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196-103
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~¢ -~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other COMMENTS: Scanned by: Beverly ~Vincent Nathan Lowell Date: ~-I~/' Isl L~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA ~~EIVED3/~~~ ALASK~IL AND GAS CONSERVATION COSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG !i~AR 1 ~ 2009 m~ _~__ nu a n__ n___ rv,.....,,. ..~.... 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero el la ®Devel~~a~ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2/17/2009 12. Permit to Drill .Number 196-103 ' 308-444 3. Address:- P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/13/1996 13. API Number 5o°oRq-zi479-o~ 50-21~~i~A~-- 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/19/1996 14. Well Name and Number: PBU 05-27A- 2144 FSL, 1207 FWL, SEC. 32, T11N, R15E, UM Top of Productive Horizon: 407 FNL, 3721' FWL, SEC. 05, T10N, R15E, UM 8. KB (ft above MSL): 67' - Ground (ft MSL): 34.54' 15. Field /Pool(s): Prudhoe Bay Field % Prudhoe Bay Total Depth: 2631' FNL, 1434' FWL, SEC. 04, T10N, R15E, UM 9. Plug Back Depth (MD+TVp) 13600' 9045' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 698296 y- 5948338 Zone- ASP4 10. Total Depth (MD+TVD) 11573' 9046' 16. Property Designation: ADL 028328 TPI: x- 700885 y- 5945856 Zone- ASP4 Total Depth: x- 703943 y- 5943713 Zone- ASP4 11. SSSV DeN hA(MD+TVD) 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi r nic and rin inf rmation er 20 AAC 25.05 19. Water depth, if offshore NIA ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FL GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED. 20" 91.5# H-4 S rfa 11 urf 110' 30" 2850 # Pol - / " / 1 - / " III -5/8" 47# L-80 urf 2' rf ce 8501' 1 -1/4" 75 x I s'G' 7" 2 1 1' 11154' 2 0' 9060' - /2" 50 x I " 1 1 1 n I i 2- / " 4.6# L- 12 2T 1 6 0' 9034' 904 ' - /4" n men ed SI d i er 23. Open to production or inject ion? ^ Yes ®No 24. TueING RECORD If Yes, IISt each I (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD a-u2°, 12.6# x 3-V2^, s.z#, ~-ao 10496' 10477 MD TVD MD TVD 2S. ACID,. FRACTURE, CEMENT SQUEEZE, ETC. r~~ry~ DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED ~, , , .t;,,°~v~~i~,a, ~' !~ ~~ - ~~ ~_J~ `" 11573' Set Whipstock 11573' P&A w/ 45 Bbls Class 'G' 26. 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 PfeSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE. DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Core s A wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~~Z Form 10-407 Revised OZ/2007 r t CO TINUED ON REVERSE SIDE =~l"p (t ~q 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND M RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 9555' 8519' None Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram ' 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. . ~~/ I t/V Signed Terrie Hubble Title Drilling Technologist Date PBU 05-27A 196-103 308-444 Prepared ey NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and .base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 0212007 Submit Original Only • U 05-27A, Well History (Pre Rig Sidetrack) Date Summary 11/29/08 WELL S/I ON ARRIVAL. DRIFTED TO 10,700' SLM W/2.70" CENT. CURRENTLY IN HOLE W/ 24 ARM PDS CALIPER. 