ ~ ~\ --------------------- ~__ _ BKRKBPKR - ---------------- WHIPSTOCK ~ BKR WD-1 PKR, ORIENTING ~ KEY 80°, LEFT OF HIGH SIDE PBTD ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 2-7/8" SLTD LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 03/18l86 ORIGINAL COM PLETION 03/26/06 RPH/PJC WANER SFTY NOTE DELETED WELL: D-28B 02/26l97 HITLO SIDETRACK COM PL~'ION 03/26l06 TEL/PJC GLV C/O PERMIT No: 05/19/04 SRB/KAK SET IBP; ADPERF 10/15/08 DMS/PJC PULL IBP/ FISH IN HOLE (10/10/O S) API No: 50-029-21556-02 05/28/04 LWB/KA GLM ND DEPTH CORRECTION 06/18/09 MSE PROPOSED CTD SIDETRACK SEC 23, T11 N, R13E, 1496' FNL 8 1692' FEL 05/29l04 DAVlKA GLV GO 07l11/04 MDC/KAK ADPERFS BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~''~¢' ~ ~ ~ ~ CommissiOner B; ~.'~' ~' . ,.~ Tom Maunder, ~~~ ' P. i. Supervisor ~(.~,~.-O ~,. DATE: April 20, 2001 FROM: Chuck SCheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit D Pad Friday, April 20, 200!; I traveled to BPXs D Pad and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates ! witnessed the testing of 20 wells and 40 components with 1 failure. The surface safety valve on well, D-06 had a slow leak when pressure tested. This valve was serviced and the retest witnessed on this date. Merv Liddlow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houSes on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and ali equipment appeared to be in fair conditions. Summary: I witnessed the semi annual SVS testing at BPXs D-Pad. PBU D Pad, 20 wells, 40 components, 1 failure 2.5% failure rate 25 wellhouse inSpections Attachment: SVS PBU D Pad 4-20-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU D Pad 4-20-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Cht~ck Scheve Field/Unit/Pad: Prudhoe/PBU / D Pad Separator psi: LPS 154 Date: 4/19 & 4/20 HPS 660 i i WeB Permit Separ Set L/P Test Test Test Date oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE , D-01A 1970780 154: 125 125 P P OIL , ,, D-03A 2001340 154 125 125 P P OIL , D-04A 1871250 D-05 1700060 660 550 450 P P '0IL ~ , D-06A 1970430 660~ 550 600 P 4 OIL D207A 1931570 6601 550 525 P P "4/20/0'1 OIL D-08 1790360 , D-09A 1990850 660 550 525 P P OIL D-10 1790530 6601 550 525 P P ' OIL D-11A 1951830 660! 550 525 P P OIL , D-12 1800150 660~ 550 530 P P OIL, D-13A 2000810 ' ' D-14A 1961530 .... D-15A 1972120 , D-16 1811710 660 550 500 P P OIL D-17A 1960460 D-18 1811880 D-20 1820440 154 125 120 P P OIL D-21 1820~20 154 125 125 P P OIL D-22~ ' 1972040 D-23A 1961880 660 550 525 P P ' OIL D-24 1852990 D-25A 2000240 154 125 100 P P ' OIL D-26A 1970870 660 550 525 P P OIL D-27 1860330 660 550 ~50 P P ' " OIL D-28A 1952130 660 550 550 P P OILi D-29 1852530 154 125 110 P P OIL , i r D-30 1960260 D-31A 1960950 660 550 550 'P P OIL D-33 1960360 660 550 550 e P OIL ,, ,, , RJF 1/16/01 Page 1 of 2 SVS PBU D Pad 4-20-01 CS ii i i i i _ . · Number Number PSI PSI Trip Code Wells: '~:20 Components: 40 Failures: Test Code 1 IsSs l.. i . . '-~ .:.' .: :..-; : -:. ,....~ ,~. ,,:. ':.-. , ~., ;, :.-, .. Test Date Oil, WAG, GIN J, Code Passed GAS or CYCLE Failure Rate: 2.50% Ulo0 Day Remarks: The surface safety, valve on well D-6 had slow leak when press,ure tested. Valve was serviced and retested same day RJF 1/16/01 Page 2 of 2 SVS PBU D Pad 4-20-01 CS 0.3 ,00 PERMIT AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 02/25/98 DATA T DATA PLUS RUN RECVD -- 95-213 CN/GR/CCL ~EPIA q2~-0- t0 770 1 05/21/96 95-213 GR/CCL/JEWELRY L SEPIA ~52~-- 10"7~_.~ 1 05/21/96 95-213 PLS (PROD) L~/SEPiA ~'~0- [~':."("~ 1 05/03/96 95-213 7303 L-T~N/GR 9850-10770 1 06/28/96 95 -213 NGP/DGR/RES-TVD ~/'8404-9028 FINAL 12/16/96 95 -213 NGP/DGR/RES-MD ~9840-11866 FINAL 12/16/96 95-213 7600 a.~SPERRY GR/RES q~/0 - //~Q(~ 1-3,6 01/29/97 10-407 ~q COMPLETION DATE ~/ )-/ ~/ DALLY WELL OPS R )/!J' ©& / :.,I TO ~(/ 6 /~/ o//~} lq/ / Are dry di samples required~ ~yes' ~ ~d received? -ycs no Was the well cored? yes .._~ Analysis & description received? ye~ Are well tests required? ~ yes ~ Received? Well is in compliance ~ Initial"~ COMMENTS 0 !:t I I.-I-- I IM G S E I:1L/I r' Ec: WELL LOG TRANSMITTAL To: State of Alaska January 29, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D-28A The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. API#: 50-029-21556-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 December 13, 1996 RE: MWD Formation Evaluation Logs D-28A, AK-MW-60011 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, fiG, Anchorage, AK 99518 D-28A: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-21556-01 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-21556-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia R CE!V u 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: D-28A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Date: RE: 14 June 1996 Transmittal of Data ECC #: 6650.01 Sent by: HAND CARRY Data: LDWG Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ O~~o (907) 563-7803 Received by: Date: u: .s Co;is. "'" ' Anchorage LARRY G~ANT Attn. ALASKA OiL + GAS CONSERVATION 3001 ~ ~'~-~ DRIVE ANCHOP~.GE AK, 99501. Date: 30 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, ~se find the data as described below: Enclosed, r~_ WELL ~ DESCRIPTION 1 PDK FIANL BL & RF q f-"/~l 5 D-28A ~-1 CN FINAL BL & RF -'1 GR/CCL FINAL BL & RF 1 CCL FINAL BL & RF ECC No. Run # 1 5868.08 Run # 1 6650.01 Run # 1 Run # 1 6665.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchora~e, AK 99518 F~) 563-7803 Date: LARRY GRANT Attn. ALASi<A OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE AK, 99501. Date: 18 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~.~/]~i C-21 (32-19-11-14) ?~- [~q u-02 ~6~ 00~ P-20A 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # i 4352.03 Run # 1 4502.03 Run # 1 5962.03 Run ~ 1 6503.04 Run # 1 6624.02 Run # 1 Run ~ 1 6650.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: Anchorage, AK 99518 xl / Or FAX to (907) 563-7~C. 3 'ti , ~ (~~/~/' Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG !1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 95-213 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21556-01 4. Location of well at surface 9. Unit or Lease Name 1496' SNL, 1692' WEL, SEC. 23, T11N, R13E ? ..................... __[ Prudhoe Bay Unit ;~,~;.;'~_~"-;'~" .......... ' :~':: ,: : i!i ~'.!~ lO. Well Number At Top Producing Interval D-28A ~~~ 11. Field and Pool ~!:_ Prudhoe Bay Field/Prudhoe Bay Pool At Total Depth 3805' NSL, 2080' WEL, SEC. 14, T11N, R13E ~ '- ~'-' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.66 ADL 028285 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 01/23/96 01/29/96 02/05/96I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11866'MD/9027'TVD 11779'MD/9026'TVD YES [] NO []I 2187feet MD 1900'(Approx.) 22. Type Electric or Other Logs Run GR, RES, DIR/FE 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FFOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" X 20" Insulated Conductor Surface 110' 26" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2670' 17-1/2" 3255 cuft PF 'E', 465 cuft PF 9-5/8" 47# L-80 Surface 9882' 12-1/4" 575 cuft Class 'G' 7" 29# L-80 9639' 10075' 8-1/2" 575 cuft Class 'G' 4-1/2" 12.6# L-80 9530' 11866' 6" 341 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SIll'(MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2" 9538' 9480' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10910' - 11110' 9038' - 9034' Freeze Protect w/145 Bbls Diesel 11270' - 11650' 9035'- 9027' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 12, 1996 Gas Lift Date of Test Hours Tested TEsTPRODUCTIONpERIOD FORi~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ' ' i"v" :: ORIGINAL 4 -"' '199" Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sadlerochit 10050' 8539' Top of Zone 3 10281' 8705' Top of Zone 2C 10396' 8797' Top of Zone lB 10742' 9027' ORIGINAL 31. LIST OF A1-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Senior Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: D-28A Rig Name: Doyon 9 AFE: Accept Date: 01/1 4/96 Spud Date: 01/23/96 Release Date: 4P8018 02/05/96 Jan 15 1996 (1) Rig moved 100 %. Fill pits with Seawater. Removed Hanger plug. Held safety meeting. Rigged