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Home My WebLink About197-014STATE OF ALASKA ALASKA ~AND GAS CONSERVATION COMM~ION ~~~~~~~~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND L 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Plugged ~ Abandoned ^ Suspended ZOAAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero ` 1b. ~W I CI ss~ .~ G~~~~+~~IS ~} ^ Service An~~raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5~. Date Comp., Susp., or Aband.: ~ 9/23/2009. 4~, Permit to Drill Number: 197-014 309-290 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded: 02/21/1997 1'~. API Number: 50-029-21556-60-00 4a. Location of Well (Govemmental Section): Surface: ' ' 7. Date T.D. Reached: 02/24/1997 ~,4. Well Name and Number: PBU D-28AL1 FNL, 1692 1496 FEL, SEC. 23, T11 N, R13E, UM Top of Productive Horizon: 2701' FSL, 1869' 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 Bay Field / Prudhoe Bay Total Depth: 3671' FSL, 2107' FEL, SEC. 14, T11N, R13E, UM 9. Plug Back Depth {MD+ND): 11320' 9035' Oil POOI 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 653458 y_ 5959492 Zone- ASP4 10. Total Depth (MD+ND): 11748' 9010' 16. Property Designation: ADL 028285 TPI: x- 653192 y- 5963685 Zone- ASP4 Total Depth: z- 652933 Y- 5964650 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): GR 22. Re-Drill/Lateral Top Window MD/ND: 11420' (D-28AL1) 9034' z3. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTFF ND HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " x 20" Ins I t d nduct r Surf 110' S rfa 110' 26" 8 cu ds n rete 1 /8" 7 2 7' rf ' 17-1/ " 2 rm f '' PF 9- /8" 47# L- Surface 2' Surf ce 497' 1-1/4" 57 ft Class' ' 7" 29# ~-8 9 39' 10 7' 82 ' 8-1/2" 48 Class'G' 4-1/ ' 12. ' 1 ' " 1 I s ' 24. Open to production or injection? ^ Yes ~ No 25. TuaiN~ RecoRo If Yes, IISt @8CI1 I~t8N8I Op@Il (MD+ND of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ~ ND ~ 4-1/2", 12.6#, L-80 9538' 9480' / 8177' MD ND MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.` DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~~~y~~^ ~~~ ,/ ~ ~ ~~j(} ~ 11320' Set Whipstock ~` -r o~ ~~i 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24Hour 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, 'rf needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None IOC~ Form 10-407 Revised 07/2009 CONTINU ON REVERSE ~ ~~ Submit Original Only ~,~ ~~`-~`! °~ ~1~~ ~ ~ 29. GEOIOGIC MARKERS (List all formati ons and encountered): 30. RMATION TESTS NAME MD ND Well Tested? es ~ No PBrmafrost 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. Kicked Off In Zone 1 B 10742' 9027' None (From D-28A) Zone 1 B 11621' 9015' Formation at Total Depth (Name): 31. List ofAttachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ O/ Signed: Terrie Hubble • Title: Drilling Technologist Date: '7/Qq PBU D-28AL1 197-014 309-290 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 repoR and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production ftom more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07L Form 10-407 Revised 07/2009 Submit Original Only CJ • 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 ~ 2158' SLM. SET 4-1/2" DSSSV PLUG BODY C~ 2158' SLM. SET P-PRONG (~ 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~3 casing valve and skid. AL system is down. Tbg FL ~ 2010'. IA FL C~ 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 = 630/1000NAC. SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 6/11/2009 T/I/O = 750/880NAC. 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= 780/840NAC. Temp= SI. OART (day 2). AL SI (~ 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= 780/810NAC. 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~ casing valve. ALP=200 psi. IAP decreased 30 psi overnight. TP and OAP unchanged. IA FL 120'. Removed OART tags from IA and OA. SV, WV = closed. SSV, MV =o pen. IA, OA = OTG. NOVP. 6/14/2009 T/I/0=780/780Nac. SI. Bleed T and IAP to 0 psi (pre-PPPOT/CTD screen). AL SI and blinded ~ casing valve. ALP=200 psi. TBG FL 2010', will need UR to bleed. IA FL ~ 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/ONac. 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 ~ casing valve. TP increased 10 psi & IAP increased 10 psi overnight. Tbg FL ~ 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 = 8/3NAC. 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 = 140/10NAC. Temp = SI. Bleed T and IAP to 0 psi (pre-PPPOT/CTD screen). ALP = 200 psi. AL SI C«~ casing valve. Tbg FL ~ 2010'. !A 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=100/60Nac Temp=Sl Assist Slickline, Load Tbg (CTD Screen) Pumped 5 bbls meth, 30 bbls diesel down Tbg to load. Final WHPs = 100/60Nac. 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 C~ 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 hold, 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~3 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 ~ 2163' SLM W/ NO RESTRICTIONS. SET 4-1/2" DSSSV PLUG BODY (4 x 3/16" eq-ports, 3 sets of pkg) IN SVLN ~ 2163' SLM. OBTAINED CONTROL / BALANCE LINE INTEGRITY, BOTH LINES BLED TO Opsi. SET P- PRONG IN DSSSV PLUG BODY ~ 2163' SLM (top of prong C~3 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 line 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, W V, MV = S/I; IA, OA = OTG tags hung pad op notified. 9/15/2009 T/1/0=150/100/0. Set 6-3/8" CIW J TWC #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~3 118" using one 2' extension. 9/18/2009 ARRIVE ON LOC WELL S/I. R/U EGlUIPMENT 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. WHPs, 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 • • vperat~ans surnrnary ~eport 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 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 - 22:30 225 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) 0020 - 04:00 3.67 MOB P PRE CUT AND LD HERCULITE FOR CELLAR, LD RIG MATS 04:00 - 04:15 0.25 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 - 06:15 025 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 1.00 BOPSU P PRE FILL STACK & SHELL TEST. 14:00 - 22:00 8.00 BOPSU P PRE TEST BOPE PER AOGCC REGS, 250PSI/3500PSI. CHUCK SCHEVE WAIVED WITNESS TO TEST - PASS. GREASE VALVES AS NEEDED. 22:00 - 22:30 0.50 BOPSU P PRE PJSM W/ DSM REGARDiNG PULLING BPV. 22:30 - 00:00 1.50 BOPSU P PRE RU DSM LUBRICATOR. PT 250PSI/2000PSi. BLEED OFF WHP & OPEN WELL - 70PSI. ATTEMPT TO PULL 6" CIW BPV. 9/23/2009 00:00 - 01:15 1.25 BOPSU P PRE CONTINUE TO PULL 6" CIW BPV W/ SUCCESS AFTER ADDING 2' EXTENSION. RD DSM 01:15 - 01:30 0.25 RIGU P PRE PJSM REGARDING STABBING COIL. 01:30 - 04:15 2.75 RIGU P 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 COI L. 04:15 - 05:00 0.75 BOPSU P PRE PT PACKOFFS & INNER REEL VALVE PER AOGCC REGS 250PSI/3500PSI - PASS. 05:00 - 05:20 0.33 RIGU P PRE PJSM REGARDING RU COIL CUTTER & CUTTING/HANDLING COIL. BLOW BACK COIL W/ AIR WHILE PERFORMING PJSM - 10BBLS RECOVERED. 05:20 - 07:15 1.92 RIGU P PRE RU COIL CUTTER. CUT 362' OF COIL & FIND WIRE. TEST WIRE. CREW CHANGE. LD CUTTER 07:15 - 09:15 2.00 RIGU P PRE INSTALL CTC. PT 35K, 3500 PSI. INSTALL BHI UQC AND TEST 09:15 - 10:00 0.75 STWHIP P WEXIT BRING BTT TOOLS TO FLOOR. INSTALL 2 RA TAGS IN WS 10:00 - 11:00 1.00 RIGU P PRE STAB ONTO WELL. OPEN UP TO WELL AND HAD 100 PSI WHP. BEGIN BH KILL BY PUMPING SLACK FORWARD AT Nnntea: iui~zuua ~u:~r.SaAnn ~ • BP EXPLORATION Pa9~ 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 Operations 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 ~OSING 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 - 15:15 025 STWHIP P WEXiT RIH TO SET DEPTH AT 11336' 15:15 - 15:40 0.42 STWHIP P WEXIT CLOSE EDC. PRESSURE CT TO 2000 PS! W/ 3.5 BBLS AND WS SET. STACK 4.9K ON WS TO 11337.7' AND HE~D, BUT NOTED THAT TF MOVED FROM 145R TO 185R. PULLED UP HOLE CLEAN AT 46K LEAVING TOWS AT 11320' ELMD 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 - 1925 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/ 2PP6 BI , 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 W(NDOW @ 1FPH FROM 11, . .666PM 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 - 08:15 225 S7'WH WEXIT 11325.6' 2.61/2.56/2460 w/ 0.80k 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 DRESSWINDOW,DRYTAG 09:30 - i2: 2.50 STWHlP P WEXIT POH CIRC THRU MILL 2.6/2200 12:0 :45 0.75 STWHIP P WEXIT LD AND LOAD OUT MILLING BHA. MIL~ AND SR WERE BOTH 3:79" PIIIltBtl: 70/5/"LUW IU:Y/:SyAM KB. ELEV = 78.7' BF. ELE![ = 42.71' KOP =• 4282' IV,Jax Angle = '.2 @ 12449' Datum MD = 10496' DatumND= 8800' SS ~ ~ ~~'D ~IClef3'~~k ~~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2670' SAF OTES: WELL ANC~.E> 70° @ 10742'. 2188' -j4-1/2" HES HXOSSSV NIP, ID=3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH F~RT DATE 5 3087 3087 1 HES TB DMY RM 0 03/26/06 4 5293 5217 33 HES TB QMY RM 0 03/26/06 03i26 6 7667 6880 43 HES TB DN1Y RM 0 /0 2 9201 7975 41 HES TB DNIY RA 0 1 9398 8120 45 HES TB DMY RM 0 03/26i06 9469' -i4-1/2" HESX NIP, ID=3.813" ~ Minimum ID = 2.