11/29/08 TIO= 300/525/50 Asisst Slickline. Pump down 12.3 bbls methanol down tbg per slickline. Valve positions at departure: Wing Shut, Swab, Master, SSV are open and Annular valves open to gauges. SLB Slickline on well at departure, FWHP's = 250/ 525/ 50 11/30/08 RAN 24 ARM PDS CALIPER FROM 10,600' SLM (NO DATA FROM 3000' TO SURFACE). BRUSHED X- NIPPLE AT 9,632' MD W/3-1/2" BLB, 2.80" G.RING. SET 3 1/2" PX-PLUG BODY AT 9,613' SLM, (4-1/4" EO PORTS). SET PRONG IN PLUG BODY AT 9,605' SLM (1.81" BODY, 1-3/4" F.N., 96" OAL). RAN 42 ARM PDS CALIPER FROM 3,100' SLM TO SURFACE (GOOD DATA). 12/01/08 T/I/0=250/520/0 Assist Slickline. Pumped 2 bbls methanol followed by 1 bbls crude to pressure up Tbg. TP reached 2000 psi and decreased to 800 psi. Slickline RIH to pull prong and investigate. Released from jobsite. FWHP's = 250/520/0. Slickline on well upon LRS departure. 12/01/08 RE-SET PRONG IN 3 1/2" PX-PLUG AT 9605' SLM. LEFT WELL S/I NOTIFIED PAD OP ON DEPARTURE. 1.2/02/08 T/I/0= 90/550/0. Temp= SI. TBG & IA FL for FB. AL line Si @ casing valve. ALP= 2400 psi. TBG FL @ 162' (3 bbls). IA FL @ 1638' (88 bbls). SV, WV =Closed. SSV, MV =Open. IA, OA = OTG. NOVP. 12/04/08 T/I/0=200/520/20 Temp=S1 MIT-T FAILED to 3000 psi. Pumped down Tbg with 3 bbls 0°F neat meth and 11.1 bbls 80°F crude to reach test pressure for MITT. Tbg lost 2820 psi in 15 min. RD from Tbg & RU to IA to attempt CMIT TxIA to 3000 psi. 12/05/08 T/I/0=180/620/100 Temp=Sl CMIT TxIA PASSED to 3000 psi. Loaded IA with 80 bbls crude. Subsequent testing showed a leaking wing valve, with consistent TxIA communication. Greased wing twice, and applied heat. Still leaked. Performed CMIT TxIA with SSV and Master shut in. Pressured up IA with 9.1 bbls crude. IA lost 80 psi in 1st 15 min, 40 psi in 2nd 15 min for a total pressure loss of 120 psi in 30 min. Bled IA. FWHP's = 750/800/240. Swab =shut, Master =open, Wing =shut, SSV =shut, IA = open, OA =open, AL =shut. 12/08/08 T/I/O = 1100/1100/160. Temp = SI. Bleed WHP's to 0 psi pre-PPPOT. Flow line SI @ wing (400 psi). SI grove valve. TBG FL @ surface. Bled TBG pressure to 670 psi in 30 min (7.5bbls liquid). During bleed, IAP decreased to 720 psi. SI, monitored for 30 min. No change in Pressures. Final W HP's = 670/720/160. WV, SV =Closed. MV, SSV =Open. IA & OA = OTG. NOVP. 12/09/08 T/I/O = 710/780/130. Temp = SI. Bleed WHPs to 0 psi pre-PPOT. AL SI @ CSG valve. TP increased 40 psi, IAP increased 60 psi, OAP decreased 30 psi since day shift. IA FL @ 180' (10 bbls). T & OA FL @ surface. Flowline @ 710 psi. Bled IAP from 780 psi to 0 psi in 5 hrs 30 min (all gas). While bleeding IAP, TP decreased to 15 psi, OAP decreased to 25 psi and flowline decreased to 180 psi. Bled TP from 15 psi to 0 psi in 5 min (all gas). Bled OAP from 25 psi to 0 psi in 5 min (all fluid). SI and monitor for 30 min. IA FL unchanged. Final WHPs = 5/10/5. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 12/10/08 T/I/O = 50/100/20. Temp = SI. Bleed WHPs to 0 psi pre PPPOT. AL line SI @ casing valve. ALP = 1740 psi. T & IA FL @ surface, IA FL @ 180' (10 bbl). Bled TP from 50 psi to 30 psi,Sl fluid to surface. Bled OAP from 20 psi to 0 psi into a grounded metal bucket in 1 min. Bled IAP from 100 psi to 0 psi in 2 hour 40 min into BT. During IA bleed TP decreased to a VAC. Monitored pressures for 60 min. IAP increased to 3 psi, OAP increased to 11 psi. Bled IAP & OAP to 0 psi in 10 min, held open bleed for 30 min. Final WHPs =VAC/0/0. MV &SSV open. IA & OA valves OTGs. WV, SV & AL closed. 12/11/08 T/I/O =VAC/20/0+. Temp= SI. WHPs post-bleed pre-PPPOT. ALP= 1740 psi, SI @ casing valve. TBGP unchanged, IAP increased 20 psi, OAP increased 10 psi from 12/10/08. SV, WV = C SSV, MV = O IA, OA = OTG NOVP. Page 1 of 3 • 05-27A, Well History (Pre Rig Sidetrack) Date Summary 12/12/08 T/I/0=65/130/25. Temp=Sl. WHPs post-bleed pre-PPPOT. AL SI C~ casing valve. ALP = 1740 psi. TP increased 65 psi, IAP increased 110 psi, OAP increased 5 psi overnight. SV, WV =Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 12/13/08 T/IA/OA = SI/0/0 Temp =cold PPPOT-T (PASS) PPPOT-IC (PASS) PPPOT-T Remove 1/2" NPT plug off set internal check 0 psi, remove internal check install 1/2" Alemite test fitting. Pressured THA void to 5000 psi for 30 min test, 4900/ 15 minutes, 4900/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torque LDS "N style" all were in good working and visual condition. PPPOT-IC Remove 1/2" NPT plug off set internal check 0 psi, remove internal check install 1/2" Alemite test fitting. Pressured IC void to 3500 psi for 30 min test, 3400/ 15 minutes, 3350/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torque LDS "N style" all were in good working and visual condition. 12/13/08 T/I/O = 125/160/25. Temp=S1. Bleed IAP & OAP to 0 psi (pre-PPPOT). AL SI @ casing valve. ALP=1910 psi. TP increased 60 psi, IAP increased 30 psi, OAP unchanged overnight. IA FL Q 234' (12.5 bbl). OA FL near surface. Bled IAP to 0 + psi in 1 hr 45 min. Bled OAP to 0 psi in 15 min. TP went on vac during IA bleed. Turned well over to Cameron. Final WHPs =Vac/0+/0+. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 01/08/09 WELL S/I ON ARRIVAL. SET 3-1/2" SLIP STOP CATCHER Q 6056' SLM. PULLED RK-OGLV FROM STA # 2 @ 5949' MD, PULLED RK-LGLV FROM STA # 1 C~ 3120' MD. SET RK-DGLV IN STA # 1 C~ 3120' MD &STA # 2 C«~ 5959' SLM. PULLED 3 1/2" SLIP STOP CATCHER FROM 6065' SLM. 01/08/09 T/I/0= 1060/0/60 Temp = SI Assist Slickline pump as directed. Load meth at Pad 10, Load diesel at COTU, Road to location, Spot equipment. Job In Progress. 