up High pressure lines. Circulated at 9500 ft. Jan 16 1996 (2) Installed Hanger plug. Retrieved Xmas tree. Rigged up BOP stack. Held safety meeting. Rigged up Annular preventor. Test- ed All functions. Retrieved Hanger plug. Installed Tubing re- trieval string. Held safety meeting. Retrieved Hanger plug. Laid down Tubing to 2100 ft. Rigged down sub-surface equipment - SCSSSV. Laid down Tubing to 2500 ft. Jan 17 1996 (3) Laid down Tubing to 9500 ft. Held safety meeting. Rigged down Tubing handling equipment. Retrieved Seal assembly. Ran Drillpipe to 2000 ft (5 in OD). Held safety meeting. Ran Drillpipe to 3000 ft (5 in OD). Serviced Rig services. Ran Drillpipe to 5000 ft (5 in OD). Jan 18 1996 (4) Ran Drillpipe to 8000 ft (5 in OD). Pulled Drillpipe in stands to 8000 ft. Made up BHA no. 1 . R.I.H. to 8 ft. Held safety meeting. R.I.H. to 8500 ft. Ran Drillpipe to 9470 ft (5 in OD). Rigged up Kelly/top drive hose. Worked toolstring at 9504 ft. Circulated at 9504 ft. Pulled Drillpipe in stands to 0 ft. Ran Drillpipe to 0 ft (5 in OD). Installed Seal assembly. Jan 19 1996 (5) Ran Drillpipe to 9600 ft (5 in OD). Worked toolstring at 9600 ft. Circulated at 9600 ft. Pulled Drillpipe in stands to 5000 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Laid down fish. R.I.H. to 9593 ft. Milled Permanent packer at 9615 ft. Circulated at 9615 ft. Held safety meeting. Circulat- ed at 9615 ft. Pulled out of hole to 0 ft. Pulled BHA. Operations Summary for: D-2~.. Jan 20 1996 (6) Laid down fish. Pulled BHA. Made up BHA no. 4 . Held safety meeting. Made up BHA no. 4. Rigged up Drillstring handling equipment. R.I.H. to 10358 ft. Serviced Block line. Tested Casing - Via string. Circulated at 10358 ft. Held safety meet- ing. Circulated at 10358 ft. Laid down 279 ft of 5 in OD drill pipe. Rigged up Mud shakers. Milled Casing at 10075 ft. Jan 21 1996 (7) Milled Casing at 10102 ft. Held safety meeting. Circulated at 10102 ft. Milled Casing at 10125 ft. Held safety meeting. Cir- culated at 10125 ft. Pulled out of hole to 9725 ft. Circulated at 9760 ft. Circulated at 9760 ft. Pulled out of hole to 7000 ft. Jan 22 1996 (8) Pulled out of hole to 0 ft. Pulled BHA. Circulated at 20 ft. Held safety meeting. Ran Drillpipe to 0 ft (3.5 in OD). Rigged up Drillstring handling equipment. Ran Drillpipe in stands to 10225 ft. Circulated at 10225 ft. Mixed and pumped slurry- 20 bbl. Pulled Drillpipe in stands to 9000 ft. Circulated at 9000 ft. Held 1500 psi pressure on 3.5 bbl squeezed cement. Circu- lated at 0 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Laid down Drillpipe to 1200 ft. Laid down Drill collar to 270 ft. Jan 23 1996 (9) Rigged up BOP stack. Rigged up All rams. Tested All functions. Tested Kelly/top drive hose. Rigged up Drillstring handling equipment. Held safety meeting. Made up BHA no. 1 . Tested MWD - Via annulus and string. R.I.H. to 9500 ft. Serviced Drillfloor/Derrick. R.I.H. to 9607 ft. Washed to 9809 ft. Drilled cement to 9809 ft. Held safety meeting. Drilled to 10114 ft. Jan 24 1996 (10) Drilled to 10318 ft. Held safety meeting. Drilled to 10445 ft. Circulated at 10 ft. Flow check. Circulated at 9600 ft. Pulled out of hole to 5000 ft. Held safety meeting. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 1000 ft. Tested M.W.D. tool- Via string. Page 2 Operations Summary for: D-2,.,,, Jan 25 1996 (11) R.I.H. to 10445 ft. Drilled to 10460 ft. Held safety meeting. Drilled to 10603 ft. Circulated at 10603 ft. Pulled out of hole to 1891 ft. Pulled BHA. Held drill (H2S). Made up BHA no. 3 . R.I.H. to 3488 ft. Held safety meeting. R.I.H. to 10000 ft. Serviced Block line. R.I.H. to 10603 ft. Jan 26 1996 (12) Drilled to 10744 ft. Held safety meeting. Circulated at 10744 ft. Pulled out of hole to 1528 ft. Pulled BHA. Downloaded MWD tool. Made up BHA no. 4. R.I.H. to 8418 ft. Held safety meet- ing. R.I.H. to 10744 ft. Drilled to 10744 ft. Circulated at 10744 ft. Pulled out of hole to 7526 ft. Jan 27 1996 (13) Pulled out of hole to 1506 ft. Pulled BHA. Made up BHA no. 5 . Held safety meeting. Made up BHA no. 5. R.I.H. to 10744 ft. Drilled to 10783 ft. Held safety meeting. Drilled to 10798 ft. Circulated at 10798 ft. Pulled out of hole to 3080 ft. Jan 28 1996 (14) Pulled out of hole to 2039 ft. Pulled BHA. Made up BHA no. 6 . Held safety meeting. Made up BHA no. 6. R.I.H. to 10798 ft. Drilled to 10812 ft. Held safety meeting. Drilled to 10875 ft. Logged hole with LWD: DIR/FE from 10750 ft to 10806 ft. Jan 29 1996 (15) Logged hole with LWD: DIR/FE from 10750 ft to 10806 ft. Drilled to 11126 ft. Held safety meeting. Drilled to 11444 ft. Held safety meeting. Drilled to 11600 ft. Jan 30 1996 (16) Drilled to 11729 ft. Held safety meeting. Drilled to 11866 ft. Circulated at 11866 ft. Pulled out of hole to 10075 ft. Ser- viced Block line. R.I.H. to 11706 ft. Jan 31 1996 (17) R.I.H. to 11866 ft. Circulated at 11866 ft. Held safety meet- ing. Pulled out of hole to 4000 ft. Held safety meeting. Pulled out of hole to 3015 ft. Pulled BHA. Tested All func- tions. Made up BHA no. 7. R.I.H. to 3400 ft. Held safety meeting. R.I.H. to 10290 ft. Reamed to 11464 ft. Page Operations Summary for: D-2~,., Feb I 1996 (18) Reamed to 11866 ft. Circulated at 11866 ft. Pulled out of hole to 10075 ft. R.I.H. to 11866 ft. Circulated at 11866 ft. Held safety meeting. Circulated at 11866 ft. Pulled out of hole to 2316 ft. Pulled BHA. Ran Casing to 2000 ft (4.5 in OD). Held safety meeting. Ran Casing to 2336 ft (4.5 in OD). Circulated at 2336 ft. Ran Drillpipe in stands to 8500 ft. Feb 2 1996 (19) Ran Drillpipe in stands to 8500 ft. Circulated at 10075 ft. Ran Drillpipe in stands to 11866 ft. Batch mixed slurry- 60 bbl. Pumped spacers - volume 70 bbl. Mixed and pumped slurry - 60 bbl. Displaced slurry - 198 bbl. Reverse circulated at 9530 ft. Pulled Drillpipe in stands to 8590 ft. Circulated at 8575 ft. Pulled Drillpipe in stands to 0 ft. Laid down HWDP to 1637 ft. Held safety meeting. Laid down HWDP to 564 ft. Made up BHA no. 8. Feb 3 1996 (20) Made up BHA no. 8. Circulated at 2313 ft. R.I.H. to 5200 ft. Serviced Block line. R.I.H. to 11779 ft. Circulated at 11779 ft. Tested Casing - Via string. Circulated at 11779 ft. Pulled out of hole to 10771 ft. Held safety meeting. Pulled out of hole to 2313 ft. Pulled BHA. Feb 4 1996 (21) Rigged up sub-surface equipment- Perforating tools. Rigged up sub-surface equipment - Gun assembly. Held safety meeting. Ran Drillpipe in stands to 11779 ft. Held safety meeting. Perforat- ed from 10910 ft to 11650 ft. Reverse circulated at 11779 ft. Rigged down High pressure lines. Laid down Drillpipe to 9880 ft. Feb 5 1996 (22) Laid down Drillpipe to 0 ft. Retrieved Wear bushing. Ran Tubing to 1000 ft (4.5 in OD). Held safety meeting. Ran Tubing to 8500 ft (4.5 in OD). Held safety meeting. Ran Tubing to 9538 ft (4.5 in OD). Reverse circulated at 9538 ft. Page 4 Operations Summary for: Feb 6 1996 (23) Reverse circulated at 9538 ft. Set packer at 9479 ft with 4000 psi. Installed Hanger plug. Rigged up All rams. Held safety meeting. Rigged down BOP stack. Installed Xmas tree. Retrieved Hanger plug. Freeze protect well - 145 bbl of Diesel. Installed Hanger plug. Page 5 SPi .