~~~~ '~~~~~' " Inside TUP C?F LINER - saso' 9-5/8"X4-1/2"TNVHBBP-TPKR, ID=4.00 9504' 4-1/2" HES X NIP, ID = 3.813" 9526~ 4-1l2" HES XN NIP, M ILLLm ID = 3.80" TOPOF 4-1/2" LNR 9530' 9530' 9-5l8" 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-S0, .0371 bpf, ID = 6.184" 9550' 9528' ELMD TT LOGGED 04/23/96 9660' 7" X 4-1/2" XO, ID = 3.958" TOPOF 7" LNR 9639' 9639~ 7" LNR HGR 9-5l8" CSG, 47#, L-80, ID = 8.681" 9882~ TSG R 9931 ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10075~ 7" MILLOUT WINDOW (D-28A) 10075' - 10125' 3.70° 8KR LNR DEPLOYM~N7' SLV, IC3 = 2.30" 102~Q' ~o KB packer ID: 2.38" 10194° TUC 10200' 4-1i2" rrwnobore packer w hipstock~ ~ 1320' PERFORATION SUMMARY REF LOG: BNI MWaGR C7N 9l3QI09 A NGLE AT TOP PERF: 91.9° ~ 19 850' Note: I~fer to Production DB for historical perf data SQE SPF INTERVAL OpNSqz Q4TE 2" 6 11850-'{ 215Q C3 1 C7/03f09 2" 6 122t~')-1239Q CJ 10I03rYJ9 2" 6 12A~-92900 t? "IQ10310~ 2" 6 125A0-~i3Q57 fl 201t733lU9 91° 11391' ~-1 BKR KB PKR WHIPSTOCK ~ BKRUNQI PKR, ORIENTING KEY 80°, LEFT OF HIGH SIDE PBTD I 11434' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" I Xo I 3-3116" x 2-718" crrt'd ~ perf`d ~-~ 139170' ~T 13tY57' DATE REV BY CAMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/16/86 ORIGINAL COM PLETION 03/26/06 RPHlPJC WANER SF7Y NOTE DELETED WELL: D-288 02l26/97 HITLO SIDETRACKCOMPLETION 03/26/O6 TEL/PJC GLVGO PERMITNo: 05/19/04 SRB/KAK SETIBP, ADPERF 10/15/08 DMS/PJC PULL IBPY FISH IN HOLE (10/10/0 8) AR No: 50-029-21556-02 OSl28/04 LWBIKAK GLM ND DEPfH CORRECTION 141dt121p9 Nordic Z GT~ SIDEtRACK far mpre pil... SEC 23, T11 N, R13E, 1496' FNL & 1692' FEL 05/29/04 DAV/KAK GLV GO 07/11l04 MDGKAK ADPERFS BP Exploration (Alaska) ~ z~L' 3 F ~ ' 4 y ~k y _ p~ ,Ya : _ p .1 ~ gd , ~C ~ ~ C f ~ ~ J ~~ ~ [ ~ ~ F F ~ ~ r, k~..i $ ~n ei ~i h., ~i ~ ~ ~ ~ ~~~ ~ ~ ~- ~ ~ ~ ~ ~ r~ ~ ~ ~ ~,~~ ~ , ~ ~ ~ e ~,. ~ a € ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~k G ~ ~ R ~ ~~°,, ~~ ~ SEAN PARNELL, GOVERNOR ~,! ~ i?. ~ ,a~, m-,'z ~ 4.'s f ~ e ~,n F~~ fi_-.~sx ~3 ~ ~ ~:~, ~~ ~ ~5 E,~ ~r ra~-7~ Q~ tai~ai V~a--7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOrT COMI~IISSIOI~T ~ ANCHORAGE,ALASKA 99501-3539 y PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. O'~ ~ P,O. Box 196612 ~'' Anchorage, AK 99519-6612 ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-28AL1 Sundry Number: 309-290 ~,,~ ~~ ~,~ ~,a#-~s,~ !~,' ~ ~ _., r'' ~ ~!~!`: ~ ,M ~ Dear Mr. McMullen: Enclosed is the approved Application for Sundiy 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 Comrnission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decisi4n, or such further time as the Commission grants for good cause shawn, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:~0 PM on the 23rd day following the date of this letter, or the ne~ 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, /~ Chair DATED this~-~ day of August, 2009 Encl. ~,(1~' Y~ STATE OF ALASKA "° .?,~o`~ ~b~LASKA OIL AND GAS CONSERVATION COMMISSION ,,'~ APPLICATION FOR SUNDRY APPROVAL ~ 20 AAC 25.280 ~~~~~~~~~~~ , ~~;! f ~~ ~ ~ ~ ~~~i a.d~~:~~Fi i~~i i'~ 4~~ .~.;+~'v, ~...S~~t;.i~° r,Eijt~i. 1. Type of Request: ~ Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension~~;~°' ~ "' ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 197-014 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21556-60-00 ~ 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-28AL1- 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 WEIL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11748 - 9010 11748 9010 None Yes, depth Unknown Casin Len h Siz MD N Burst olla s ructural o n c t r 11 ' 3" " 11 ' 11 ' Surface 2670' 13-3/ " 267 ' 2670' 493 2 70 In rmediate Pr u in ' -/" 47' 87 47 Liner 436' 7" 9639' - 10 75' 82 4` - 8555' 7240 541 Liner 233 ' 4-1/2" 9530' - 11425' 8211' - 9027' 8430 7500 ' r 7' -7/ " 1 1' - 11748' 1' 1 1 0 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10680' -11850', Slotted Liner (71397' - 11715~ 9003' - 9013', Slotted Liner (~34 - 9010~ 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: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean Mc~au9hlin, 564-4387 Printed Name Joh c II Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4711 Date ~/~~ f% Sondra Stewman, 56a-a750 Commission Use Onl Sundry Number: _ ~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity lJ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~S °° f s~ _ Q~~ l~~ 25~~ p St ~ nhw~~ % ~J~ ~`'''~.• ) Subsequent Form Required: t U_,~ ~y ~~ C APPROVED BY Z~ ~ ~ A roved B: COMMISSIONER THE COMMISSION Date Form 10-403 Revise 06/2006 / OR{GI~IAL ~~ ~~~~ ~::ti';: 3 { t1Q~' Submit In Duplicate ,~~ ~-xa%' ~ ~ 2,f-0 f / To: Tom Maunder Petroleum Engineer b p Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: August 18, 2009 Re: D-28A and D-28AL1 Sundry Approval Well Construction: D-28 was drilled in 1986 to target an area in northern 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?" production liner to ll,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-U2" 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 TIFI. 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 MIT-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 MTT-IA passed to 3000 psi verifying competent tubing, packer, and production casing. Pre-rig MTT's were performed 6/4/09, the MIT-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 Fa11 of 2008, the IBP was removed in the hopes of accessing low GOR oil in the toe 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 Sentember 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 MIT-IA to 3000 psi DONE 6/04/09 3. C Dummy WS drift to 11350' (IBP element in the hole) 4. W AGLDS; 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 ~ J 3a~, ~- Rig Work: (scheduled to begin on September 7, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 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) ~ ~ ~c~ ,~p $'~ ~ 5. Drill Lateral: 4.125" OH, 1600' (12 deg/100 planned) ~ r 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 MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (~1000') 11. Freeze protect well, RDMO ~~ ~ ~~ T ~' L' // " h ~G ~Y~ Post-Rig Work: ~ ~ , ~-~ h ~ w~ 1. Re-install wellhouse and FL's. y~~ ~L~.~,~t?r~"~~ ' "~ `~'` ;~Sc~~~~5~ `'~~ " r~ ~"~ 2. Generic GLV s E ~ rt• " `~ ~R{, ~%~ ' .~r~i;' f~ U ; ~ ~~L ;~ 4 Ur y t ' ! ~wr~ -, .r f. //~I "~ rJ ~~'~~ Sean Mclaughlin r~,a ~''~~~~' "~ . ~ yz, ~~~ ?~~'~~iO~ ~s ' CTD Engineer 564-4387 -`,'~ ''z' ~e~ ~'a'~ ~„~""~ /1~ll~a~~?s ',~ ~r =, c ~ -~ ~ ~ ~~ ~ ~ ~,.- ~ X, « ~rc ~ CC: Well File ~° ` ` f S d St /T i H bbl ~i~ ~ ~1 ~ ~`~~ ~~ ` ,~ ~ ` ~ '~~~~~~ ra on ewman err e e u ~ ., f y ~ r ~ ~,~i~ l~ KB. ~EV = ~~mm 78.7' BF. EL~V = 42.71' KOP = 4282' A4ax Angle = 101 @ 11537' Datum MD = 10496' Datum ND = 8800' SS D-28AL1 SAFETY NOTES: WELL ANGLE> 70° @ 70742'. I C 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.37" @ 11391' TOP OF 2-7/8" SLOTTED LINER 2~$8' --~4-1/2" HES FIXO SSSV NIP, ID = 3.813" GAS LIFf MANDR~S 5 3087 3087 1 HES TB DMY RM 0 03/26/06 4 5293 5217 33 HES TB DMY RM 0 03/26/06 3 7667 6880 43 HES TB DMY RM 0 03/26/O6 2 9201 7975 41 HES TB DMY RA 0 1 9398 8120 45 HES TB DMY RM 0 03/26/O6 ~, 4-1/2" HES X NIP, ID = 3.813" 9480' --,9-518" X 4-1l2" TNV HBBP-T PKR i~ = 4.00„ J~' 4-1 /2" HES X NIP, ID = 3.813" 14-1/2" HES XN NIP, M ILLLED ID = 3.80" I ~ TOP 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 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ PERFORATION SUMMARY R~ LOG: SP~RY SUN MWD/GR ON 01/29/96 ANGLE AT TOP PERF: 60° Q 10680' Note: Refer to Production DB for historicai perf data SIZE SPF INTERVAL OpnlSqz DATE 2-7/8" 6 10680 - 10705 O 07/11/04 2-7/8" 6 10716 - 10738 O OS/18/04 2-3/4" 4 10910 - 11110 O 02/05/96 2-3/4" 4 11270 - 11650 O 02/OS(96 9530~ ~ 9-5/8" X 7" BKR MMC LNR PKR 9538' 4-1/2" WLEG, ID = 3.958" 9528' ~MD TT LOGGED 04/23/96 9550' 7" X 4-1 /2" XO, ID = 3.958" 7" LNR HGR 9878' -inno~wcs~.~Onvr ~ 7" MILLOUT WINDOW (D-28A) 10075' - 10125' ~-j FISH - IBP E1ENI~ff (10/10/08) 11391~ BKR KB PKR ~ 4-1/2" MILLOIff WINDOW (D-28AL1) 11425' - 11437' ~ ~ ~ ~ ~ ~ ~ ~\ ~--------------------- ~----------------------~ OF 2-7/8" SLTD LNR ~-~ WH~STOCK BKR WQ1 PKR ~~~G 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 COMMEMS PRUDHOE BAY UNff 03/18/86 OWGINAL COMPLETION 03/26/06 RPH/PJC WAN82 SFTY NOTE DF1ETm W~L: D-28AL1 02126/97 HITLO SIDEfRACKCOMPLETION 03l26/06 TE1/PJC GLV GO PERMITNo:~1970140 05/19/04 SRBlKAK SET IBP, ADPEFiF 10/15/08 DMS/PJC PULL IBP/ FISH IN HOLE (10/10/0 8) API No: 50-029-21556-60 05/28/04 LWBlKA GLM ND DEFfH CORRECTION SEC 23, T11 N, R13E, 1496' FNL & 1692' FEL 05/29/04 DAV/KA GLV GO 07/11/04 MDGKA ADPERFS BP 6cploration (Alaska) KB. H..EV = 78.7' BF. E1~1/ = 42.71' KOP = 4282' Max Angle = 101 @ 11537' Datum MD = 10496' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.30" @ 10180' TOP OF LINER ITOPOF4-1/2" ~NR 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 I 9-5/8" CSG, 47#, L-S0, ID = 8.681" 9882~ 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 10075~ 3.70" BKR LNR DEPLOYMENT S~V, ID = 2.30" ~ 10180' ToC 10180' ~ 41/2" monobore w hipstock ~ P9~FORATION SUMMARY R~ LOG: SPERRY SUN MWD/GR ON 1/29/96 ANGLE AT TOP P6~F: 60° @ 68 0' Note: Refer to Production 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 - 107 O 05/18/04 2-3/4" 4 10910 - 11 10 O 02/05/96 2-3l4" 4 11270 - 1650 O 02/05/96 SAFETY NOTES: W ELL ANq.E > 70° @ 10742'. I ~ 2188~ --~4-1/2" HES HXO SSSV NIP, ID = 3.813" ~ GAS LIFf MANDREIS ST 5 4 MD 3087 5293 TV D 3087 5217 DEV 1 33 TY PE HES TB HES TB V LV DMY D H RM RM PORT 0 0 DATE 03/26/O6 03/26/06 3 2 7667 9201 6880 7975 43 41 HES TB HES DMY RM RA 0 0 03/26/06 1 9398 8120 9469~ 45 HES DMY RM 0 03/26/06 4-1 /2" X NIP ID = 3 813" , . ID = 4 9480~ 9- S" X 4-1/2" TNV HBBP-T PKR 00" . , 1/2" HES X NIP ID = 3 813" 95(~4' 4 - , . 