01/09/09 Temp= SI Assist Slickline pump as directed. MIT IA to 3000 psi FAILED. Pumped 23 bbls diesel down IA, TBG pressure tracked up with IAP, Bleed IAP, TBG pressure tracked down with IAP, Pumped 5 bbls diesel down IA, TBG pressure tracked up with IAP, Bleed IAP, Final WHP's 1000/960/20 "Valves on departure IA & OA open to gages" "SLB on well Q time of departure" 01/09/09 LRS ATTEMPT TO MIT-IA TO 3000#. TUBING TRACKING W ITH IA. TROUBLE SHOOT GLM'S. 01/09/09 T/I/O = 1470/1.450/100 Temp = SI Assist Slickline pump as directed. Rigged up & PT surface line, Called off job, Final WHP's 1470/1450/100. 01/10/09 T/I/0=1280/1480/100 Assist S/L w/Tecwell LDL. Pumped 193 bbls crude down IA, taking returns up TBG to F/L, while S/L made logging passes. Freeze protected flowline with 5 bbls neat meth and 65 bbls crude. Tags hung upon departure, IA & OA valves left open to gauges. FWP's = 82/820/140. 01/10/09 RUN PDS LDL FROM 9557' SLM TO SURFACE. (DATA SHOWS STA #7 LEAKING). SET 3 1/2" WHIDDON CATCHER C~3 9583' SLM. PULL RK-DGLV FROM STA #7 Q 8915' MD. (LOWER SET OF PACKING GONE). 01/11/09 RUN POCKET BRUSH TO STA #7 Q 8915' MD. MULTIPLE ATTEMPS TO SET RK-DGLV IN STA #7 Q 8915 MD. WELL LEFT S/I, DSO NOTIFIED. 01/14/09 WELL S/I ON ARRIVAL. R/U SLICKLINE UNIT #4516. CURRENTLY STBY FOR GREASE CREW (SWAB). 01/15/09 ATTEMPT TO SET (RK) DGLV IN STA#7. RATTLE STA#7 W/ KJ, KJ, 1.50" G.RING C 8895' SLM. SET (RK) DGLV IN STA#7 C~1 8895' SLM. MIT-IA TO 3000# (GOOD). PULL EMPTY WHIDDDON CATCHER SUB FROM 9,583' SLM. PULL "P" PRONG FROM 9,604' SLM. UNABLE TO LATCH 3-1/2" PLUG BODY (SUSPECT - 2' OF FILL). WELL S/I ON DEPARTURE, DSO NOTIFIED OF ALL CONDITIONS. NOTE: 3-1/2" PLUG BODY REMAINING IN HOLE. 01/16/09 WELL SHUT IN. BAIL -2 GAL PLASTIC COATING FROM PLUG BODY FROM 9613' TO 9617' SLM. CURRENTLY RIH W/ 3-1/2" GR. Page 2 of 3 05-27A, Well History (Pre Rig Sidetrack) Date Summary 01/17/09 PULL 3-1/2" PLUG BODY C«3 9617' SLM (FULL OF PLASTIC COATING). WELL S/I ON DEPARTURE, NOTIFY DSO OF VALVE & WELL CONDITIONS. 01/21/09 MU and RIH with Baker 2.70" whipstock drift. Sat down at 11170' ctmd. Could not wash deeper. POOH. MU 2.20" DJN assy. 01/22/09 RIH with 2.20" DJN. Sat down then popped through restriction at 11172' ctmd. Continue RIH and sat down hard at 12234' ctmd, 93' shy of the top of the liner. Could not jet past this depth. POOH for motor and mill. Change out pack-off and inspect chains. MU and RIH with 2.80" parabolic speed mill. Dry tag C~3 11170' ctmd. PUH and establish free spin. Begin milling obstruction. Frequent stalls with no progress. Discuss plan forward with well engineer. POOH for taper mill. Freeze protect coil. Secure well and rig back to chnage mills. MU and RIH with a 2.80" Long-Taper junk mill. Sat down dry at 11172' ctmd. Milling on restriction at 11170' ctmd. 01/23/09 Continue milling on restriction at 11170' ctmd. Milled through restriction at 11171' ctmd. Ran dry through restriction and continued downhole. Sat down at 12231' ctmd. Milling restriction at 12231' ctmd. Unable to make any progress with mill. Discuss plan forward with town engineer. POOH for whipstock drift. Make additional reaming passes through