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 .HA_RED SERVICES DRILLING PBU/D-28A 500292155601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 012996 MWD SURVEY JOB NUMBER: AK-MM-960102 KELLY BUSHING ELEV. = 78.66 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10071.36 8552.70 8474.04 10080.00 8558.11 8479.45 10204.52 8645.44 8566.78 10236.17 8669.96 8591.30 10267.91 8694.69 8616.03 51 13 51 18 39 26 38 59 38 40 N 7.42 E .00 3743.20N 140.00W N 7.41 E .92 3749.88N 139.13W N 3.20 E 9.83 3837.90N 130.62W N 3.90 E 1.99 3857.87N 129.38W N 3.30 E 1.56 3877.73N 128.13W 3742.83 3749.43 3836.52 3856.34 3876.04 10299.47 8719.56 8640.90 37 16 10331.21 8744.94 8666.28 36 31 10362.76 8770.34 8691.68 36 14 10390.42 8792.70 8714.04 35 53 10407.50 8806.56 8727.90 35 39 N 1.60 E 5.51 3897.13N 127.30W N 1.60 W 6.51 3916.18N 127.30W N 2.60 W 2.08 3934.88N 127.98W N 3.00 W 1.52 3951.14N 128.78W N 4.42 W 5.06 3961.11N 129.42W 3895.32 3914.31 3933.01 3949.29 3959.27 10439.21 8832.42 8753.75 35 7 10471.02 8858.45 8779.79 35 4 10502.73 8884.01 8805.35 37 28 10535.26 8909.23 8830.57 40 52 10561.98 8929.03 8850.37 43 30 N 3.10 W 2.93 N 9.25 W 11.11 N 12.81 W 10.04 N 14.16 W 10.78 N 15.63 W 10.51 3979.43N 130.63W 3997.59N 132.59W 4015.99N 136.20W 4035.97N 140.99W 4053.31N 145.61W 3977.63 3995.89 4014.52 4034.80 4052.44 10593.70 8951.36 8872.70 10625.43 8972.21 8893.55 10641.75 8982.17 8903.50 10657.19 8990.95 8912.29 10673.57 8999.59 8920.93 46 58 50 52 53 59 56 40 59 37 N 18.60 W 12.80 N 14.58 W 15.56 N 12.83 W 20.92 N 13.75 W 18.10 N 11.03 W 22.87 4074.82N 152.25W 4097.73N 159.05W 4110.30N 162.12W 4122.66N 165.04W 4136.24N 168.02W 4074.40 4097.77 4110.54 4123.09 4136.86 10689.03 9007.13 8928.47 61 57 10741.94 9027.39 8948.73 72 56 10770.12 9033.78 8955.12 80 51 10804.94 9037.26 8958.60 87 39 10836.55 9038.09 8959.43 89 19 N 13.16 W 19.28 N 11.23 W 21.02 N 11.73 W 28.16 N 9.87 W 20.24 N 11.11 W 6.55 4149.44N 170.85W 4197.13N 181.12W 4224.00N 186.58W 4258.02N 193.06W 4289.08N 198.82W 4150.24 4198.58 4225.80 4260.21 4291.62 10867.56-9038.22 8959.56 10899.34 9038.06 8959.40 10931.01 9037.72 8959.06 10962.73 ~9037.19 8958.53 10991.83 9036.57 8957.91 90 10 N 10.28 W 3.85 90 25 N 12.20 W 6.09 90 46 N 12.30 W 1.12 91 10 N 10.76 W 5.02 91 15 N 13.89 W 10.76 4319.55N 204.57W 4350.72N 210.76W 4381.66N 217.48W 4412.74N 223.82W 4441.15N 230.03W 4322.45 4354.00 4385.37 4416.84 4445.65 11023.57 9035.90 8957.24 11055.17 9035.28 8956.62 11086.23 9034.71 8956.05 11118.34 9034.22 8955.56 11150.00 9034.28 8955.62 91 8 91 7 90 58 90 44 89 2 N 12.89 W 3.17 4472.02N 237.38W N 12.73 W .50 4502.83N 244.38W N 11.72 W 3.29 4533.18N 250.96W N 13.16 W 4.55 4564.53N 257.88W N 11.42 W 7.68 4595.46N 264.61W 4477.00 4508.26 4539.02 4570.81 4602.17 SP5 Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE .iARED SERVICES DRILLING PBU/D-28A 500292155601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 012996 MWD SURVEY JOB NUMBER: AK-MM-960102 KELLY BUSHING ELEV. = 78.66 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11182.32 9034.78 8956.12 89 11 N 11.47 W .52 4627.13N 271.03W 4634.24 11214.30 9035.12 8956.46 89 35 N 10.70 W 2.71 4658.51N 277.17W 4666.00 11246.12 9035.36 8956.70 89 30 N 8.77 W 6.07 4689.87N 282.55W 4697.68 11279.54 9035.25 8956.59 90 51 N 8.42 W 4.17 4722.91N 287.55W 4731.01 11311.25 9034.75 8956.09 90 57 N 8.97 W 1.76 4754.25N 292.34W 4762.63 11339.03 9034.34 8955.68 90 44 N 10.97 W 7.24 4781.61N 297.15W 4790.27 11374.74 9034.09 8955.43 90 3 N 10.77 W 1.99 4816.67N 303.88W 4825.76 11406.90 9034.11 8955.45 89 52 N 8.31 W 7.67 4848.38N 309.21W 4857.78 11438.34 9033.79 8955.13 91 15 N 10.71 W 8.81 4879.39N 314.41W 4889.09 11469.88 9033.22 8954.56 90 49 N 9.72 W 3.42 4910.42N 320.00W 4920.47 11500.65 9032.76 8954.10 90 51 N 8.85 W 2.83 4940.78N 324.96W 4951.12 11532.38 9032.00 8953.34 91 54 N 11.39 W 8.66 4972.01N 330.54W 4982.68 11564.15 9030.87 8952.21 92 9 N 10.80 W 2.00 5003.16N 336.65W 5014.22 11595.78 9029.65 8950.99 92 16 N 9.19 W 5.10 5034.29N 342.13W 5045.67 11627.40 9028.26 8949.60 92 45 N 10.33 W 3.91 5065.42N 347.48W 5077.12 11658.95 9027.12 8948.46 91 22 N 10.83 W 4.65 5096.41N 353.27W 5108.47 11690.86 9026.30 8947.64 91 34 N 9.13 W 5.36 5127.82N 358.80W 5140.22 11721.19 ~9025.69 8947.03 90 44 N 8.89 W 2.85 5157.77N 363.55W 5170.44 11752.71 9025.53 8946.87 89 50 N 9.35 W 3.18 5188.89N 368.55W 5201.85 11795.49 9025.97 8947.31 88 56 N 9.85 W 2.41 5231.07N 375.68W 5244.46 11866.00 9027.27 8948.61 88 56 N 9.85 W .03 5300.52N 387.74W 5314.64 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5314.69 FEET AT NORTH 4 DEG. 11 MIN. WEST AT MD = 11866 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 355.57 DEG. TIE IN POINT 10071.36' WINDOW POINT 10080' INTERPOLATED DEPTH 11866' SPt .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ~HARED SERVICES DRILLING PBU/D-28A 500292155601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 012996 JOB NUMBER: AK-MM-960102 KELLY BUSHING ELEV. = 78.66 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10071.36 8552.70 8474.04 11071.36 9034.96 8956.30 11866.00 9027.27 8948.61 3743.20 N 140.00 W 1518.66 4518.62 N 247.94 W 2036.40 517.74 5300.52 N 387.74 W 2838.73 802.33 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE H3kRED SERVICES DRILLING PBU/D-28A 500292155601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 1/96 DATE OF SURVEY: 012996 JOB NUMBER: AK-MM-960102 KELLY BUSHING ELEV. = 78.66 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10071.36 8552.70 8474.04 3743.20 N 140.00 W 1518.66 10111.83 8578.66 8500.00 3774.00 N 136.19 W 1533.17 14.51 10247.36 8678.66 8600.00 3864.90 N 128.91 W 1568.70 35.53 10373.06 8778.66 8700.00 3940.96 N 128.26 W 1594.40 25.70 10496.05 8878.66 8800.00 4012.08 N 135.37 W 1617.39 22.98 10636.02 8978.66 8900.00 4105.89 N 161.06 W 1657.36 39.98 11866.00 9027.27 8948.61 5300.52 N 387.74 W 2838.73 1181.37 THE-CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASK~--'~.IL AND GAS CONSERVATION COMMISSIOh: REPORT O. SUNDRY WELL OPE .ATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging__ Pull tubing_ Alter casing Repair well__ Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1496' SNL, 1692' WEL, SEC. 23, T11 N, R 13E, UPM At top of productive interval 2230' NSL, 1834' WEL, SEC. 14, T11N, R 13E, UPM At effective depth 2093' SNL, 1697' WEL, SEC. 14, T11N, R13E, UPM At total depth 2053' SNL, 1691' WEL, SEC. 14, T11N, R13E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service 12. Present well condition summary Total depth: measured 11208 feet Plugs (measured) true vertical BKB 9109 feet Effective depth: measured 11165 feet Junk (measured) true vertical BKB 9093 feet Casing Length Size Cemented Structural -- Conductor 67' 20X30" 8 cu. yds. Surface 2627' 13-3/8" 3720 c.f. Intermediate 9839' 9-5/8" 575 c.f. Production -- Liner 1569' 7" 480 c.f. Perforation depth: measured 10948'-11054' true vertical subsea 8929'-8980' Tubing (size, grade, and measured depth) 5-1/2" L-80 to 9596' with 4-1/2" tailpipe to 9717' 6. Datum elevation (DF or KB) KBE=71.46 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-28 (33-14-11-13) PBU 9. Permit nq.~er/appr,.~ova/I numb~er,,...2 10. APl number "~ ¢¢ ,.~- .2,.- /..:3 I 50- 029-21556 I 11. Field/Pool Prudhoe 0il Pool Measured depth 110' 2670' 9882' 9639'- 11208' Packers and SSSV (type and measured depth) 9-58" TlWpackerat9596~ 5-1/2" SSSV at 2082' 8281~9109' Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 2011 27758 20 Subsequent to operation 2369 39065 24 15. Attachments I 16. Status of well classification as: Copies of Logs and Survey,,,sd'-~n ~ ~ Daily Repo~of We~l Ope/Ctions ,- / I Oil._X_. Gas__ Suspended 17. I ~hereby c/~ify th~ the/V~reg.,eing is t.,r~,e ~nd ~correct to the best of my knowledge. Signed,~//~,.,~.~/~.,.¢ /~/~//"~...-¢/..-~,.~"'' Title TechnicalAssistant III Form 1'0-40d Rev 06/15/88 /; .... "'~ ~ ' Tubing Pressure 858 952 Service Dat e~-.~/"~i_~ ~,2 SUBMIT IN DUPLICATE 14. 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth BKB 110' 2670' 8434' 5/11/95 WELL D-28 (33-14-11-13) Addperf The following additional interval were perforated using 3 3/8" guns, 4 SPF, random orientation and 60/120© phasing. 10624- 10629 MD' MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 22,1996 THRU: Blair Wondzell,~~' FILE NO: P. I. Supervisor aiflavdd.doc FROM: John Spaulding,'~ .re. SUBJECT: Petroleum Insp, BOPE Test Doyon 9 BPX PBU D-28 A Prudhoe Oil Pool PTD Monday January 22, 1996: I traveled this date to BPX's PBU well to witness the BOPE test on Doyon rig 9. The AOGCC test report is attached for refernce. i found the rig BOPE to be in excellent condition with 1 failure observed on the inside BOP. This valve was repaired immediately and testing was resumed'. The area surrounding the rig is being kept in an orderly fashion allowing good access to the rig. Summary: I witnessed the BOPE test on Doyon rig 9 with 1 failure, 4 hour test time. Attachments: aiflavdd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: DATE: 1/22/96 Doyon Rig No. 9 PTD # 95-213 Rig Ph.