1/2" HES XN NIP M ILLLm ID = 3 80" 9526~ 4 - , . " " ~ 9 O 9538~ X 7 BKR HMC LNR PKR 9-5/8 ID = 3 4 1/2" WLEG 958" - , . 9528' E1MD TT LOGGm 04/23/961 9550~ 7" X 4-1/2" XO, ID = 3.958" 9639' 7" LNR HGR xo ~ 11600' _~~ ~ 3-3/16" x 91 ° ~J N~ T 2.~ N ~-~ ~~ z~ o S . ~ ~ ~ ~ ~ ~ ~` ----------------------~ ~--- 11391~ BKRKBPKR -------------------- 2-7/8" SLTD LNR 6.16#, L-80, .0058 bpf, ID = 2.37" BKR WQ1 PKR, ORIINTING 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 03/18l86 ORIGINAL COM PLETION 03/26/06 RPWPJC WANER SFfY NOTE DE1ETm W~L: D-286 02/26/97 HITLO SIDETRACK COM PLETION 03/26/O6 TEl./PJC GLV GO PERMff No: 05/19/04 SRB/KAK SET IBP, ADPERF 10/15/08 DMS/PJC PULL IBP/ FISH IN HOLE (10/10lO S) AR No: 50-029-21556-02 05/28/04 LWB/KA GLM ND DEPTH CORRECTION 06/18/09 MSE PROPOSm CTD SIDETRACK SEC 23, T11 N, R13E, 1496' FNL & 1692' FEL 05l29/04 DAV/KA GLV GO 07/11/04 MDGKA ADPERFS BP Exploration (Alaska) D-28B Proposed CTD Sidetrack - TSGR 9931' 7" MILLOUT WINDOW (D-28A) 10075' - 10125' Page 1 of 1 Schwartz, Guy L (DOA) From: McLaughlin, 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-286.jpg Guy, The revised D-28B schematic is attached. I needed to update my files as weil. 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 isolatio~ 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:guy.schwartz@alaska.gov] Sent: Tuesday, August 25, 2009 10:15 AM To: McLaughlin, 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 pertorations above and below tMe whip sock/CIBP setting depth it would not isolate the old wetlbore 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. I will make a notation on the schematic for our file. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 8/25/2009 KB. ELEV = 78.7' BF. ELEV = 42.71' KOP = 4282' Max Angle = 101 @ 11537' Datum MD = 10496' Datum N D= 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.30" dLi 10180' TOP OF LINER I TOP OF 4-1 /2" LNR 4-1/2" TBG, 12.6#, L-S0, .0152 bpf, ID = 3.958" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" D~~ ~~ SAFETY NOTES: WELL ANGLE > 70° ~ 10742'. Proposed CTD Sidetrack N~w ~~-~;s~°~ y~-- s~-zr-o 4 /2" HES HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS 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 ~' ~ 4-1/2" monobore packer w hipstoca 4 5293 5217 33 HES TB DMY RM 0 03/26/06 3 7667 6880 43 HES TB DMY RM 0 03/26l06 2 9201 7975 41 HES TB DMY RA 0 1 9398 8120 45 HES TB DMY RM 0 03l26/06 9469~ 4-1 /2" HES X NIP, ID = 3.813" 9480~ 9-5/8" X 4-1 /2" TIW HBBP-T PKR, ID = 4.00" 9504~ 4-1 /2" HES X NIP, ID = 3.813" 9526~ 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" 9528~ ELMD TT LOGGED 04I23/96 9550~ 7" X 4-1 /2" XO, ID = 3.958" 96~ 7" LNR HGR ~ TSGR 9931' 7" MILLOUT WINDOW (Q28A) 10075' - 10125' I XO I x 2-7/8" crr~d & perf'd ~--~ 13330' PERFORATION SUMMARY REF LOG: SPERRY SUN hAWD/GR ON 01/29l96 ANGLE AT TOP PERF: 60° ~ 10680' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10680 - 10705 O 07/11 /04 2-7/8" 6 10716 - 10738 O OS/18/04 2-3/4" 4 10910 - 11110 O 02/05/96 2-3/4" 4 11270 - 11650 O 02/05/96 0 91° _ ` ~ ~ ~ ~ ~` --------------------- ~------ BKRKBPKR --~------------ WHIPSTOCK ~ BKR WD-1 PKR, ORIENTING ---[ KEY 80°, LEFT OF HIGH SIDE PBTD -I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 2-7/8" SLTD LNR, 6.16#, L-S0, 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 02/26/97 HITLO SIDETRACKCOMPLETION 03/26/06 TEL/PJC GLV C/O PERMITNo: 05l19/04 SRB/KAK SET IBP; ADPERF 10/15/08 DMS/PJC PULL IBP/ FISH IN HOLE (10/10l0 8) API No: 50-029-21556-02 OS/28f04 LWB/KAK GLM ND DEPTH CORRECTION 06/18/09 MSE PROPOSED CTD SIDETRACK SEC 23, T11 N, R13E, 1496' FNL 8 1692' FEL 05/29/04 DAV/KA GLV C/O 07/11/04 MDC/KAK ADPERFS BP Exploration (Alaska) 03/13/2007 Scblumbel'gep NO. 4177 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons C:omm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10,1- OlL( ~ l'j (;LII Field: Prudhoe Bay WI! BL CD CI J b# D t e 0 Log Description ae o or Z-04A 40012158 OH EDIT MWD/LWD 07/21/05 2 1 P2-43 10942211 MCNL 04/29/05 1 1 01-28 11630448 RST 01/14/07 1 1 D-16 11533390 RST 12/29/06 1 1 D-28AL 1 11216183 MCNL 03/21/06 1 1 01·20 11513651 RST 11/26/06 1 1 B-06 11226015 RST 11/01/06 1 1 02-20 11496876 RST 11/24/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 Ib:rJ~!üItdÇIl APR 0 3 2007 900 E. Benson Blvd. w;'UtI'U~ Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 1 Anchorage, AK 99503-2838 : ATTN: Beth ! ^l I Received by: Date Delivered: rl¡\R /~'., C_/\ . . '. STATE OF ALASKA ) ALAE)OIL AND GAS CONSERVATION COMMk . ION REPORT OF SUNDRY WELL OPERATIONS /JIJ 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate [] ii óitJ~P ~ .~~D Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver D'~~h(a=eH~Æi9,(?q) Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended w~lt~':Ol{;lni:.' ~ "1' """ BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Dfîq'I::ISIXJ(']'~~rJ Development ,r;?' Exploratory C¡ 197-0140 ,d'., Stratigraphic Service D 6. API Number: 50-029-21556-60-00 9. Well Name and Number: 2. Operator Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: 78.66 KB D-28AL 1 ADL-028285 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth Effective Depth Casing Conductor Liner Liner Liner Production Surface Perforation depth: measured 11748 true vertical 9009.56 feet feet None None Plugs (measured) Junk (measured) measured 11748 true vertical 9009.56 SCANNE.D AUG 3 1 2.00~ï feet feet Length Size MD TVD Burst Collapse 80 20" 91.5# H-40 36 - 116 36 - 116 1490 470 357 2-7/8" 6.16# L-80 11391 - 11748 9034.12 - 9009.56 13450 13890 2336 4-1/2" 12.6 # L-80 9530 - 11866 8211.39 - 9010.53 9530 11866 429 7 Inch 29 Lb L-80 9646 - 10075 8288.6 - 8555.02 9646 10075 9855 9-5/8 Inch 47 Lb L-80 34 - 9889 34 - 8441.35 34 9889 2642 13-3/8 Inch 72 Lb L-80 35 - 2677 35 - 2676.72 35 2677 Measured depth: 10680 - 10705 True Vertical depth: 9002.84 - 9014.28 10716 - 10738 9018.68 - 9026.26 Tubing: (size, grade, and measured depth) 4-1/2" 12-6# L-80 32 - 9538 Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10680-10705; 10716-10738 Treatment descriptions including volumes used and final pressure: 354 bbls 2% KCL, 12 bbls 50/50 Methanol, 107 bbls Diesel, 50 bbls 10% HCL acid T/I/O 220/820/140 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 401 16983 117 100 441 18194 126 140 15. Well Class after croposed work: Exploratoryr Development .,[;1 16. Well Status after proposed work: Oil P Gas r WAG r Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 4-1/2" TIW HBBP-T Packer 7" Baker HMC Packer 2-7/8" Baker KB Packer HES HXO SSSV 9480 9530 11391 2188 RBDMS BFL AUG 3 0 2005 Tubing pressure 200 220 Service r x GINJ r WINJr WDSPLí 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal prin:i:~a~~~ ~~ Title Data Mgmt Engr Phone 564-4424 Date 8/25/2005 ORIGINAL Form 10-404 Revised 04/2004 Submit Original Only ') ') D-28AL 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 7/11/2005 MIRU CTU #8. **** Job Scope: Acid Stimulation****. MU BHA w/2" side jet nozzle. RIH. Fluid pack with 12 bbls meth, 248 bbls of KCL, and 75 bbls of diesel to maintain positive WHP. Perform acid stimulaticm per procedure. Initial treating pressure 962 psi WHP at 1.7 bpm. WHP slowly fell to 837 psi during first 20 barrels of acid on formation then increased to 931 psi when 2% KCL flush reached nozzle. Final WHP - 1004 psi at 1.8 bpm. POOH. LD tools. Release CTU #8. Turn well over to DSO to flow acid back to GC. *****Job Complete***** FLUIDS PUMPED BBLS 354 2% KCL 12 50/50 Meth 107 Diesel 50 10% HCL acid 523 TOTAL RE' C"'E~Vrr- .