restrictions at 11170' ctmd. OOH. MU and RIH with 2.70" Baker whipstock drift. Drift liner to 12232' ctmd. PUH 20' and flag pipe C~ 12214' ctmd (red and white). POOH for memory logging tools. OOH. MU and RIH with PDS memory STP/GR/CCL. Begin injecting KCL down backside at 2.0 bpm. 01/24/09 RIH with memory STP. Logged interval 10800' to 12216' ctmd at 60 and 80 fpm while injecting into well at 2.0 bpm. Made several stop counts spaced across 4 1/2" slotted liner. POOH. Freeze protected well to 2500' with 60/40 methanol. RD CTU. Well to remain SI. Job Complete. Note: Well was taking 8.4 ppg KCL water at approximately 1.5 bpm @ zero WHP. 02/03/09 T/I/O = VAC/1130/20. Temp = SI. Monitor WHPs, TBG, IA, OA FL. AL connected, SI C~ lateral. ALP=1900psi. TBG FL near surface, IA FL near surface, OA FL near surface. SV, WV = C. SSV,MV = O. IA, OA = OTG. NOVP. 02/04/09 T/I/O=VAC/1510/20. Temp= SI. Bleed IA & OA to 0 psi. AL connected, ALP=1980 psi, SI casing valve. Had AL casing valve serviced by grease crew, lateral valve frozen in open position, notified DSO for snow removal and install heater to thaw lateral valve. IA FL Q 102' (5 bbl). Bleed IAP from 1510 psi to 0 psi in 25 min. Bleed OAP from 20 psi to 0 psi in 10 min. Monitored for 30 min. Final WHP= VAC/0+/0+. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 02/07/09 RIH w/ 1.75" JSN. Wash tubing with 15% HCL Acid from 11650 to 11500 while pumping at 1.7bpm. Made 3 passes from 11650 to 11500. POOH. Never built any wellhead pressure. Log up from 11650' with PDS caliper tool to 10500'. Freeze protect well from 2000' with 30 bbls of 60/40 methanol. Confirmed good data. RDMO. Job complete. 02/11/09 T/I/0= 0/0/0 Pressure test master, wing, swab valves to 5000 psi for 5 minutes pre CTD (Nordic 1). ALL VALVES PASSED PRESSURE TEST. Serviced all valves with Clare 501. 02/12/09 T/I/O=SSV/0+/0+. Temp=Sl. Monitor WHPs. AL SI ®casing valve. ALP = 2000 psi. WHPs unchanged. SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. Page 3 of 3 • BP EXPLORATION Page 1 of 20 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations - _ _ ---- 2/13/2009 00:00 - 12:00 12.00 MOB N WAIT PRE Waiting on Doyon 14 rig move on spine road to move Nordic 1. 12:00 - 23:00 I 11.001 MOB I P I I PRE 2/14/2009 23:00 - 00:00 00:00 - 05:00 05:00 - 05:20 05:20 - 06:30 06:30 - 06:45 06:45 - 09:30 09:30 - 09:45 09:45 - 14:00 14:00 - 14:15 14:15 - 18:00 18:00 - 18:30 18:30 - 20:00 N P P P WAIT PRE PRE PRE PRE P P P P P P P PRE PRE PRE PRE PRE PRE PRE 20:00 - 20:15 0.25 MOB P PRE 20:15 - 21:00 0.75 MOB P PRE 21:00 - 00:00 3.00 MOB P PRE 1.00 MOB 5.00 MOB 0.33 MOB 1.17 MOB 0.25 MOB 2.75 MOB 0.25 MOB 4.25 MOB 0.25 MOB 3.75 MOB 0.50 MOB 1.50 MOB N I WAIT I PRE 2/15/2009 00:00 - 02:00 2.00 MOB P PRE 02:00 - 08:00 6.00 BOPSU P PRE 08:00 - 08:15 0.25 MOB P 08:15 - 08:30 0.25 MOB P 08:30 - 12:15 3.75 MOB P 12:15 - 12:30 0.25 MOB P 12:30 - 14:30 2.00 MOB P PRE PRE PRE PRE PRE Waiting on E pad for the wind to go down, gusting to 25 mph, unable to lower wind walls