# 659-4832 BPX Rep.: Jesse New D-28A Rig Rep.: Tim Krupa Set @ 10,075' Location: Sec. 23 T. 11N R. 13E Meridian UM Weekly Other TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign ok Drl. Rig ok Hazard Sec. ok Quan. Test Press. P/F 300/3,000 P 500/5,000 P 500/5,000 P 500/5, 000 P 500/5,000 P 500/5,000 P 500/5,000 P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 500/5,000 P 500/5, 000 P 500/5,000 P 500/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 500/5, 000 P 38 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure PresSure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5 @ 2400 avg. 3,050 [ P 1, 700 P minutes 36 sec. minutes 24 sec. Yes Remote: Yes Psig. TEST RESULTS Number of Failures: I ,Test Time: 4.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Dart valve failed on Iow pressure test; valve was rebuilt and retested Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AIFLAVDD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION December 26, 1995 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Terry Jordan, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 .~mchorage, AK 99519-6612 Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit D-28A BP Exploration (Alaska), Inc. 95-213 1496'SNL, 169ZWEL, Sec 23, T1 iN, R13E, UM 1456'SNL, 2098'WEL, Sec 14, TllN, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W Chairman BY ORDER OF TI-rE COMMISSION ljb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 .a. Typeofwork Drill lEI Redrillfqllb. TypeofwelI. Exploratoryl~l Stratigraphic Test[] DevelopmentOil[] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration Plan RTE = 78 f e et Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1496' SNL, 1692' WEL, SEC. 23, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2436' SNL, 1913' WEL, SEC. 14, T11N, R13E D-28A 2S100302630-277 At total depth 9. Approximate spud date Amount 1456' SNL, 2098' WEL, SEC. 14, T11N, R13E 01/01/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well t4. Number of acres in property 15. Proposed depth (MD andTVD) property line ADL 028280 1456 feet D-07, 510'at 11675'MD feet 2560 11866'MD/9022'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth lOO7~ feet Maximum hole angleg~.39 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 BTC-Mod 1941' 9925' 8388' 11866' 8945' 211 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEiV Surface Intermediate Production21 995 Liner Perforation depth: measured AJasks0il&GasCorls. Commissk)l~ true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing_is true and correct to the best of my knowledge \~q~f~¥r~¢¢¢fzl '~f~'''-''/' '' TitleSeniorDrillin~Engineer ~/ t Signed Commission Use Only Permit Number IAPI number Approva~l date/ See cover letter ?,-~'-'-~/~ 150'0'2''~'-'2'/''~'''y'~''''c::)/ I /z:2,/'~//"~'~'''-'- for other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes ,1~ No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE 1-12M; FI3M; I~5M; I-IIOM; I-I15M; Other: LIJ'i[jll'ial Signed 6y by order of ,-Appr°ved.~ .~.bY _ David ..... W. dohnst0n Commissioner tne commission Date /~.~..~ Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: [D-28A Redrill Plan Summary [Type of Redrill [ Shut In Producer I Surface Location: 1496' FNL, 1692' FEL, S23, T1 IN, R13E, UM Target Location: 2436' FNL, 1913' FEL, S14, T1 IN, R13E, UM Bottom Hole Location: 1456' FNL, 2098' FEL, S14, Tl lN, R13E, UM [AFE Number: 14P8018.0 I I Rig: I Doyon9 [Estimated Start Date: [Jan. 1, 1995 I [Operating days to complete: IMD: I11866 I I TVD: 19022' brt I IRTE I 22 [Well Design (conventional, slimhole): I Horizontal Sidetrack [ Objective [ To recover present Zone 2 reserves. Mud Program: Used Flo-Pro will be used as a milling fluid. New Flo-Pro will be used in horizontal section Horiz. I 9.0 I 10 140-451 23 I 29 [ +6cc [ 0 [ 0 Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVDss MD/TVDss 6 4.5" liner 12.6# L-80 mc-Mod 1941 9925/8388 11866/8945 N/A 4.5" tb~ 12.6# L-80 Btc-Mod 10045 Surface 10045/8727 Cement Calculations: Liner Size: [ 4.5" production liner Basis:130% open hole excess, 80' shoe joint, 150' liner lap and 200' excess above liner Total Cement Volume: [ 211 I sxs of Class (3 Blend @ 1.17 ft3/sx ( Estimated Volume ) Directional-. Sidetrack KOP: 10075' MD Build to horiz. KOP: 10869'MD Maximum Hole Angle: Close Approach Well: 91.39 degrees @ 11409 D-07: 510' away at 11675' MD Well Control: RECEIV -o OEC 2 1 1995 Alaska 0il & Cas Cons. Commission Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Drilling Hazards: ° Maximum anticipated BHP: 4390psi @ 8800' ss o Maximum surface pressure 3330 psi @ 8800' ss o Planned Completion Fluid: 8.6 ppg filtered sea water a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fO. c. The most recent H2S level on this well was measured at 11 ppm (7/24/95). e. Drilling Hazards: · A gas zone is present from Top of Sag River to the current GOC. · KOP will be 70' TVDss below a fault. Another 20'-40' fault will be crossed in Zone 2. Lost circulation is a possibility near these fault zones. December 20, 1995 Pre-Rig Work 1. D-28A Operations Summary R/U slick line, RIH and pull SSSV at 2082' MD. 2. R/U cement unit & establish an injection rate. Bullhead and squeeze perforations at 11054'- 10624' MD. Displace to leave the top of cement in 7" Liner @ no lower than 10524' MD. Pressure test as per AOGCC requirements. ( Volume of cement should be 20 bbls plus 10 bbls excess squeezed for the total volume of 30 bbls ) 3. R/U E-line, tag cement plug, verify at least 100' above perfs. Pick up and cut 5-1/2" tbg in the middle of the first full joint above the tubing seal assembly. The seal assembly is at 9580' MD, so the cut should be made at -9553' MD. 4. Freeze protect the top 2200' MD of inner annulus with diesel. 5. Test 9-5/8" mandrel pack-off to 5000 psi. 6. Bleed off any pressure from tubing and inner/outer annuli. 7. Set BPV & test from below to 1000 psi. Secure well. 8. Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Please provide total well preparation cost on the handover form. Rig Work: ENSURE THAT AN APPROVED PERMIT FROM THE AT THE RIG PRIOR TO SPUDDING D-28A. L) . , . , . . , , (Note: All work to be completed as per Recommended Practices) OEC 21 1995 . MIRU drilling rig. Alaska 0il & Gas Cons. Commismi0n Anchorage Pull BPV. Circulate out freeze protection from inner and outer annuli and recover for future use. Test 9-5/8" mandrel packoff to 5000 psi. If pack-off fails, change out packoff in Step 10 prior to cutting the section. Install a TWC and test from below to 1000 psi. ND the production tree. N/U BOP. Test BOP to 250/5000 psi against TWC. Test annular preventer to 250 /2500 psi. Remove TWO. Send adapter flange and tree to DSM for inspection and repair. Pull and lay down the 5-1/2" tubing. (Tubing should be chemical cut at 9553' MD. Check the location and exact depth of the cut on production handover form) Inspect for NORM. Label tubing as it is laid down with well name and joint number. Install thread protectors on pipe which upon visual inspection appears to be re-usable. If tubing is salvageable, send tubing to Tuboscpoe for inspection. TIH with 8-1/2" overshot assembly with 5-1/2" grapple to the tubing stub. Establish all weights prior to engaging fish. Engage fish with overshot and attempt to release anchor latch by rotating 10-15 turns to the right at the packer. If this is unsuccessful, shear off the SBR, pinned at 85,000#. Circulate bottoms up and POOH. If anchor latch and SBR were recovered, proceed to Step 8, TIH with 8-1/2" overshot with 6-1/2" grapple to top of slick stick at _+9580' MD. Establish all weights prior to engaging fish. Engage fish and set grapple. Rotate anchor latch out of packer with 10-15 turns to the right at the packer. POOH with slick stick and anchor. TIH with 8-1/2" packer mill with 4-3/4" catch PRT to top of TIW HBBP packer at _+9596' MD. Establish all weights prior to milling packer. After packer drops, circulate bottoms up to remove any trapped gas. Push packer to top of 7" liner at 9639' MD. POOH with packer. TIH with 5-7/8" reverse basket assembly to PBTD (11165' MD) in 7" liner to clean up any remaining packer junk. Circulate bottoms up and POOH. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. Test casing to 3500 psi for 30 minutes to ensure casing integrity. Bleed off pressure. If 9-5/8" mandrel packoff did not test in Step 2, pull and replace packoff through the BOP stack. P/U section mill on 5" DP & RIH to 10524" MD. Displace hole to drilling fluid (which will be used as milling fluid) and spot 18 ppg mud up to the base of the proposed 7" section, 10125' MD. Pull up to 10075' MD. Cut window from 10075' to 10125'. POOH after ensuring the hole is clean and free of metal cuttings. RIH open ended to 10225' MD and spot a kick-off plug from 100' below the base of the section to -200' above the top of the section (8075' MD). Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve a 1000- 2000 psi squeeze but do not displace TOC below 100' above section top. POOH and function rams to clear cavities and test BOP's. RIH with 6'_' steerable assembly (MWD/GR) on 3-1/2" drillpipe. Dress the cement to 5' below the section top. Circulate h~)le clean. Kickoff and directionally drill to Zone 2 (through the chert if possible). POOH. TIH with 6" steerable assembly (MWD/GR/4-Phase Real Time Resistivity). Displace to new FIo-Pro system. Drill build section to horizontal at 14°/100' to horizontal. POOH. RIH with 6" PDC bit on Halliburton "Short Stack" motor. Drill to 11866' TD. See attached directional plan #7. RIH with hole opener (MWD/4-Phase Real Time Resistivity)to TD of horizontal section. Trip speed should be no greater than 900 fph while tripping in the production zone, to allow Resistivity logging of the target intervals. RIH with 4-1/2", 12.6#, L-80, BTC-Mod liner (possibly with 4-1/2" isolation packer) with 4-1/2"x7" packer/hanger spaced out for 150' of lap. Cement the liner in place with the total cement volume based on 30% excess across the reservoir, 150' liner lap, top of cement 200' above the liner with drillpipe in the hole, and 80' shoe volume. Set liner hanger and packer. Unsting running tool and reverse circulate excess cement from the wellbore. POOH. RIH with 33/4" mill on mud motor. Clean out to landing collar. Test liner and liner lap to 3500 psi. for 30 minutes. Displace the hole to filtered seawater. POOH. RIH with 23/4" drillpipe conveyed perforating guns and perforate the 41/2" liner. POOH and lay down guns. RIH with ,~1/ ,, · -~-L2, 12.6#, L-80 NSCT completion with SSSV, GLMs, and 7"x 41/2'' packer. The bottom 2 GLMs will be the ultraslim design to fit in the 7" liner, upper 3 GLM's will be conventional 4-1/2"x 1-1/2" mandrels. Set packer and test tubing to 4000 psi. Refer to the Recommended Practices for Running Tubing, V3.2. Set TWC valve. Test to 1000 psi. ND BOPs. NU tubing head adapter and tree. Test same to 5000 psi. Pull TWC valve. Test 41/2''x 7" annulus to 3500 psi with 2000 psi on tubing. Shear RP valve. Freeze protect well through shear valve in top GLM station. Set BPV. Release rig. Complete appropriate documentation and handover to Production. RECEiVbU OEC 2 1 1995 Alaska Oil & Gas Cons. Commission Ampoule dd Services Drilling ~tute Plane: Zone'~-~ WOA: 1)-Pad -~SA Wp7 i-IALLIBURTON 7 ' 7O ' 16~ I ! · t.0o' 2.41. ~'- 42' t.l~' .-,5OOO .490O -4700 -45O0 ~0 200 RECEiV L 2 1 1995 vr.~c~ v~ ~/VELL PLAN PROFILE SUMMARY sc~z,oon./t~. IsTRaT~o ~Ouo I~~ ~ ~F: 5gC~O~F: ~ 10075 it305Jvin~o, section in exls:ing 7' Liner. Kickou: Jlth 6' ~ssembJy =: B'/IOO' ~o IncLination OF 38' J i~nd ~zimu~h oF 349', ~0305 ~10497 ?alntaln ~ ~*ngent through Zone 3, I ~ ~ ' ~ ~ 10497 ~iCB69 [S~r~ oF buitd ~: I4'/t00' ~o IncUna:lon oF 90' and azimuth oF 349'. J ~' . ...... J [0869 jtJ387JMmlnt~in ~ horlzontml t~ngent thr~gh Zone 1. J ~ ~,-. ~,. ~ I I I aa~ ~ 7 r e ~ ~ t1387 11409 }Sz~rt oF curve =t 6'/I00' to 91.39' ot 349' ~zlmu%h %o cUmb Into Zone 2, 4 .4& ~ e J 82~9~ ........... ~ ~33~ ............. 4 4 ~/g' Tlr ~ck~ 1 ' ' 8~7. .... ~ ........... ~"~'. ............... ~*~ ~ r~?~ ~ee ~: ~ I .1409 II~590 Nain~a:n :~ngent up ,n~o Zone 2. e4~+ ........ ~ .................~ ~47e L-~ I ~ j ?~ ......................... 3~ ......................... -e ~ r z 4/4 ~ SE~0N ~: 355.5~ CAS[NG POINT DATA J OD MD [nc Azi TVD N/S E/V 1/2 In [1866 90.00' 349,74' 9022 5320 N 4[2 V CRITICAL POINT DATA ND [nc Azl. Top S~ / 10047 51.26'7.5[' Zone 4 / 48 KOP / TIE IN / t0075 5t.28'7.41' INTERq~DLATED POINT / START DF CURVE ~ 8,00'/I00 Ft ~ Zone 3 t0303 38.11'349.21' DF CURVE t0305 38.00'349.00' Top Zone 2 / t04tt 38.00'349.00' 2C START OF BUILD t0497 38.00'349.00' E !4,00'/100 PG~C 10547 44.9~'349.00' Top Zone I / t0724 69,75'349.00' START OF 1086990.00'349.00' CURVE ~ 0,02'/100 F~ Zi£n~ (Ac~u~[) [1387 90.06'349.05' / START DF ~dRVE ~ 6.00'/t00 Ft £ND DF CURVE11409 91.39'349.03' STARt DF 11590 91.39'349.03' CURVE 6.00'/I00 f~ END OF CURVE11616 90,00'349,74' TD 11866 90.00'349.74' TVD N/S E/V 8537 3726 N 142 V 8554 3747N 139V 8717 3906 N 14t V 8719 3907 N 141 W 880~ 3971N 154~ 8870 4024 N164V 8907 4056 ~170 ~ 9002 420t t99 902~./~4340 N 226W 90~7 4849 N324~ 9027 4871N 328q 9022 5048 N363q 9022 5074 ~ 3~8 ~ 9022 5320 412 T~rget N~me .~ D-28APo~¥gon p~l' Z~End ZIEnd TD PoL¥ poln: 2 Pray poln~ 3 P~y point 4 ~ Poty point t BTarg (Actuo. t) A?7 ....... WELL DESIGN TVD NS EV Grid X Grid Y 9012 5315 N fBI V 653169 5964802 9022 5074 N 368 V 652987 5964557 9027.4849 N 324 V 6534J35 596433~J 902~ 5320 N 412 V 65293~ 596480~ 9012 53~5 N 644 V 6527d6 5~6480~ 9012 4331N 495 V 652875 59638t2 9087 4388 N 801V 653169 5963815 901~ 5315 N 181V 653169 5964802 9027 4337 N 828 V 653148 5963823 PLOT INFORMATION · . DRAWING NAME / FILE NAME SURFACE LO~ATION PROPO3ED BIlL aaM~a~p~e,. J ~ ~m ~ 9022.01 ~ 11886.37 y: ~ 0319.90 ~to :~ ~fi~ By ERMIT CHECKLIST PROGRAM: exp [] der [] redrll.~ serv [] ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. N 10. Operator has appropriate bond in force ........ N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. N 13. Can permit be approved before 15-day wait ....... N REMARKS 14. Conductor string provided ................ Y N)~ ~.^~,~~ 15. Surface casing protects all known USDWs ......... Y N . 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~ N 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ............ ~ ....... ~ N 26. BOPE press rating adequate; test to b ~i> psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2s gas probable ............ -~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/w/ 31. Data presented on potential overpressure zones ..... Y//N 32. Seismic analysis of shallow gas zones .......... ~ N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/Ijb - AflFORMS~cheklist rev 11/95 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. Tape Subfile 2 is type: TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 M. HALL J. NEW D-28A 500292155601 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 22-JAN-97 MWD RUN 2 M. GABEL MWD RUN 3 M. GABEL MWD RUN 6 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M. GABEL R. BORDES WELL CASING RECORD 23 liN 13E 1496 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 11866.0 MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL WAS KICKED OFF AT 10075' MD. MWD RUN 1 WAS DIRECTIONAL AND GAMMA RAY (SCINTILLATION TYPE). MWD RUNS 2 & 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (GEIGER MUELLER TYPE) AND PHASE 4 RESISTIVITY (EWR4). MWD RI/NS 4 & 5 WERE DIRECTIONAL ONLY & ARE NOT PRESENTED. MWD RUN 6 WAS DIRECTIONAL WITH DUAL GAMMA RAY (GEIGER MIIELLER TYPE) AND PHASE 4 RESISTIVITY. A MEASURED AFTER DRILLING (MAD) PASS WAS RUN FROM 10648 - 11865'. THIS ~ PASS CONSISTS OF DUAL GAMMA RAY (GEIGER MUELLER TYPE) AND PHASE 4 RESISTIVITY. THIS WELL REACHED A TOTAL DEPTH OF 11866'. NO DEPTH S' '~TS WERE APPLIED PER GREG BP EXPLOk~TION (ALASKA) INC. RNASKI OF FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 10071.0 10365.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 11809.0 11816.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 9840.0 10445.0 2 10445.0 10604.0 3 10604.0 10744.0 6 10798.0 11866.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM FET MWD 68 1 HR ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 DATA RECORD (TY~ % 0 ) Total Data Records: 119 998 BYTES * Tape File Start Depth = 11890.000000 Tape File End Depth = 10055.