œwœ ':;u¡.;.:m, I ~\tI" "... ,(I' __ "I~"""", AUG 2 4 2005 \ STATE OF ALASKA '\ ALAS~ >OIL AND GAS CONSERVATION COMMI.... -,,fON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Plug Perforations D Performed: Alter Casing D Pull Tubing D Perforate New Pool D Change Approved Program D Operat. Shutdown D Perforate D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: Name: Developm ent R' 3. Address: P.O. Box 196612 Stratigraphic [] Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: Stimu~ate 0 . A;" k~~~r~_,~;~~' r:mu~j,. Gornmissimt Waiver D Tmïë ~tenslon [ , u;mna~e Re-enter Suspended Well I 5. Permit to Drill Number: Exploratory 0 197-0140 Service [] 6. API Number: 50-029-21556-60-00 9. Well Name and Number: 78.66 KB D-28AL 1 ADL-028285 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Fieldl PRUDHOE OIL Pool Total Depth Effective Depth Casing Conductor Liner Liner Liner Production Surface Perforation depth: measured 11748 true vertical 9009.56 feet feet Plugs (measured) Junk (measured) 10800 None measured 11748 true vertical 9009.56 feet feet Length Size MD TVD Burst Collapse 80 20" 91.5# H-40 36 - 116 36 - 116 1490 470 357 2-7/8" 6.16# L-80 11391 - 11748 9034.12 - 9009.56 13450 13890 2336 4-1/2" 12.6 # L-80 9530 - 11866 8211.39 - 9010.53 9530 11866 429 7 Inch 29 Lb L-80 9646 - 10075 8288.6 - 8555.02 9646 10075 9855 9-5/8 Inch 47 Lb L-80 34 - 9889 34 - 8441.35 34 9889 2642 13-3/8 Inch 72 Lb L-80 35 - 2677 35 - 2676.72 35 2677 Measured depth: 10680 - 10705 True Vertical depth: 9002.84 - 9014.28 10716 - 10738 9018.68 - 9026.26 Tubing: (size, grade, and measured depth) 4-1/2" 12-6# L-80 32 - 9538 Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10680-10705; 10716-10738 Treatment descriptions including volumes used and final pressure: 354 bbls 2% KCL, 12 bbls 50/50 Methanol, 107 bbls Diesel, 50 bbls 10% HCL acid TIIIO 220/820/140 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure 401 16983 117 100 441 18194 126 140 15. Well Class after Droposed work: Exploratory r Development ,¡;r 16. Well Status after proposed work: Oil r Gas P' WAG r Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 4-1/2" TIW HBBP-T Packer 7" Baker HMC Packer 2-7/8" Baker KB Packer HES HXO SSSV 9480 9530 11391 2188 ~ÇI,~H\fED lJ.UG :~ Q 2005 Tubing pressure 200 220 Service r x GINJ r WINJ ,r WDSPL[" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact Sharmaine Vestal prin:i::::;¿~7bJ Title Data Mgmt Engr Form 10-404 Revised 04/2004 Phone 564-4424 Date 8/17/2005 U RIG I N A L Rsvns d.!fl,~iginal Only '" ') ) D-28AL 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 7/11/2005 MIRU CTU #8. ****Job Scope: Acid Stimulation****. MU BHA w/2" side jet nozzle. RIH. Fluid pack with 12 bbls meth, 248 bbls of KCL, and 75 bbls of diesel to maintain positive WHP. Perform acid stimulation per procedure. Initial treating pressure 962 psi WHP at 1.7 bpm. WHP slowly fell to 837 psi during first 20 barrels of acid on formation then increased to 931 psi when 2% KCL flush reached nozzle. Final WHP - 1004 psi at 1.8 bpm. POOH. LD tools. Release CTU #8. Turn well over to DSO to flow acid back to GC. ***** Job Complete***** FLUIDS PUMPED BBLS 354 20/0 KCL 12 50/50 Meth 107 Diesel 50 10% HCL acid 523 TOTAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved ProgramD 2. Operator Repair WellD Pluq Perforations[K] Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate ŒJ 4. Current Well Class: Stimulate 0 OtherD WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 197-0140 Name: BP Exploration (Alaska), Inc. Development ŒJ Stratigraphic D 9. Well Name and Number: D-28AL 1 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool ExploratoryD Service D 6. API Number 50-029-21556-60-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 78.66 8. Property Designation: ADL-0028285 11. Present Well Condition Summary: Total Depth measured 11748 feet true vertical 9009.6 feet Plugs (measured) 10800 Effective Depth measured 10800 feet true vertical 9037.1 feet Junk (measured) None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 36 116 36.0 116.0 1490 470 Liner 2336 4-1/2" 12.6# L-80 9530 - 11866 8211.4 - 9010.5 8430 7500 Liner 429 7" 29# L-80 9646 - 10075 8288.6 - 8555.0 8160 7020 Li ner 357 2-7/8" 6.16# L-80 11391 - 11748 9034.1 - 9009.6 13450 13890 Production 9855 9-5/8" 47# L-80 34 - 9889 34.0 - 8441.4 6870 4760 Surface 2642 13-3/8" 72# L-80 35 - 2677 35.0 - 2676.7 4930 2670 Perforation depth: Measured depth: 10680 - 10685,10685 -10705, 10716 -10738 RECE~'"ED True vertical depth: 9002.84 - 9005.27,9005.27 - 9014.28,9018.68 - 9026.26 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 @ 32 9538 ,': ~J' . ) ') ^ ,:-'. ~ ':' J r ,1:0.'14 ÞJB.¡¡ Oil &. Gas Cons. Comm' . .4n~ ~~ .¡,; Packers & SSSV (type & measured depth): 2-7/8" Baker KB Packer 4-112" TIW HBBP- T Packer 7" Baker HMC Liner Packer @ 11391 @ 9480 @ 9530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 746 396 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 30.6 69 800 13 5.2 92 2000 Tubing Pressure 1110 184 Oil-Bbl 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development Œ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Oil ŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Garry Catron Garry Catron ,.l1c~ C~ Title Production Technical Assistant Contact Printed Name Phone 564-4657 Date 8/3/04 Form 10-404 Revised 4/2004 RßOMS BfL AU6 1.1 200~~ D-28AL 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/16/04 ***WELL FLOWING ON ARRIVAL *** (DRIFT FOR IBP). RAN 3 3/811 DUMMY GUN TO 10707 SLM. ***WELL SHUT IN, TURN OVER TO DSO TO POP*** 05/17/04 CTU #4, TIE-IN LOG; MIRU OS CTU #4. LOAD WELL WITH KCL TO KNOCK DOWN WHP. RIH WITH SWS MEMORY GR/CCL. LOG FROM 10950' TO 10600' CTMD. FLAG PIPE AT 10774' CTMD. POOH. CHECK DATA - GOOD. SECURE WELL FOR THE NIGHT. CONTINUE ON 5/18/04 ... 05/18/04 Perforate 10716'-10738' 6 SPF 05/18/04 SET IBP @ 10800' 05/19/04 CTU #4, IBP/PERF; CONTINUE FROM 5/18/04... AT SURFACE WITH GUN #1. ALL SHOTS FIRED. STAND BACK DS CTU #4. SECURE WELL. RETURN LATER TO BLOW DOWN COIL AND ATTEMPT N2 LIFT. RIH TO 4000 ' TVD PU OS/28/04 TIO= 350/0/0---LOAD TBG FOR SLlCKLlNE---FINAL WHP'S=200/1 00/0 OS/28/04 T/I/O= 150/50/0. TEMP= SI. (FLS FOR SL). IA FL @ 180'. OS/29/04 Change out GLV @ Station 1 06/01/04 TIO= 180/1520/0. TEMP=90. IA FL @ 9398' (STA # 1). (FOR OPERATOR). 07/11/04 T/I/O= 1200/1450/0, ASSIST E-LlNE, PUMP 25.3 BBLS OF CRUDE DOWN TBG. FINALS T /1/0= 900/1450/0. 07/11/04 PERFORATED FROM 10680-10705' WITH 2-7/8" HSD 2906 PJ, HMX, 6 SPF, RANDOM ORIENTATION GUNS. NOTIFY PAD OPERATOR TO POP WELL. FLUIDS PUMPED BBLS 177 293 1500 55 2025 50/50 Methanal 2% KCL Gal N2 Crude TOTAL Page 1 TREE = õ' McEVOY WI3..LI..EAD = McEVOY A CfUA TOR = OTIS KB. ELEV = 78.7' BF.ELEV = 42.71' 'KOP = 4282' Max Angle = 101 @ 11537' Dab.Jm MD = 10496' Dab.Jm TV D = 8800' SS 113-318" CSG, 72#, L-BO, ID = 12.34 T' H 2670' Minimu m ID = 2.37" @ 11391' TOP OF 2-718" SLOTTED LINER ITOP OF 7" LNR 1-1 9530' I 14-112" lBG, 12.6#, L-80, .0152 bpf,lD =3.958" 1-1 9538' I 17' LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 9550' t ITOP OF 4-1/2" LNR 1-1 9550' I I TOP OF 7" LNR 1-1 9639' I I 9-5/8" CSG, 47#, L-80, ID;:: 8.681" 1-1 9882' I I 7' LNR, 29#, L-80, .0371 bpf. ID = 6.184" 1-1 10075' I ÆRFORA llON SUMMARY REF LOG: SPffiRY SUN MWD/GR ON 01/29/96 ANGLE AT TOP PERF: 60 @ 10680' Note: Refer 10 Production DB for hstoncal perf data SIZE SFF INTffiVAL Opn/Sqz DATE 2-7/8" 6 10680- 10705 0 07/11/04 2-7/8" 6 10716- 10738 0 05/18/04 2-3/4" 4 10910- 11110 C 02/05/96 2-3/4" 4 11270-11650 C 02/05/96 D-28AL 1 f) ~ L :8: I ~ ~ ~ 8, ~ I t ... ... SAFETY NOTES: 70° @ 10742' AND 90° @ 10868'. Or-SLOW T X IA COMM. MAINTAIN OPERATING UMITOFTHE9-5/8" ANNULUS @ 2000 PSI. MAINTAIN OPERATING LIMIT OFTHE 13-3/8" ANNULUS @ 1000 PSI (11/12/02 W AlVER)Or'" 2188' H4-1/2" HES HXO SSSV NIP, ID = 3.813" I ~ GAS LIFT I\N\NDRELS ST MD TVD DEV TYPE VLV LATCH 5 3087 3087 1 HES lB DOrvE RM 4 5293 5217 33 HES lB DOME RM 3 7667 6880 43 HES lB DOME RM 2 9201 7975 41 HES lB DMY 1 9398 8120 45 HES lB SO FDRT OA. TE 16 OS/29/04 16 OS/29/04 16 OS/29/04 0 20 OS/29/04 9469' 1-14-1/2" HES X NIP, ID = 3.813" I RM 1-19-5/8" X 4-1/2" TW H3BP- T PKR ID = 4.00" 1 1-14-1/2" HES X NIP, ID = 3.813" I 1-14-1/2" HES XN NP, MILLLED ID = 3.80" 1 1-19-5/8" X 7' BKR HMC LNR R<R 1 1-14-1/2" WLEG, ID ;:: 3.958" I 1-1 ELMD TT LOGGED 04/23/96 1 1-17" X 4-1/2" XO 1 9639' 1-17" LNR HGR 1 9878' 1-1 MARKffi JOINT 9480' 9504' 9526' 9530' 9538' 9528' 9550' 7" MILLOUT WINDOW 10075' - 10125' 4-1/2" MILLOUTWINDOW 11425' - 11437' 10800' I-iBKR IBP I 11391' I-1BKRKBPKR 1 I 11748' r 2-7/8" SL TD LNR. 6.16#, , L-80, .00579 bpf, ID = 2.37' '\~;~~---=-~-=~~~-=-~=: ~~~~~ ITOPOF2-7/8" SLTD LNR l-i 11391' IWHIPSTOO< H 11446' 1 BKR WD-1 PKR ORIENTING -1 11434' KEY 80:, LEFT OF HIGH SIDE I PBTD l-i 11773' 14-1/2" LNR 12.6#, L-80, .0152 bpf.ID = 3.958" H 11866' DATE REV BY COMMENTS 03/18/86 ORIGINAL COMPLETION 02/26/97 NHITLO,^ SIDETRACK COM PLETION 03/04/02 RNrrp CORRECfIONS 09/02/02 GROTP API CORRECTION 10/09/02 JA LiKK WA IVER SAFETY NOTE 11/12/02 JRCiKK WA IVER SAFETY NOTE DA TE REV BY COMMENTS 07/09/03 CMO/TLP KB I3..EV A llON & MA X ANGLE 09/16/03 CMO/TLP ÆRF ANGLE CORRECfION 05/19/04 SRB/KAK SET IBP. ADPffiF OS/28/04 LWB/KAK GLM TVD DEPTH CORRECfIONS OS/29/04 DA V /KAK GL V C/O 07/11/04 MDOKAK ADÆRFS PRUDHOE BAY UNIT WB...L: D-28AL 1 ÆRMITNo: 1970140 API No: 50-029-21556-60 SEC 13, T11N. R13E.1495.9' FNL & 1692' FEL BP Exploration (Alaska) --- STATE OF ALASKA ALASK/-, ,alL AND GAS CONSERVATION Ct.,,~tMISSION REPORT OF. SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] 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, T11N, R13E At top of productive interval 2230' NSL, 1834' WEL, SEC. 