and derrick. Wind limit is 20 MPH. Nordic crew is replacing #2 fluid end while waiting. SAFETY MEETING. Held safety meeting with Security, tool service, Nordic and BP. Review rig move plan and hazard and procedures. Move rig on K pad road, to West Dock road, to Pad 10 to lay down derrick before getting on DS 05 access road. Arrive at Pad 10, wait for wind to subside so derrick can be lowered. Continue waiting at Pad 10 for the wind to lessen so derrick can be lowered. SAFETY MEETING. Wind has eased enough to lay windwalls over. PJSM to discuss hazards and mitigations. Hook up bridal lines to forklift, prep for pulling walls over. SAFETY MEETING. Crew change and PJSM for lowering windwal Is. Lower windwalls. SAFETY MEETING. PJSM for lowering derrick. Lower derrick and move Rig to DS-05. Set down rig. SAFETY MEETING. PJSM for raising derrick and windwalls. Rasie derrick, raise windwalls. SAFETY MEETING. Crew change and PJSM for setting derrick tilt cylinders into position. Hook up tugger to derrick cylinders, pull them onto supports. Unhook bridal lines. Attach long slings to block, pick up stack and secure for travel. SAFETY MEETING. PJSM for moving rig over well. Jack up rig, move it over well and set down. Accept rig at 21:00. N/U BOPs. Install catch basin around CT riser. Continue installing catch basin around CT riser. Clean up rig floor, grease tree valves, prep for BOP test. Test BOPS. Test witness waived by AOGCC official Chuck Sheive. Test 2" Combi Pipe/Slip, 2-3/8" Pipe/Slip, 2" Pipe/Slip, Blind Shears, Kill line Valves and TIW valves. Replace test joints back onto rack. Prep rig floor to pick up injector. SAFETY MEETING. Review procedure, hazards and mitigation for installing pipe straitener and guide arch on injecter and picking injecter out of pipe bay. M/U pipe straitener on injecter head. Pick injecter head from pipe bay. Secure hose bundle. Install guide arch on top of pipe straightener. Line up guide arch. SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil to injecter head. Install internal grapple and pull test. Pull coil to injecter. Stab Printed: 3/6/2009 1:44:17 PM • BP EXPLORATION Operations Summary Report Page 2 of 20 ~ Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: i Date ,From - To Hours Task Code NPT Phase Description of Operations 2/15/2009 12:30 - 14:30 2.00 MOB P PRE coil. Cut off grapple. 14:30 - 17:30 3.00 MOB P PRE Fill coil. Pump reverse circ slack management. Cut off 330' coil to reach E-Line. Cut off 30 more ft coil to find clean area for CTC. 17:30 - 18:30 1.00 CLEAN P WEXIT M/U Kendal CTC and pull test. M/U BHI UOC and test E-Line. 18:30 - 19:15 0.75 CLEAN P WEXIT Crew change, then pull BPV equipment up to rig floor. 19:15 - 19:30 0.25 CLEAN P WEXIT SAFETY MEETING. PJSM for pulling BPV. Trapped pressure and overhead loads were discussed. 19:30 - 20:20 0.83 CLEAN P WEXIT Move Tioga heater away from Tiger Tank. Pull BPV. No pressure underneath. 20:20 - 20:45 0.42 CLEAN P WEXIT Load out BPV equipment. 