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 29369 datums Tape Subfile: 2 217 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: L~S FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: CN WN FN COUN STAT START DEPTH 10648.0 10655.0 STOP DEPTH 11808.0 11815.0 MAD RUN NO. MAD PASS NO. MERGE TOP 1 6 10704.0 MERGE BASE 11865.0 MAD PASS LOGGED AFTER MWD RUN 6. $ : BP EXPLORATION (ALASKA) : D-28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 RATE MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 82 Tape File Start Depth = 11870.000000 Tape File End Depth = 10600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20329 datums Tape Subfile: 3 106 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfite 4 is type: LAS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10071.0 $ 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: 'MAXIMUMANGLE: STOP DEPTH 10360.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: MWD RUN 1. 24-JAN-96 1.32 5.74 MEMORY 10445.0 9840.0 10445.0 0 35.9 41.5 TOOL NUMBER NGP 196 6.000 .0 FLO-PRO 9.00 102.0 12.0 31000 .0 .000 .000 .000 .000 .0 137.5 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-28A : PRLrDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 10 Tape File Start Depth = 10450.000000 Tape File End Depth = 10055.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31743 datums Tape Subfile: 4 73 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LiS FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10360.0 EWR4 10365.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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) MINIM UMANGLE: MAXIMUM ANGLE: STOP DEPTH 10549.0 10556.0 24-JAN-96 1.32 5.74 MEMORY 10604.0 10445.0 10604.0 0 35.1 40.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0475SP4 P0475SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 .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 TEMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.90 75.0 10.0 35000 5.6 .140 .060 .140 .100 80.0 165.0 78.O 9O.O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 2. $ : BP EXPLORATION (ALASKA) : D-28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 995 99 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 18 Tape File Start Depth = 10620.000000 Tape File End Depth = 10350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24658 datums Tape Subfile: 5 83 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 6 is type: FILE HEADER FILE NIIMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10549.0 EWR4 10556.0 $ 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: STOP DEPTH 10702.0 10709.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 25-JAN-96 1.32 5.74 MEMORY 10744.0 10604.0 10744.0 0 43.5 62.0 TOOL NUMBER P0475SP4 P0475SP4 6.000 .0 FLO-PRO 8.90 73.0 9.0 41000 6.2 .140 .060 .140 .100 80.0 166.0 80.0 88.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3. $ : BP EXPLORATION (ALASKA) : D-28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 995 99 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 15 Tape File Start Depth = 10750.000000 Tape File End Depth = 10525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35352 datums Tape Subfile: 6 80 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 7 is type: FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10702.0 EWR4 10709.0 $ 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: STOP DEPTH 11809.0 11816.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 30-JAN-96 1.32 5.74 MEMORY 11866.0 10798.0 11866.0 0 87.7 92.8 TOOL NUMBER P0475SP4 P0475SP4 6.000 .0 FLO-PRO 9.00 72.0 11.0 44000 6.2 .130 .060 .130 .120 76.0 170.0 70.0 85.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 995 99 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 77 Tape File Start Depth = 11890.000000 Tape File End Depth = 10700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 43707 datums Tape Subfile: 7 142 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 8 is type: L-S FILE HEADER FILE NI/MBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10648.0 EWR4 10655.0 $ 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: STOP DEPTH 11808.0 11815.0 30-JAN-96 1.32 5.74 MEMORY 11866.0 10648.0 11815.0 0 87.7 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0475SP4 P0475SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 .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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 9.00 72.0 11.0 44000 6.2 .130 .060 .130 .120 76.0 170.0 70.0 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): .0 ~WR FREQUENCY (HZ) : REMARKS: MAD PASS LOGGED AFTER MWD RUN 6. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D-28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 FET MAD 68 1 HR 4 7 SRAT MAD 68 1 FPHR 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 82 Tape File Start Depth = 11870.000000 Tape File End Depth = 10600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55681 datums Tape Subfile: 8 148 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 9 is type: LiS 97/ 1/22 01 **** REEL TRAILER **** 97/ 1/22 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 22 JAN 97 10:56a Elapsed execution time = 2.64 seconds. SYSTEM RETURN CODE = 0 PRUDHOE BAY 1 o i I i I ~/,.. ~1~ i i ~ ~:!~ & ~ ~---~J_..~ //) / ~~~ ~ . I ~c~-; ,_ ~~ ~:.:~:a:~:~: ~::-:: ~,~:~?~:::.-:'-~::- :.: ~'?"- i//' ~/'/---.~'"~'~': .... '~ :-~-~.,~/' .... '; ~' ~?~;:.? ~:'i:)~ ~:~t/'-z:t~: :'~,'~t~ :~.. ~: .~, ~__ >"~i - , ~, -. = -~ :~,- =- :_~ _~-.----..~-,:--. .:.~ .: : .... . ../." .:. / ~- ~- . '. ~/' / .c ~ =' Y. ~ _ / ~;~d:-~/~--.~::~: ...... :'.::.":~'-.. ~ .... ~ ~ ~ ' .... - [ ~' ,~:~ :"::- ~..x-: 7 ,. ~:;/ ,~:-?_-5L~5~';.~'::--:.:.--: :~'~:-':" :~-/5:-- :.-... z'. ~ ' · · ...l~~;'~, ~ I ~, ~ . ~- ~ -~ :~ ~:-_:~_%:;-~,_~.~:._-: ~ -~ ~:: -, .~._ .. ..- ~.. ~ .~ ~ ~ . ~ i ~l ~"~~ ......~,--._.__...~/ ~ ~ · ......... / .... 1 .... ..: :: ._.,- .... ~. . -'- - ~- · -'- - -'..:t~: - '", . , . .% ..-. ~ : , - ~ ~ · --r~~ ~ {'' .%~'~d ~=-_;:_C:.:--.: ...... :'~ t.' ~ "-~-J'" / .... ~ ' ~ - ' 'x ~,~ ,~ 't~r~%~- / ~ : ~' : ~" :~'::'" ' ": :':: :' '~ "':". -' - -- ~ ~' i'~ - - ~:- ' '-. ' ~:~'v: :- --'-" '.'-".:': ..... -. -~-~: .'.~:--~-:-._~,~.':~:-.--~':;:/--.~:~ ~:;~:~;'~::~::X.. ~i I .... / ~' ~ ~ ........... ~-' ........ - .... x- · ~,-:. '-~'.- - '- . ' : I ,:- --r~ ~:%~---~..-~ -~.-~_,- [~" ~'," ~ ~-:':' .... -:' ..... : ' ..... -~ .... '":'"~ ...... ~ --~ ~-~ ..~ 2~ - A~r,! - ! 996 I~.;~;~:.r~..~:~ ! I- ,_ / ~. :: . ~, :.: .-~-:~z : .... :;: : ' : - :"-~ ' :':-:::';' -'~- .... ~/ --': ~ ~ - '~ ~7,~'~2E.%:-~:~:~1 I I ~ - ~'~ .~ ;.' ..... ,':-:. .. ?..'.: ::-- ' .; 2.~'";; .... ~:- . :.. -':..~-- e;.~ ~ % r ~r-' . : ::z:*i '." ..... '.,.~.eC ' · r _'.: u - '.~:~{-. - . - :' " . ~?~.":~.~,¢'~J~4:~;~*:~'~ · z ..... . .:- ..... ,. - ....... ..,... .... ~:-..::::~:~.-: -,-:--.:..-:-...- :,--: -::i u~sad Hole ~:,.~ .......... -:.~:~..~.:.,:~.~ .... - /-" -~'~ .... ".-~ .:- --:':-:- * .... :'::-~ :'- .--::: ~ - ,' I .... /i-_t:%:;,:--_', .... : :-~-. ,z-E-_ ,'- ::- :- -.-.,.:.._ i%-'t.L':~;C't 'E:'-.Y:L:_ :~:-.. '._~: ._ : ~ ~~..:~:~5-:~:.~ ~.~.~~¥,. ~;~ _..- .-, ......... ~ -'. ~ .... . . -, -:-~.: : .'- : '~.'- L :~--": -.~*'.:- '. ~--- ' -:.~.- '- ~~~~-~: ~-~'"~--::~- ~ ~'~' "'-- ~',' ' ~: ...... ~ ............... ~ ' ' - ........ I WESTERN ATLAS Logging Services I I I 0il & Gss Cons. ~'r~rnission ~nchorage ,~e Subfile ,2 is ,type: 'IS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING D - 28A 500292155601 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 12-JUN-96 6550.01 D. BARBA S. KIORPES 23 liN 13E 1496 1692 71.50 70.50 41.70 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7.000 10125.0 29.00 4.500 9538.0 12.60 7.000 9550.0 26.00 4.500 11866.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: MWD GR 2 1 24 -JAN- 96 SPERRY-SUN BASELINE DEPTH 9835.5 10081.0 10130.5 10165.5 10187.0 10204.5 10240.0 10289.0 10305.0 10394.5 10411.0 10432.0 '10447.0 GRCH 9825.0 10070.5 10119.5 10155.0 10176.5 10194.0 10229.5 10282.0 10296.5 10387.0 10403.5 10425.0 10440.5 EQUIVALENT UNSHIFTED DEPTH 10468.5 10485.0 10505.5 10508.0 10509.5 10511.0 10512.5 10552.0 10575.0 10635.5 10654.5 10662.5 10718.0 10733.5 10734.0 10734.5 10735.5 10746.0 10746.5 10805.0 $ REMARKS: 1( 2.0 10~/8.5 10499.5 10501.0 10502.5 10504.0 10505.5 10547.0 10569.5 10630.5 10650.0 10658.0 10713.5 10731.5 10732.0 10733.0 10734.0 10744.0 10744.5 10803.0 CN/GR Cased Hole. TIED INTO CN DATED 21-AUG-94/WALS. PUMPED 200 BBLS SEAWATER PRIOR TO LOGGING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CHISM OFF, CALIPER & CASING CORRECTED, SALINITY = 0.0 PPM. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A. OUT $ ~'ILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9841.0 10750.0 2418 9850.0 10759.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH NPHI 9834.5 9825.0 9914.5 9905.0 9965.5 9956.0 10050.0 10039.0 10080.5 10069.5 10143.0 10131.5 10145.0 10133.5 10165.0 10154.0 10168.0 10157.0 10169.0 10157.5 10169.5 10158.5 10170.0 10159.0 10189.5 10179.0 10195.0 10184.5 10196.0 10185.0 10196.5 10185.5 10198.5 10187.0 10199.5 10188.0 10203.5 10192.5 10208.5 10197.5 10217.5 10206.0 10218.5 10207.0 10219.0 10208.0 10220.5 10209.5 10223.0 10213.0 10229.0 10219.0 10243.5 10235.0 10244.5 10236.0 10252.0 10242.0 10253.0 10243.0 10271.0 10262.5 10271.5 10263.0 10272.0 10263.5 10280.5 10273.5 10284.5 10277.5 10293.5 10286.5 10306.5 10297.5 10307.5 10298.5 10308.0 10299.5 EQUIVALENT UNSHIFTED DEPTH 10308.5 10409.0 10411.0 10425.5 10426.5 10429.5 10431.0 10441.5 10472 · 0 10485.0 10505.0 10551.5 10650.5 10696.0 10718.0 10733.5 10734.0 10734.5 10735.5 10746.0 10746.5 10805.0 $ REMARKS: 1( ~.0 10902.5 10404.5 10418.0 10418.5 10421.5 10423.5 10434.5 10465.0 10478.0 10498.5 10547.0 10646.0 10690.5 10713.5 10731.5 10732.0 10733.0 10734.0 10744.0 10744.5 10803.0 PASS 1. FUCT & NUCT WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH1B. OUT $ : BP EXPLORATION (ALASKA) : D - 28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 40 Tape File Start Depth = 10805.000000 Tape File End Depth = 9825.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9806 datums Tape Subfile: 2 238 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9841.0 10750.0 9850.0 10759.0 BASELINE DEPTH 9846.0 9855.5 9881.5 9888.0 9898.0 9899.0 9899.5 9900.5 -9903.5 9908.0 9908.5 9909.5 9930.5 9949.0 9964.0 9971.5 9972.0 9972.5 9983.0 9983.5 9984.5 9985.0 9986.0 9987.0 9994.5 9995.5 9996.0 9996.5 9997.0 9998.5 9999.5 10001.0 10001.5 10002.0 10002.5 10012.5 10013.5 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 9835.5 9845.0 9870.5 9877.0 9888.0 9889.0 9890.0 9891.0 9898.0 9898.5 9899.0 9984.0 9984.5 9985.0 9986.0 9991.5 9992.5 NPHI 9895.5 9921.5 9939.5 9955.0 9962.0 9962.5 9963.5 9973.0 9973.5 9974.0 9975.0 9976.0 9976.5 9986.0 9987.0 9988.5 9989.0 9990.5 9991.5 10002.5 10003.0 10014.0 10015.0 10015.5 10018,0 10019.0 10024.5 10025.0 10026.5 10027.5 10029.0 10029.5 10031.0 10031.5 10032.0 10033.5 10034.5 10035.0 10035.5 10042.5 10043.5 10045.5 10046.5 10056.0 10057.0 10058.0 10058.5 10059.0 10059.5 10060.5 10067.5 10068.0 10071.5 10075.5 10076.0 10088.5 10096.0 10096.5 10097.0 10100.5 10102.0 10102.5 10109.0 10110.0 10114.5 10123.0 10124.0 10130.5 10131.0 10132.0 10134.5 10135.5 10136.0 10145.5 10150.5 10153.5 10154.0 10154.5 10155.5 10158.0 10158.5 1, ~4.0 10004.5 10005.5 10008.0 10008.5 10018.5 10021.5 10032.5 10033.0 10047.5 10048.5 10049.0 10049.5 10050.0 10078.0 10089.5 10091.0 10092.0 10112.5 10113.0 10125.0 10143.0 10144.0 10144.5 10147.5 10014.0 10015.0 10016.5 10017.0 10018.5 10019.5 10021.0 10021.5 10023.0 10023.5 10024.0 10025.0 10035.0 10035.5 10045.0 10045.5 10056.0 10056.5 10060.0 10064.0 10065.0 10077.5 10084.0 10084.5 10085.5 10097.5 10098.0 10102.5 10119.5 10120.0 10120.5 10123.0 10123.5 10133.5 10139.0 10142.5 10147.0 10159 10162 10162 10167 10168 10168 10169 10180 10182 10185 10188 10189 1019'7 10197 10198 10207 10208 10208 10210 10211 10217 10220 10222 10223 10224 10228 10230 10232 10235 10236 10244 10245 10245 10246 10246 1024-8 10249 10251 10259 10259 10260 10274 10274 10278 10281 10281 10284 10289 10291 10292 10295 10296 10296 10301 10302 10304 10301 10308 10309 10310 .0 .0 .5 .0 .0 .5 .5 .5 .0 .5 .0 .0 .0 .5 .0 .0 .0 .5 .5 .5 .5 .5 .5 .0 .0 .5 .5 .0 .0 .0 .5 .0 .5 .0 .5 .5 .5 .5 .0 .5 .5 .0 .5 .0 .0 .5 .5 .0 .5 .0 .0 .0 .5 .0 .0 .0 .5 .5 .5 .5 i 48.5 10151.5 10152.5 10157.0 10157.5 10158.5 10159.5 10169.5 10171.5 10175.0 10177 · 5 10178.0 10186.5 10186.5 10187.5 10187.0 10196.5 10198.0 10198.5 10199.5 10200.0 10207.0 10209.0 10212.0 10212.5 10213.0 10217.5 10220.0 10222.5 10225.5 10226.0 10234.5 10235.5 10236.0 10236.5 10237.0 10239.0 10239.5 10241.5 10251.5 10252.0 10252.5 10266.0 10267.0 10270.5 10275.5 10276.0 10277.0 10282.0 10284.0 10285.0 10287.5 10288.0 10288.5 10289.0 10292.5 10293.0 10295.0 10293.0 10300.0 10300.5 10302.0 10315.5 10317.0 10318.0 10321.5 10322.0 10331.0 10332.0 10332.5 10335.5 10341.5 10345.5 10346.5 10353.0 10362.5 10365.5 10375.5 10376.0 10376.5 10387.0 10387.5 10388.0 10389.0 10396.5 10399.5 10405.5 10406.5 10407.0 10413.5 10414.5 10422.5 10424.0 10425.0 10425.5 10426.5 10427.0 10427.5 10435.0 10435.5 10436.5 10437.5 10439.0 10439.5 10440.5 10443.5 10444.0 10446.0 10452.5 10453.5 10463.0 10468.5 10469.0 10469.5 10472.0 10472.5 10473.0 10473.5 10474.5 10475.0 10476.0 10478.0 10309.0 10309.5 10418.0 10418.5 10419.0 10429.0 10433.5 10436.5 10437.5 10439.5 10456.0 10461.5 10462.0 10462.5 10466.5 10469.5 10471.0 10313.0 10314.0 10323.0 10323.5 10324.5 10327.5 10334.0 10338.0 10338.5 10345.0 10356.0 10359.0 10368.0 10368.5 10369.5 10380.0 10381.0 10381.5 10382.0 10389.5 10393.0 10399.0 10399.5 10400.5 10407.0 10407.5 10415.5 10416.0 10419.0 10420.0 10427.5 10428.5 10429.5 10430.0 10431.5 10432.5 10445.5 10446.0 10464.5 10465.0 10465.5 10466.0 10466.5 10467.0 10467.5 10483.5 10484.5 10485.0 10489.5 10493.5 10498.0 10499.0 10500.5 10501.5 10505.5 10507.0 10507.5 10509 · 0 10511.0 10511.5 10512.0 10513.5 10514.5 10516.5 10521.5 10522.0 10524.5 10526.0 10526.5 10527.5 10530.5 10531.0 10533.0 10536.5 10537.0 10538.0 10540.0 10547.5 10548.0 10551.5 10552.5 10554.5 10555.0 10556.0 10557.0 10576.5 10625.0 10636.5 10639.5 10646.0 10648.0 10650.5 10653.5 10654.5 10659.0 10660.0 10661.0 10661.5 10662.5 10663.5 10665.5 10695.0 10698.0 10700.0 10701.0 10482.5 10486.0 10490.5 10492.5 10499.0 10505.0 10507.0 10534.0 10541.5 10542.5 10546.0 10546.5 10548.5 10549.5 10550.5 10551.0 10570.5 10631.0 10640.5 10643.5 10646.5 10649.5 10650.0 10654.5 10655.0 10656.0 10657.0 10658.0 10658.5 10660.5 10691.0 10696.0 10476.0 10477.0 10478.0 10493.5 10494.0 10499.5 1O5OO.5 10504.5 10505.5 10507.0 10507.5 10510.0 10515.0 10516.0 10518.5 10519.5 10520.0 10521.5 10524.5 10525.5 10527.5 10532.0 10532.5 10533.0 10549.5 10619.0 10633.5 10688.5 10691.5 10694.0 10706.0 10707.0 10708.0 10713.0 10713.5 10718.0 10737.5 10741.5 10742.5 10746.5 $ REMARKS: 10703.0 10708.0 10709.0 10713.5 10736.5 10741.0 10745.0 10699.0 10699.5 10736.5 PASS 2. FUCT & NUCTWERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH2A. OUT / ??MATCH2B. OUT $ : BP EXPLORATION (ALASKA) : D - 28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 40 Tape File Start Depth = 10805.000000 Tape File End Depth = 9825.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9806 datums Tape Subfile: 3 Minimum record length: Maximum record length: 361 records... 62 bytes 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 9841.0 10750.0 9850.0 10759.0 BASELINE DEPTH 9846.0 9854.0 9855.5 9845.0 9863.5 9879.5 9868.0 9888.0 9876.5 9898.0 9887.0 9914.0 9903.0 9915.0 9903.5 9917.5 9906.0 9927.0 9916.0 9930.0 9931.0 9932.0 9932.5 9933.0 9933.5 9934.5 9936.0 9936.5 9937.5 9938.5 9941.0 9943.0 9932.0 9944.0 9932.5 9944.5 9945.5 9947.5 9936.0 9948.0 9937.0 9948.5 9949.5 9956.0 9960.0 9960.5 9961.0 9962.0 9962.5 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH NPHI 9835.5 9844.5 9854.0 9918.5 9919.5 9920.0 9920.5 9923.5 9924.0 9924.5 9926.0 9927.0 9928.0 9928.5 9931.5 9933.5 9934.0 9934.5 9937.5 9938.0 9946.0 9950.0 9951.0 9951.5 9952.0 9953.0 9965. 9966. 9973. 9981. 9984. 9985. 9986. 9987. 9996. 9997. 9998. 10000. 10001. 10002. 10006. 10006. 10008. 10009. 10009. 10012. 10013. 10013. 10018. 10019. 10022. 10023. 10026. 10027. 10028. 10029. 10032. 10034. 10035. 10044. 10045. 10046. 10053. 10054. 10056. 10057. 10057. 10059. 10059. 10061. 10061. 10062. 10065. 10068. 10071. 10073. 10074. 10075. 10085. 10087. 10092. 10093. 10095. 10096. 10097. 10108. 