14, T11 N, R13E At effective depth (n/a) At total depth 1612' SNL, 2111' WEL, SEC. 14,~T11N, R13E RST-PSP PL log Type ~f well: I~ Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 71.46' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-28AL1 9. Permit Number / Approval No. 97-14 10. APl Number 50- 029-21556-60 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11748 feet true vertical 8930 feet Effective depth: measured 11748 feet true vertical 8930 feet Casing Length Size Structural Conductor 67' Surface 2627' Intermediate 9839' Production Liner 436' Sidetrack Liner 1884' Sidetrack Liner 348' 7" Liner KOP (window) 10075'- 10125'. Plugs (measured) 4-1/2" Liner KOP. Abandoned 4-1/2" from 11434' to 11866' Junk (measured) Cemented MD TVD 20" x 30" 72 c.f. 13-3/8" 3720 c.f. 9-5/8" 575 c.f. 7" 575 c.f. 4-1/2" 341 c.f. 2-7/8" uncemented slotted liner 110' 110' 2670' 2865' 9882' 8424' 9639'-10075' 8192'-9186' 9530'-11434' 8204'-9027' 11390'-11748' 9027'-9030' Perforation depth: measured true vertical Open Perfs 10910' - 11110', 11270' - 11650', Slotted Liner 11390' - 11738' Open Perfs 9031' - 9027', 9028' - 9020', Slotted Liner 9027' - 9018' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 tubing to 9480' with 4-1/2" tailpipe @ 9538'. Packers and SSSV (type and measured depth) 9-5/8" TIW HBBP-T PKR @ 9480', 4-1/2" HES 'HXO' SSSVLN @ 2188'. (this Category II well --- No SSSV). 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Pdor to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ S~ott L~Voie --....-..~ Title Technical Assistant Prepared By Name/Number: :ii .,:' .~ i i:~. Date ~'/,~/~/ De Wayne ,~chnorr 564-5174 Submit In Duplicate D-28A Description of Work Completed NRWO OPERATIONS 05/02/2001 RST: PSP/BORAX RST SUMMARY 05/02/01 CAN NOT ASCERTAIN FIELD GCC PICK. SPLITS ARE CALCULATED FROM STOP COUNTS: 95% BELOW 11390' (2 7/8" LINER), 3% FROM 11385' - 11360', 1% FROM 11360' - 11330', 1% FROM 11330' - 11300'. NO CHANNELS NOTED FROM BORAX PASSES. FURTHER ANALYSIS OF LOGS TO BE DETERMINED BY APE.---TUBING AND FLOW LINE F/P ...... BRING WELL BACK ON PRODUCTION--- Fluids Pumped BBLS. Description 100 60/40 METH/WATER 800 2% KCL WATER 250 BORAX 1150 TOTAL STATE OF ALASKA ALASK~--,~IL AND GAS CONSERVATION C,..~MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Ann-Comm 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, T11N, R13E At top of productive interval 2230' NSL, 1834' WEL, SEC. 14, T11N, R13E At effective depth (n/a) At total depth 1612' SNL, 2111' WEL, SEC. 14;T11N, R13E 5. Type~f well: I~ Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 71.46' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-28AL1 9. Permit Number / Approval No. 97-14 10. APl Number 50-029-21556-60 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11748 feet true vertical 8930 feet Effective depth: measured 11748 feet true vertical 8930 feet Casing Length Size Structural Conductor 67' Surface 2627' Intermediate 9839' Production Liner 436' Sidetrack Liner 1884' Sidetrack Liner 348' Plugs (measured) Junk (measured) 7" Liner KOP (window) 10075' - 10125'. 4-1/2" Liner KOP. Abandoned 4-1/2" from 11434' to 11866' Cemented MD TVD 20" x 30" 72 c.f. 13-3/8" 3720 c.f. 9-5/8" 575 c.f. 7" 575 c.f. 4-1/2" 341 c.f. 2-7/8" uncemented slotted liner 110' 110' 2670' 2865' 9882' 8424' 9639'-10075' 8192'-9186' 9530'-11434' 8204'-9¢27' 11390'-11748' 9027'-9030' Perforation depth: measured true vertical Open Perfs 10910' - 11110', 11270' - 11650', Slotted Liner 11390' - 11738' Open Perfs 9031' - 9027', 9028' - 9020', Slotted Liner 9027' - 9018' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 tubing to 9480' with 4-1/2" tailpipe @ 9538'. Packers and SSSV (type and measured depth) 9-5/8" TIW HBBP-T PKR @ 9480', 4-1/2" HES 'HXO' SSSVLN @ 2188'. (this Category II well --- No SSSV). 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signedsco. LaVoie ~---~J~ ,/~f~ Title TechnicalAssistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 / '~ ~ "i ;"' i DeWayne S~hnorr~564-~174 Submit In Duplicate D-28A ~--J Description of Work Completed NRWO OPERATIONS 02/12/2001 02/13/2001 03/09/2001 03/11/2001 03/16/2001 03/16/2001 03/18/2001 03/19/2001 ANN-COMM: SET DGLV'S FOR MITIA (IN PROGRESS) ANN-COMM: SET DGLV'S FOR MITIA ANN-COMM: EVAL T X IA COMM ANN-COMM: EVAL T X IA X CA COMM ANN-COMM: MIT-IA ACID: MIT IA RST: ATTEMPT TO PULL TTP ANN-COMM: PULL PLUG (RATE) POST A/C WORK SUMMARY 02/12/01 SET WHIDDON C-SUB. PULL STA #5 - 3068' - LGLV, STA #4 - 5274' - LGLV UNABLE TO LATCH STA #3. PULL STA #1 - 9387'- OGLV: NOTE--> OGLV CHECK STUCK OFF SEAT. WELL LEFT SHUT IN. 02/13/01 PULL LGLV FROM STA #3. SET DGLV IN STA.# 5 (RM LATCH) @ 3068', SET DGLV IN STA #4 (RM LATCH) @ 5274', SET DGLV IN STA #3 (RA LATCH) @ 7654', SET DGLV IN STA #1 (RA LATCH) @ 9387'. PULL CS, FOUND "X" KEY IN CATCHER OF UNKNOWN ORIGIN. 03/09/01 TIFL PASSED, BLED IA FROM 1000 TO 0 PSI, DID NOT BUILD UP. 03/11/01 BLEED OA TO 0 PSI 03/16/01 MITIA PASSED TO 2000 PSI 03/16/01 DO PRESSURE TEST ON IA 03/18/01 EQUALIZE X-TTP @ 9450' SLM AND ATTEMPT TO PULL, BEAT ON FOR 45 MIN AND SHEARED OFF TRY AGAIN IN AM - WELL LEFT SHUT IN 03/19/01 PULLED PLUG FROM X-NIPPLE AT 9469' MD. NOTE: LOCK WAS MISSING A KEY (FOUND IN C-SUB ON EARLIER G/L JOB DATED 2/13/01) WELL RELEASED FOR PRODUCTION Fluids Pumped BBLS. Description 2 DIESEL FOR PFF 2 DIESEL 10 NEAT 424 CRUDE 2 DSL 440 TOTAL THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE PL M ATE IA L E W U N D E R T H IS M A R K E R C:LORI~IFILM.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 01/21/99 T DATA PLUS RUN RECVD ............. 97-014 NGP-TVD ~955-8931 FINAL 06/20/97 97-014 NGP-MD ~11437-11745 FINAL 06/20/97 97-014 EOW SRVY ~DR~LEX 11374.70-11745. 06/03/97 DA'r~,¥ WZ~,~, o~s ~ )F :':' /~??/ TO ~'/~/~ ?/ · / Are dry ditch samples required? yes ~-received? ye~ Was the well cored? yes ~_~_~-ysis & description received? Are well tests required? yes ~ived? Well is in compliance Initial 0 I~ I I--I--I IM G SEFt~dlC~S WELL LOG TRANSMITTAL To: State of Alaska June 25, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D-28A L1, AK-MW-70046 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21556-60. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 !:11 I__1__11M G S I::: I:! L/I r" E S WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs D-28A L1, AK-MW-70046 June 11, 1997 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, #G, Anchorage, AK 99518 D-28A L1: 2" x 5" MD Gamma Ray Logs: 50-029-21556-60 2"x 5" TVD Gamma Ray Logs: 50-029-21556-60 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company STATE OF ALASKA ALASK/'--~IL AND GAS CONSERVATION C':MMISSION .,,'ELL COMPLETION' OR RECOMP LETION r.IEPORT AND LOG 11. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDEC [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 9 7-14 3. Address P. O. Box 196612 Anchoraqe Alaska 99519-6612 4. Location of well at su trace 1496' SNL, 1692' WEL, Sec.23, T11N, R13E, UN,,.~ ,~;;,';~..77'.'~;:,~.?:7~ At Top Producing Inte~al ~ ...... 2230'NSL, 1834' WEL, Sec. 14, T11N, R13E, U¢~~'/-' ( At Total Depth ~~--' ___ i 1612'SNL, 2111' WEL, Sec. 14, T11N, R13E, uM ....................... 5. Elevation in feet (ind KBE= 71.46 8. APl Number 5o- 029-21556-60 9. Unit or Lease Name Prudhoe Bav Unit 10. Well Number D-28A L- 1 11. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool icate KB, DF, etc.) 16. Lease Designation and Serial No. ! I028285 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offsh ore I16. No. of Completions 2/21/97 2/24/97 J 2/25/97 n/a feet MSL ~1 one 18. Plug Back Depth (MD+T VD)/19. Directional Survey 120. I t 11 748 8930'TVD / YES [~] NO ~ 21. Thickness of Permafro approx1900' 17. Total Depth (MD+TVD) 11,748, 8930' TVD 22. Type Electric or Othe GR r Logs Run Depth where SSSV set 2, 188 feet MD f3PlP, iklAI Vl\l UII~IF~L_ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH ME: CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORE AMOUNT PULLED 2 7/8" 6.16# L-80 11,391 . 11,748 3 3/4" Uncemented slotted liner [ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. interval, size and number ) TUBING RECORD SIZE I DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SOJEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flow ing, gas lift, etc.) March 1, 1997 Date of Test Hours Tested Flow Tubing Casing Pressure Press. PRODUCTION FOR TEST PERIOD ]~ OIL-BBL GAS-MCF WATER-BBL CALCULATED~, OIL-BBL GAS-MCF IWATER-BBL 24-HOUR RATE -- I CORE DATA ICHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) 28. Brief description of lith ology, porosity, fracture s, apparent dips, and pre sence of oil, gas or wate r. Submit core chips. JL]~, ~ ]997 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Shublik A Shublik B Zone 4 GEOLOGIC MARKERS MEAS. DEPTH 9926 9976 10040 TRUE VERT. DEPTH 8460 8490 8531 30. ,' -ORMATION TESTS Include interval tested, pressure data, all fluids GOR, and time of each pha se. recovered and gravity, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and co rrect to the best of my k nowledge Title Cc)il Tuhip.q r)rillin~ TA Date General: This form is des all types of lands and le Item 1: Classification of water disposal, water sup Item 5: Indicate which el given in other spaces on Item 16 and 24: If this completion), so state in in item 27. Submit a sep data pertinent to such in Item 21: Indicate whether Item 23: Attached supplem igned for submitting a co ases in Alaska. Service Wells: Gas injec ply for injection, observ evation is used as refere this form and in any atta well is completed for sep item 16, and in item 24 s arate form for each addit terval. from ground level (GL) o ental records for this we ing and the location of t he cementing tool. Item 27: Method of Operat ion: Flowing, Gas Lift, R jection, Gas Injection, S hut-in, Other-explain. Item 28: If no cores take n, indicate "none". Form 10-407 INSTRUCTIONS replete and correct well c tion, water injection, st ation, injection for in-s nce (where not otherwise chments. arate production from mor how the producing interva ional interval to be sepa r other elevation (DF, KB II should show the detail od Pump, Hydraulic Pump, ompletion report and log on eam injection, air inject ion, salt itu combustion. shown) for depth measurem ents e than one interval (mult iple Is for only the interval reported rately produced, showing the , etc.). s of any multiple stage c ement- Daily Operations Well: D-28AL-1 Accept: 2~20~97 Field: Prudhoe Bay Spud: 2/21/97 APl: 50-029-21556-60 Release: 2~25~97 Permit: 97-14 CTD Unit: Nordic #1 Date Day Depth 2~20~97 1 11,434 ACCEPT RIG AT 01:00 HRS ON 02/20/97. Flange up BOP Stack to Swab valve. Spot tanks, Install cellar liner. M/U hardline to tanks. Spot Sperry and MI trailers. Spot MEOH tank. Prep to pressure and function test BOP's and Choke and Kill manifolds. 2-21-97 2 11,434 Pressure test BOP's, Choke and Kill Manifolds, State inspector witnessed test.. M/U Baker BHA to run oriented whipstock. RIH with BHA #1. Stop at 11,200 ft and turn well over to FIoPro. RIH and Set down on Baker Packer at 11,434 ft BKB. Whipstock did not latch first time. Set down 6 more times with 6,000 lbs down wt before whipstock latched. Pick up, set down 10k. Pick up and sheared 10K shear pin with 7K overpull. RIH and set down 13k on whipstock. POOH with running tools. Layout Baker running tools and M/U 2 7/8" Navidrill motor and 3.80" Baker starting mill. RIH with starting mill. Tag top of whipstock and mill 2.9 ft based on CT measure. Estimate 9" liner milled [-26" due to jar compression]. POOH with starting mill. Lay out starting Mill. 2~22~97 3 11,451 M/U Baker Window Mill and RIH with BHA#3. Mill from 11,420' - 11,432'. Wash and ream and POOH. 10- 12,000# Overpull from 11,250'- 11,160': PU Baker string mill and BHA #4. RIH, Correct depth to flag. Ream window from 11420 -11432 ft. Easy reaming. Drill formation from 11432 - 11444 ft bkb. Change out mud to new FIopro. Ream window four times. POOH. RIH with Drilex / Sperry / DS directional BHA. Test Sperry tools at 1000 ft. RIH. Tie-in with GR. Drill build section of horizontal sidetrack 2/23/97 4 11,610 Drill build section of horizontal sidetrack. Unable to get away from 4.~oriz. Liner with 1.25 deg bend motor. POOH to run higher bend motor. RIH with 2.52 deg bent motor and new Sperry Probe. Orient TF and drill build section from 11524 -11545 f. Deviation increased to 98 deg, OK. Magnetics still affecting Azimuth readings. Re-Orient TF. Drill at 100 deg dev. First good directional survey was 100 ft past window in liner. Drill from 11,570 - 11,610 ft with TF to Iow side to reduce deviation. Sperry tools failed at 11,610 ft. POOH. 2/24/97 5 11,748 POOH to change out Sperry GR probe. RIH with 1.25 deg bent motor and new Sperry tools. Drill through shale and drill good sand from 11,610 - 11,748 ft bkb. Tie-in with GR and tag TD, Final corrected TD = 11,748 ft BKB. POOH. Held Safety meeting. Run 12jts of 2 7/8", 6.16#, FL4S slotted liner. Deploywith stinger / work string with a Baker KB Packer and running tools. RIH to 11,170 ft CTD and sat down wt. Work CT several times but unable to get liner any deeper. Liner shoe was about 250 ft above window in horizontal 4.5" liner. POOH to inspect packer and guide shoe. .; 2/25/97 6 11,748 POOH to inspect packer and guide shoe. OOH, had dis-connected and left liner in hole. PU Hydraulic Release "G" spear, jars, and accelerator. TIH and latch liner. Pull 5,000# over and liner came up hole. Go back down 50' below original to of fish, no drag. POOH. Packer had not sheared. Decision to run packer as deployment sub and release w/"G" hydraulic release spear. M/U Baker packer to liner, M/U seal assembly. RIH with CS Hydril. Stab "G"hyd release running tool into packer. Pull test. RIH with Liner. Land liner at TD. Release from liner, leaving liner shoe at 11,748 ft BKB. POOH and tag top of liner at 11,391 ft BKB. Circ well to seawater. Haul 400 BBLS of FIoPro to MI. POOH. Freeze protect tubing with MEOH. Recover running tools and CS Hydril. Blow down CT with N2 2/26/97 7 Blow down CT with Nitrogen. Clean pit, Nipple down BOP. RELEASE RIG 10:00 AM 2125197 i D-28~uW. xis D-28 A END OF WELL SURVEY ~ii'iz97 3:i i BP EXPLORATION ALASKA INC. END OF WELL SURVEY REPORT FoR THE D-28 A SIDETRACK APRIL 1, 1997i VERTICAL SECTION USED RKB NOTE 345.16° RELATIVE TO TRUE NORTH i: -78.70'i t i i: GRID N/S AND ENV OFFSETS ALSO GRID ASP X AND Y ARE RELATIVE TO GRID NORTH GRID N/S AND ENV OFFSETS ARE REQUIRED FOR GEOLOGICAL WORK TRUE N/S AND E/W OFFSETS ARE RELATIVE TO TRUE NORTH i i i i: ALL AZIMUTH VALUES ARE RELATIVE TO TRUE NORTH i i i: OFFSETS ARE CALCULATED TO GRID AND TRUE NORTH AS INDICATED GRID CONVERGENCE i: 1-17° MAGNETIC DEC. TO TRUE NORTH PREPARED BY: DATES: DIRECTIONAL CO.i IVlWD CO. i: 28-49° i: DRILEX i: FEB. 21 TO FEB. 23, 1997 I: DRILEX SYSTEMS, INC. i:SPERRYSUN COMMENTS MD! Inc.i Dir! SS DEPTHi VS! TRUE~ fti deg! degl ft! ft! N/~ i 11374.70! 90,061 349.23j 8955.50i 0.00i Tie in Point/KOP TD TRUE! E/-WI degl'lO0 ! Turni Dogleg GRID GRID ~-SP YI ASP X d e g 11~'", degllO0 NI-S E/-W: ftI ft 4816.70i -303.901 0.00) 0.00i 0.00 -308.601 0.001 0.00', 0.00 4809.50 4834.30 -402,20 5964302.01 653056.1 -407,40 5964327.01 653050.9 11400.00 90.06 349.23'~ 8955.50] 25.20 4841.60 11437.001 91.67i 349.231 895490! 62.10, 4877.90 -315.501 4.401 0.001 4.40 4870.40 -415.10, 5964363.0! 653043.3 11456.00i 90.621 341.971 8954.50i 81.10 4896.30 -320.30i -5.50l -38.201 38.60 4888.70 -420.20' 5964382.0! 653038.1 11480.60i 91.93i 338.871 8954.00! 105.60] 4919.50 -328.50i 5.301 -12601 13.70' 4911.70 -428.90' 5964405.0! 653029.4 11510.701 97.21i 334.98! 8951.60i 135.30! 4947.00] -34030! 17.50 -12.901 21~01- 4939.10 -441.20' 5964432.0! 653017.1 11537.10 i -453.30 5964455.0 ! 653005.0 100.80! 331.97i 8947.501 160.80i 4970.40i -351.90i 13.60! -11.40~ 17.70i 4962.20 100.401 329.07i 8942.70i 185.401 4992.40l -364.401 -1.601 -11.201 11.20! 4984.00! 95.10! 335.971 8938.50', 215.601 5019.901 -378.701 -16.90i 22.00; 27.60', 5011.20 11562.90: -466.30 5964477.0i 652992.1 11594.20 , -481.10 5964504.01 652977.2 11624.90~ 93.161 337.671 8936.30~ 245.90! 5048.10i -390.70! -6.30i 5.50! ~ 5039.00 -493.70 5964532.0i 652964.6 11655.701 93.901 342.77~ 8934.40i 276.50! 5077.00i -401.101 2.40l 16.601 16.70} 5067.70! 11687.001 93.40i 346.871 8932.401 307.70i 5107,10J -409.30 11726.00! 90 80i 351.27~ 8931.00~ 346.60i 5145.40i -416.70 r 11745.001 89,53! 353.41! 8930.901 365.501 5164 201 -419.20 -1.60i 13.10[ 13.201 5097.70 -6.7~ 11.30i 13 10! 5135.80! -6.70 11.30i 13.10 -504.70 5964561.01 652953.6 -513.50 THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. 5964591.0J 652944.8 -521.70 5964629.0i 652936.6 5154.60i -524.60 5964648.01 652933.6 BIMO HADIPUTRO ~: i i i DISTRICT MANAGER- DRILEX-sYSTEMS, INC. ! ! ' i I -,,_,-,,,,-,,-,_,vv.×,s D-28 A END OF WELL SURVE'Y "'"~' BP EXPLORATIONiALASKA INC. END ?Fl WELL SURVEY REPORTi FORI THE D-28 A SIDETP~CK APi~IL 1, 19971 I VERTICAL SECTION USED : 345.16° RELATIVE TO TRUE NORTH I ~KB , :-78.70' , , , , , , , -- ~TE] I i: GRID N/S'AND FAN OFFSETS ALSO GRID ASP X AND Y ARE RELATIVE TO GRID NOt RTHJ J I · TRUE N/S AND ENV OFFSETS ARE RELATIVE TO TRUE NORTH ~ --- -- i I ' ALL AZIMUTH VALUES ARE RELAT,VE TO TRUE NORTH , ] t 1' ~ ] ' OFFSETS ARE CALCULATED TO GRID AND TRUE NORTH AS INDICATED G~ID CONVERGENCE I: 1.17° i i ] i ' I MAGNETIC DEC. TO TRUE NO~,TH ! I128'49° i j J I I -- -- i JI DRILEX i i J l PREPARED BY' ]I' 'i ' ! ' i ' I ~" !, -- , DRILEX SYSTEMS. INC. i ! J I ?o co. I j ! ' I ! , i ' I I __~__ .~ ,.gl - ,I ,,-~ ~.~i ~.g,,oo ~e~,~OOooo "~'~i I . i -402.2o I I J ' i 0.00 4809.501 5964302.0 653056.1 Tie in Point/KOP 11374.70 90.06l 349.231 8955.50 0.00 4816.70 -303.901 0.00 . -- I 11400.00' 90.06 349.23 8955.50] 25.201 4841.60, -308.60 0.001 0.00 4834.30! -407.40 5964327.0 653050.~ · 0.00 __ 11437.00 91.67 349.23 8954.90i 62.101 4877.90i -315.50i 4.40] 0.001 4.40 4870.40! -415.10~ 5964363.0 653043.3 11456.001 90.62 341.97 8954.50i 81.10! 4896.30 -320.30] -5.501 -38.20 38.60 4888.701 -420.2~ 5964382.0 653038.1 11510.701 97.21 334.981 8951 60! 