9973.5 9974.0 9985.0 9986.0 10001.5 10002.5 10007.5 10008.0 10011.0 10011.5 10034.0 10035.0 10046.0 10049.0 10050.5 10051.0 10051.5 10063.0 10063.5 10074.5 10075.5 9956.0 9956.5 9963.0 9969.5 9975.0 9977.0 9988.0 9988.5 9989.5 9991.5 9995.0 9996.0 9997.5 9998.0 9999.0 10002.0 10002.5 10015.5 10016.0 10017.0 10018.0 10021.5 10022.0 10024.0 10033.0 10033.5 10041.5 10042.5 10045.0 10045.5 10047.0 10047.5 10054.0 10057.0 10059.5 10062.5 10063.5 10081.0 10081.5 10083.5 10084.0 10085.0 10096.0 10108.5 10110.5 10111.0 10112.0 10113.0 10114.5 10115.0 10117.0 10130.5 10131.0 10132.0 10136.0 10138.0 10140.5 10141.0 10142.5 10143.5 10144.0 10144.5 10153.0 10158.5 1015.9.0 10160.0 10163.0 10169.5 10170.5 10171.5 10172.5 10178.5 10179.0 10180.5 10182.0 10188.0 10189.0 10196.0 10197.0 10197.5 10198.0 10199.5 10200.5 10221.5 10222.0 10222.5 10223.0 10228.0 10229.0 10233.0 10234.0 10235.0 10236.0 10237.0 10240.0 10241.5 10242.5 10243.5 10244.0 10244.5 10245.0 10246.0 10247.5 10124.5 10127.0 10133.5 10141.0 10147.0 10147.5 10152.5 10159.0 10159.5 10177.0 10177.5 10186.0 10187 · 0 10217.0 10233.0 10097.0 10099.0 10100.0 10101.0 10101.5 10103.0 10104.0 10106.0 10118.5 10119.0 10119.5 10128.0 10129.0 10130.5 10131.0 10131.5 10132.5 10146.5 10147.5 10160.0 10160.5 10166.5 10167.5 10169.0 10171.0 10185.0 10185.5 10188.0 10188.5 10209.5 10210.5 10211.0 10212.0 10218.0 10223.5 10224.5 10225.0 10225.5 10226.5 10230.0 10231.5 10232.0 10233.5 10234.5 10235.0 10235.5 10236.5 10250.0 10250.5 10251.0 10253.5 10254.5 10259.0 10261.0 10268.0 10270.5 10272.5 10273.0 102'77.0 10278.0 10280.0 10281.5 10282.0 10283.0 10293.5 10294.5 10295.0 10295.5 10296.0 10298.0 10301.0 10301.5 10302.0 10306.5 10307.5 10308.5 10309.0 10311.0 10314.5 10315.0 10316.0 10317.5 10327.0 10330.0 10330.5 10334.5 10335.5 10340.5 10345.0 10346.5 10352.0 10354.0 10356.0 10363.5 10365.0 10366.0 10387.0 10387.5 10400.0 10401.0 10406.0 10406.5 10413.0 10414.0 10422.0 10424.5 10425.0 10243.0 10259.0 10268.0 10271.5 10273.0 10275.0 10287.0 10289.5 10292.0 10299.0 10307.0 10308.5 10317.5 10320.5 10321.5 10325.5 10416.5 10239.0 10239.5 10240.0 10243.5 10249.0 10251.0 1026~.5 10263.5 10264.5 10269.5 10274.0 10285.5 10286.0 10287.0 10288.0 10291.5 10292.0 10296.5 10297.0 10298.0 10299.0 10301.5 10305.0 10306.0 10326.5 10332.5 10337.0 10337.5 10343.0 10345.5 10347.5 10355.5 10357.0 10357.5 10378.5 10379.5 10392.0 10393.5 10398.5 10399.5 10406.0 10406.5 10414.5 10416.0 10416.5 10426.0 10432.5 10434.0 10434.5. 10435.0 10435.5 10436.0 10436.5 10447.0 10448.0 10448.5 10449.0 10449.5 10454.0 10455.0 10455.5 10463.0 10469.5 10470.0 10472.5 10473.5 10475.5 10476.0 10477.0 10478.0 10478.5 10479.0 10482.5 10489.5 10492.5 10495.5 10496.0 10498.0 10499.0 10505.5 10509.0 10510.0 10510.5 lO511. 10514.0 10516.0 10516.5 10517.5 10518.0 10519.0 10520.5 10521.0 10528.0 10529.0 10529.5 10530.0 10534.5 10535.5 10542.5 10546.5 10548.5 10549.5 10555.0 10555.5 10556.0 10425.5 10426.5 10428.0 10428.5 10455.0 10461.5 10462.5 10470.5 10471.0 10481.5 10483.5 10489.0 10491.5 10498.0 10502.0 10502.5 10503.0 10505.5 10507.0 10508.0 10509.0 10510.0 10511.0 10528.0 10535.0 10540.0 10542.0 10542.5 10548.0 10549.0 10549.5 10417.0 10423.5 10425.5 10426.5 10427.5 10439.0 10439.5 10440.0 10440.5 10441.0 10445.5 10446.0 10446.5 10464.0 10465.0 10466.0 10466.5 10467.0 10468.5 10469.0 10474.5 10487.5 10488.5 10501.5 10502.0 10503.5 10511.0 10513.5 10514.5 10521.5 10522.0 10522.5 10523.5 10528.0 10557.0 10560.5 10561.0 10571.0 10572.0 10577.5 10581.5 10587.5 10601.5 10602.5 10604.5 10630.0 10646.5 10647.0 10648.0 10649.0 10652.0 10653.5 10654.0 10655.0 10664.0 10665.0 10690.0 10698.0 10700.5 10708.5 10709.5 10710.0 10716.5 10717.0 10718.0 10718.5 10737.0 10741.0 10742.0 10748.0 $ 1 ~0.0 10553.5 10554.5 10564.5 10565.0 10570.5 10574.5 10582.5 10594.5 10595.0 10597.0 10624.0 10640.5 10641.5 10642.5 10643.0 10646.0 10648.5 10649.0 10649.5 10658.5 10659.0 10685.0 10693.0 10693.5 10702.5 10703.5 10704.5 10711.0 10712.0 10713.0 10713.5 10735.5 10739.5 10741.0 10746.0 PASS 3. FUCT & NUCTWERE SHIFTED WITH NPHI. /??MATCH3A. OUT / ? ?MATCH3 B. OUT $ CN : BP EXPLORATION WN : D - 28A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: (ALASKA) Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2' NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 16 * DATA RECORD (TYPES 0) '1006 BYTES * Total Data Records: 40 Tape File Start Depth = 10805.000000 Tape File End Depth = 9825.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding s~mmary: Rep Code: 68 19612 datums Tape Subfile: 4 387 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is typ~. LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN · WN FN . COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES · $ : BP EXPLORATION (ALASKA) : D - 28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ els Mod 1 GRCH CNAV 68 1 GAPI 2 NPHI CNAV 68 1 PU-S 3 FUCT CNAV 68 1 CPS 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 i 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 40 Tape File Start Depth = 10805.000000 Tape File End Depth = 9825.000000 Tape File Level Spacing = 0.500000 .Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 5 Minimum record length: Maximum record length: 19612 datums 63 records... 62 bytes 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9834.0 2418 9843.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PCM/CCL GAMMA RAY STOP DEPTH 10760.5 10770.0 COMPENSATED NEUTRON 23-APR-96 FSYS REV. J001 VER. 1.1 1259 23-~PR-96 11773.0 10772.0 9850.0 10770.0 900.0 YES TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11866.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EpITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: · HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT ~ E NORMALIZATION IN OIL ZO~ TOP NORMALIZI~ WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D - 28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 135 Tape File Start Depth = 10773.000000 Tape File End Depth = 9829.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53606 datums Tape Subfile:~6 211 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is ~ype: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9836 · 0 2418 9845.0 $ IX)G HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME 'LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10785.5 10794.5 23-APR-96 FSYS REV. J001 VER. 1.1 1406 23-APR-96 11773.0 10772.0 9850.0 10770.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PCM PCM/CCL GR GAMMA RAY CN COMPENSATED NEUTRON $ TOOL NUMBER 3913NA 8250EA/8248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11866.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER 0.00 0.0 0.0 0 0.0 0. 000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT ~ '] NORMALIZATION IN OIL ZO! TOP NORMALIZIN~ WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE. (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D - 28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 139 Tape File Start Depth = 10798.000000 Tape File End Depth = 9830.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 54470 datums Tape Subfile:.7 Minimum record length: Maximum record length: 215 records... 62 bytes 1014 bytes Tape Subfile 8 is type: LIS FILE HFs%DER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9836.0' 2418 9845.0 $ IX)G HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED _ (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PCM/CCL GAMMA RAY STOP DEPTH 10792.5 10802.0 COMPENSATED NEUTRON 23-APR-96 FSYS REV. J001 VER. 1.1 1514 23-APR-96 11773.0 10772.0 9850.0 10770.0 900.0 YES TOOL NUMBER 3913NA 8250EA/S248EA 8262XA 2418XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 11866.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): ~. SEAWATER 0.00 0.0 0.0 0 0.0 0 .,000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT ~ E NORMALIZATION IN OIL ZO! TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : D- 28A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 i F/bIN 8 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 140 Tape File Start Depth = 10805.000000 Tape File End Depth = 9829.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 88752 datums ~'ape Subfile: 8 216 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 9 is type: LIS O1 **** REEL TRAILER **** 96/ 6/13 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 13 JUN 96 3:35p Elapsed execution time = 20.49 seconds. SYSTEM RETURN CODE = 0