135.30] 4947.001 -340.301 17.50 -12.901 21.80l ' LL__- · i 5964432.0 653017.1 11537.10 100.80 331.971 8947.50 160.801 4970.40i -351 4962.20! , 11562.90 100.40i 329.07i 8942.70 185.401 4992.40 .901 13.60i -11.401 17.701 . -453.30i 5964455.0] 653005.0 , -364.401 -1.60 -11.20 11.20l 4984.00i -~-.301 5964477.0 652992.~ i 11594.20 95.10 335.97 8938.50i 215.60! 5019.901 -378.70i-16.90 22.00] 27.60i 5011.20i -481'101 5964504.01 652977.2 I · i ~168~.00 93.40 346.87 8932.40' 307.70i ~10710 -409.30! -1.60i 13.10i 1320 5097.701 -5~3.50 5964591.0 652944.8 __ 11726.00 90.80 351.27 8931.00i 346.60 5145140 -416.70i -6.70! 11.30 13.10] 5135.80! -521.70 5964629.0 652936.6 THESE SURVEYS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. !I i i i DISTRICT MANAGER- DRILEX SYSTEMS, INC. I i ] i [ I ] , ~ ~ , ~ . TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January24,1997 Ted Stagg, Coiled Tubing Drilling Engineer BP Exploration (Alaska)Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit D-28AL1 BP Exploration (Alaska) Inc. Permit No. 97-14 Surf Loc 1496'SNL, 1692'WEL, Sec 23, T1 IN, R13E, UM Btmhole Loc 1612'SNL, 2083'WEL, Sec 14, T11N, R13E, UM Dear Mr Stagg: Enclosed is the approved application for permit to drill the above referenced well'. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This permit is for a new segTnent for ex!sting well D-28A, API No. 02921556-01, Permit No. 95-213. Production should continue to be reported as a function of the original well identifier. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may ~vitness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnston X " Chairman ~ BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game. Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl MEMORANDUM TO: David john, Chairmar~/2' THRU' Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 20, 1997 FILE NO: AH9JBTEE.DOC FROM: Lou Grimaldi,/-,,,~., SUBJECT: Petroleum Inspector BOPE Test Nordic rig #3. BPX well #D-28 ~ Prudhoe Bay Field PTD #97-14~r Thursday, February 20, 1997' I witnessed the initial BOPE test on Nordic/Dowell rig #1 which was redriiling over BPX well #D-28 in the Prudhoe Bay Field. The rig was ready to test when I arrived. The test went well with the exception of a minor leakoff on all components. We traced this leakage to the tree valves inability to hold pressure from the top side by observing all other possible leak points on each set of tested components. One leak on the choke manifold was found, the outside valve to the gas buster was confirmed by fluid entry into the pit's. This valve was greased, cycled and retested. The H2S and Methane detectors were tested and although all sensors sounded the alarm and lights the set points were set much lower then our minimums (10% LEL methane & 10 PPM H2S lights & siren). ! explained our guidelines for gas detectors to Zane Montague (Nordic Tooipusher). Although I commended him on the operation of this rigs gas detection system I had a concem that continuos iow concentration alarms might lull the crews reactions. The air over hydraulic pumps would not operate when the accumulator was tested. The accumulator had a good recharge time (1 min. 54 sec's) without the air pumps. These will be repaired and operational in one day. - Doug Yessak (Nordic Driller) performed a very competent test and showed good procedure. It was evident to me that this standard of test was normal 'for him. AH9JBTEE. DOC page I of 2 . I spoke with Charlie Parker (BPX rep) about the problem with the leaky tree valve's. There are a few possibilities for avoiding this problem in the future. The tree valves could be grease locked before the test, this would help but the grease seal would likely break down after repeated pressure ups and bleed offs. A two way check could be installed in the tubing hanger and tested before the rig pulls over the well. There has been resistance to this idea due to the past experiences of some two way checks not equalizing and the additional time needed to rig up lubricator and rods in order to pull the check under pressure. I explained to Charlie that l could allow for this leakage rate as we could make a visual determination for each components integrity. This extended this test time by at least one hour and probably more. I also feared that if this occurred regularly it might lead to complacency and possibly cause a pass on a failed component. SUMMARY:. I witnessed the initial BOPE test on Nordic rig #2. There were two failures. A valve on the choke manifold and the air-over-hydraulic pumps on the accumulator. Test time 4 hours. Two failures. Attachments: AH9JBTEE.XLS CC: Al SchmoyedKen Smith (CTU Drilling Supervisors) NON-CONFIDENTIAL AH9JBTEE.DOC page 2 of 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Nordic/Dowefl Rig No. 1 PTD # BPX Rep.: D-28 ~ Rig Rep.: Set @ Location: Sec. X Weekly Other DATE: 2/20/97 97-14~ Rig Ph.# 448-1345 Charlie Parker Zane Montague 23 T. 11N R. 13E Meridian Umait TEST DATA BOP STACK: Coil Tubinq Unit: Pipe/Slip Rams Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 250/3500 Functioned P 250/3500 P 250/3500 P 250/3500 P 250/3500 P 250/3500 P 250/3500 P 250/3500 P 250/3500 P MUD SYSTEM: Visual Alarm Tdp Tank P P Pit Level Indicators P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quan. Pressure P/F 14 250/3500 F 34 250/3500 P 1 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: 2950 psi I P 2,250I P minutes 33 1 minutes 54 P Remote: 3 Bottles @ 2150 Psig. sec. sec. P MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Permit to ddll: P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P ~ ' . · " . --~ TEST RESULTS' ' Number of Failures: 2 ,Test Time: 4.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Wdtten or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Outside valve to Gas Buster had slight leak, Greased and retest "OK". Airpumps on Koomey inoperative. Repair and notify Inspector. Distribution: odg-Well File c- Oper./Rig c- Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO YES 24 HOUR NOTICE GIVEN X' NO Waived By: Witnessed By: Louis R. Grimaldi Form Revised 2/20/97 L.G. AH9JBTEF_XLS ~: :: ~ 2J2,t/97 STATE OF ALASKA ALASKA C ~,ND GAS CONSERVATION CORY. SSlON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill Bllb. Type of well. ExploratoryF'l Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=71.46 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchoraqe, Alaska 99519-6612 028285 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o,~c 25.025) 1496'SNL, 1692' WEL, SEC. 23, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2230' NSL, 1834' WEL, SEC. 14, T11N, R13E D-28AL1 2S100302630-277 At total depth 9. Approximate spud date Amount 1612' SNL, 2083' WEL, Sec. 14, T11N, R13E Feb 2,1997 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 028280 @ 1612 feet no close approach feet 2560 11738 MD, 8939 TVDss feet :16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickott deptl~ ~,43o feet Maximum hole angle g~ o Maximum surface 3330 psig At total depth (TVD) 8800'/3285 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 3/4" 2-7/8" 6.16# L-80 FL-4S 250' .¢4¢~4~- 8947 11738 8939 uncemented slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. 4(- /,~)~ .~, ~~~---,i V ~ Present well condition summary ,/'~4,, ~,~ j)~r- Total depth: measured 11866 feet Plugs (measured)~__~d Afl ~. '! 1997 true vertical 8948ss feet Effective depth: measured 11773 feet Junk (measured) Alask¢. Oil & Gas Cons. true vertical 8947ss feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural BKB Conductor 67' 20X30 8 cu.yds. 110 110' Surface 2627' 13-3/8" 3720 c.f. 2670' 2670' Intermediate 9839' 9-5/8" 575 c.f. 9882' 8434' P r o d u ct i o n 436 7" 575 c.f. 9639-100 75 8205-8545' Lin e r 2336 4-1/2" 341 c.f. 9530-11866 8208-9020' Perforation depth: measured 10,910'-11,110'; 11,270'-11,650' true vertical 8959'-8955'; 8956'-8949'ss 20. Attachments Filing fee[] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[-I 20 AAC 25.050 requirementsl-I 21.1 hereby certify_..tha~~_oing is true and correct to the best of my knowledge 7 Commission Use Only PermiLNumber__ ---- ,~,/~'/"/-7Z 15 O- (~'~-~-IAPI number ~-/0'",5"~~'- (~¢IIAppr°val date forSee otherC°Ver letter requirements Conditions of approval Samples required [] Yes []No Mud log required [] Yes [] No Hydrogen sulfide measures ]X'l Yes [] No D~rectional survey required J~ Yes [] No Required working pressure for DOPE []2M; F13M;,v, FISM; I-I10M; []15M; Other: 0rigJnal Signed ~Sy // ¢/~ ,.) Approved by po,,;,4 W, Johnston E~ ~,~ by order of ~:~,.~,u Commissioner me commission Date -- Form 10-401 Rev. 12-1-85 Submit icate BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date: Jan. 20, 1997 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Senior Petroleum Engineer Re: Well D-28AL1 CT Sidetrack Well D-28A is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prepare D-28A for sidetracking and is submitted as an attachment to Form 10-401. Form 10-403 is not being submitted as no existing perforations will be abandoned. 1. Perform tubing integrity test. 2. Drift tubing and liner with a 3.7" OD, 20 ft long drift. 3. Use CTE to drift horizontal liner through the whipstock interval. 4. Use CTE to install the whipstock anchor with confirmed orientation. 5. Rig up CT drilling unit and set whipstock into anchor. 6. Mill window with 2 3/8" drilling coil. Sincerely, Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center BPX D-28AL1 Sidetrack Summary of Operations: Well D-28A is currently producing. The well is being sidetracked to improve drainage from the 13P. No existing perforations will be abandoned but approximately 220 feet of the lowermost existing perforations will be below a 4 1/2" permanent whipstock. The whipstock will have flow channels to permit flow from the lowermost perforations to merge with flow from the new lateral hole. The new lateral will be completed with a slotted liner. This sidetrack will be conducted in two phases. Phase 1: Prep for Window: Planned for Jan. 27 to Feb. 1, 1977. - Perform tubing integrity test and drift for whipstock RU CTE and tag TD with 3.7" drift. - Set whipstock anchor with confirmed orientation. Phase 2: Mill Window and Drill Directional Hole: Planned to start Feb. 2, 1997. - Directional drilling coil tubing equipment will be dgged up and utilized to mill the window and drill the directional hole as per attached plan to planned TD of 11,738' MD (8939' TVDss). Mud Program: - Phase 1: produced fluids - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, FL-4S slotted liner will be run from TD to approx. 11,738' MD and hung with a liner top packer. Well Control: - A BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 11,430' MD (8954' TVD ss) - TD: 11,738' MD (8,939' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. LoAgging - Gamma Ray log will be run over the open hole section. ~-~-. ~' KB. ELEV = 71.46' TREE: 6" McEVOY D-28AL1 Proposed Comp[ .on BF. ELEV = 42.71' WELLHEAD: McEVOY ACTUATOR: OTiS O~,~ 4'5" HES "HXO" SSSVN I 2'188' I( 3.813" ID FOC~ ) 13 3/8", 72#/fL, 2,670' · ~ L-80, BTRSI I HES GAS LIFT MANDREL , (TB)(W/1.5" RA LATCH) K;OP: 4000' MAXANGLE: 68° @ 11,208'¢ No MD (BKB) TVDss Ang I ~ 5 3,087' 3,015' 0o ,', 4 5,293' 5,144' 33° Tubing: 4.5",12.6#, L-80 3 7,667' 6,806' 43° Modified Buttress. 3.958" 2 9,201' 7,901' 41° ID / 1 9,398' 8,046' 44° Capacity: .01522 BBLs/ft. J NOTE: 4.5" Tail pipe is inside the 4.5" HFS X-Nipple ( 3.813" ) I 9,469' 9 5~8" x 7" liner Hanger. I I r Tie Back Sleeve Approx. 8' ~/'/'/'~ I~'"~"~"~ 9-5/8"x 4.5" TIW HBBP-T Pkr. 9,480' I I 9-5/8"x7"Baker"HMC"LinerPkr.I 9,530'1 ,41 _ I k"~ 4.5"HESXN-Nipple(3.725") [ 9,526'I 9 5/8,47#/,, I 9 882' I · L-80, BTRS I ' I- cemented DP Perf Alpha Jet 2-3/4", 4-SPF, Random orientation. 2-3/4 4 11,270'-11,650' Open 2/96 D- 28 A Vertical Section Path Distance (Feet) 4,500 4,600 4,700 4,800 4,900 5,000 5,100 5,200 5,300 5,400 5,500 5,600 8920 I t t I I I I I I I I 8930 894O 8950 DL 1= 15 deg/100 8,930 8,954 896O 897O 8980 Angle O K.O.=91 deg MD:11430 11738 TD Tot Drld:308 ft Marker Depths @Ori9 Wellbore a,s3sI 8,939l~t 'rVD 8,954[ 8,954[ff TVD Kick Off [ e,ss41 TVD 11~430~ft MD iDeprtr @KO 4~996 ft MD KO Pt 11,430I MD New Hole 308I I Total MD 11 ~738[ , TVD TD 8~939[ Build Rt degll00 MD (fi) ' s.o 0.0 100 '15'.0'' 41 0.0 130 0.1 1 ,, 0.1 I Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 3O8 Drawn: 1/17/97 10:33 Plan Name: Case 1 -7oo D-28A Plan View -500 X distance from Sfc Loc -300 5300 5200 5100 5000 49OO 480O 4700 Name D-28A Distance 5,178 ft Az 3 54 deq NEW HOLE F_~ (X) Kick Off -273 TD ~501 State Plane 652,957 Surface Loc 653,458 5,964,646[ 5,959,492 Az Ch( MD (ft) o.o -15.0 1 00 0.0 41 15.0 130 0.0 1 0.0 I Curve 1 Curve 2 Curve 3 Curve 4 Curve $ Curve 6 308 Drawn: 1/1 7~97 10:33 Plan Name: Case 1 D-28AL1 CT Drilling & Completion BOP LU 36" 22.5" 18" 38" 2 3/8" CT-~ I 10,000 psi Pack-Off 7 1/16" Annular 7 1/16' 5000 psi I ,_, I ~1~~1~ ~ 7 1/16" X 5,~0 psi ~ ~ s,,.s ~ ~ ~ ~/~,, 7 1/16" ~ Pipe ~ ~ 2 3/'8" I SWAB OR MASTER VALVE 11/22/96 WELL PERMIT CHECKLISToo Y INI~ CLXSS Z9~. /--~? / GEOL AREA PROGRAM: expD dev~redrlr] servD wellbore se~ ann disp para reqD ADMINISTRATION ENGINEERING GEOLOGY 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... REMARKS 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . ..; ~ ~_~ 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... .-rY- 24. Drilling fluid program schematic & equip list adequate .~J-~ N 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~ psig~/ N ~ ~~ 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~x..~, N Permit can be issued w/o hydrogen sulfide measures .... Y ~ Data presented on potential overpressure zones ..... Y/N/ Seismic analysis of shallow gas zones ......... ~ N /~,~ Seabed condition survey (if off-shore) ....... / Y N Contact name/phone for weekly progress reports . . /. . Y N 30. 31. 32. 33. 34. [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: JDH~ mcm~ Comm%r~s / T nst=uctions: ~ 'MS\cheklist rev 01/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Jun 23 10:47:51 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/06/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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 Date D-28A L1 500292155660 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 23-JUN-97 MWD RUN t AK-MW-70046 BUD JAHN PARKER/WHITL MWD RUN 2 AK-MW-70046 BUD JAHN PARKER/WHITL MWD RUN 3 AK-MW-70046 BUD JAHN PARKER/WHITL 23 liN 13E 1496 1692 78.70 .00 42.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.630 9882.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3.750 7.000 11419.0 4.500 11419.0 11748.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 3 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. WELLBORE STARTED OVER 90 DEGREES AT 11437'MD, 8955'SSTVD AND STAYED INVERTED TO TOTAL DEPTH (TD) AT 11745'MD, 8931'SSTVD. THEREFORE ONLY INVERTED SSTVD LOG IS PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR GREG BERNASKI OF BP EXPLORATION (ALASKA), INC. ON 20 JUNE, 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11745'MD, 8931'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE S~Y PBU TOOL CODE START DEPTH STOP DEPTH GR 11410.0 11721.0 ROP 11437.0 11745.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11437.0 11481.0 2 11481.0 11610.0 3 11610.0 11745.0 MERGED MAIN PASS. $ · Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11410 11745 11577.5 671 11410 GR 20.29 835.27 59.7173 623 11410 ROP 7.17 954.7 70.2447 617 11437 Last Reading 11745 11721 11745 First Reading For Entire File .......... 11410 Last Reading For Entire File ........... 11745 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUI~MARY VENDOR TOOL CODE START DEPTH GR 11410.0 ROP 11437.0 STOP DEPTH 11454.5 11481.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERV~LL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINII~JM ANGLE: MAXIMUM ANGLE: 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 22-FEB-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 11481.0 11437.0 11481.0 90.1 91.3 TOOL NUMBER NGP 325 3.750 3.8 FLO- PRO 8.70 .0 9.0 6.4 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11410 11481 11445.5 143 GR 36.72 56.06 45.2678 90 ROP 7.17 954.7 123.067 89 First Last Reading Reading 11410 11481 11410 11454.5 11437 11481 First Reading For Entire File .......... 11410 Last Reading For Entire File ........... 11481 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11453.5 11583.0 ROP 11481.0 11610.0 $ LOG HEADER DATA DATE LOGGED: 22-FEB-97 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: 95.1 MAXIMUM ANGLE: 100.8 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 11610.0 11481.0 11610.0 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 (OH/~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP 24 3.750 3.8 FLO-PRO 8.70 .0 9.0 6.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 75.0 First Name Min Max Mean Nsam Reading DEPT 11453.5 11610 11531.8 314 11453.5 GR 30.43 514.06 56.9081 260 11453.5 ROP 14.86 525.21 62.1854 259 11481 Last Reading 11610 11583 11610 First Reading For Entire File .......... 11453.5 Last Reading For Entire File ........... 11610 File Traile~ Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11583.0 11721.0 ROP 11611.0 11745.0 $ LOG HEADER DATA DATE LOGGED: 23-FEB-97 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: 89.5 MAXIMUM ANGLE: 93.9 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: MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 11745.0 11610.0 11745.0 TOOL NUMBER NGP 74 3.750 3.8 FLO-PRO 8.80 .0 9.5 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OPLMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 70.3 First Name Min Max Mean Nsam Reading DEPT 11583 11745 11664 325 11583 GR 20.29 835.27 67.2416 277 11583 ROP 10.03 106.85 62.0634 269 11611 Last Reading 11745 11721 11745 First Reading For Entire File .......... 11583 Last Reading For Entire File ........... 11745 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/06/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File