20:45 - 21:00 0.25 CLEAN P WEXIT SAFETY MEETING. PJSM for moving Farr tongs to stabbing box. 21:00 - 21:50 0.83 CLEAN P WEXIT Move Farr tongs to stabbing box until liner running time. Move elevators onto rack. Clear rig floor. 21:50 - 22:30 0.67 CLEAN P WEXIT Pick up injector. Install pull test plate and pull test CT connector to 35K, good. Pressure test CT connector and inner reel valve to 200 / 3500 psi, good. 22:30 - 23:50 1.33 CLEAN P WEXIT Install BHI cable head with check valves. Pressure test to 3,500 psi, good. 23:50 - 00:00 0.17 CLEAN P WEXIT M/U CT riser, bullhead biozan at 2.5 bpm, 2900 psi CT pressure, 0 psi WHP. 2/16/2009 00:00 - 01:00 1.00 CLEAN P WEXIT Continue bullheading biozan. 30 bbls away, 2.54 bpm ~ 33 psi WHP. 60 bbls away, 2.54 bpm @ 19 psi WHP. 90 bbls away, 2.52 bpm C~ 0 psi WHP. 120 bbls away, 2.52 bpm @ 0 psi WHP. 150 bbls away, 2.55 bpm C~ 0 psi WHP. At 165 bbls away, shut down pump. 01:00 - 01:15 0.25 CLEAN P WEXIT SAFETY MEETING. PJSM for pick up BHA #1. 01:15 - 02:00 0.75 CLEAN P WEXIT Break off CT riser, stand back injector. P/U BHA #1 - 2.74" parabolic speed mill and string mill, 2-1/8" BOT motor, Full 2-3/8" CoilTrak minus the HOT. Test BHA at surface. 02:00 - 04:45 2.75 CLEAN P WEXIT RIH. Stop at 730 ft, change out 2 bearing pins on injector chains. Continue RIH. 04:45 - 05:25 0.67 CLEAN P WEXIT Log GR down from 10,880 ft. Correct -11 ft. 05:25 - 05:55 0.50 CLEAN P WEXIT Go to 1.63 bpm ~ 2200 psi with no returns. Wt check at 11,130 ft is 30K. RIH to 11,650 ft at 1.75 / 0 bpm ~ 2440 psi. Nothing seen at previous trouble spot of 11,172 ft. 05:55 - 06:30 0.58 CLEAN P WEXIT Back ream up to 11450' and ream down to 11610' clean. Back ream up to 11,100'. Pull back to 11,000 for dry pass past 11,172 ft. RIH no pump. RIH clean to 11270'. No indication of trouble spot. 06:30 - 09:45 3.25 CLEAN P WEXIT POH with milling BHA. Pump 1.0 bpm, no returns. Had over pull at SSSV and determined that SSSV was TRSV. Printed: 3/6/2009 1:44:17 PM • • BP EXPLORATION Page 3 of 20 Operations Summary Report 'Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 2/16/2009 06:30 - 09:45 3.25 CLEAN P~ WEXIT Held TRSV open with 4500 psi and POH. 09:45 - 10:00 0.25 WHIP I P ~ WEXIT SAFETY MEETING. Review procedure, hazards and 10:00 - 12:00 ~ 2.001 WHIP P WEXIT 12:00-15:00 I 3.OOIWHIP IP I (WEXIT 15:00 - 15:30 0.50 WHIP P WEXIT 15:30 - 16:00 0.50 WHIP P WEXIT 16:00 - 18:40 I 2.671 WHIP I P I I WEXIT 18:40 - 18:55 0.25 WHIP P WEXIT 18:55 - 19:10 0.25 WHIP P WEXIT 19:10 - 19:20 0.17 WHIP P WEXIT 19:20 - 20:30 1.17 WHIP P WEXIT 20:30 - 22:45 I 2.251 WHIP I P I I WEXIT 22:45 - 22:55 0.17 WHIP P WEXIT 22:55 - 23:10 0.25 WHIP P WEXIT 23:10 - 23:45 0.58 WHIP P WEXIT 23:45 - 00:00 0.25 WHIP P WEXIT 2/17/2009 X00:00-01:30 ~ 1.50~WHIP ~P (WEXIT mitigation for L/O mills /motor and M/U BTT whipstock and Coiltrak BHA. Lay out 2.74" mills and motor. L/O Coiltrak. M/U BOT Gen II Whipstock and setting tools to CoilTrak tools. Enter and check TF offset. Check Coiltrak tools at surface. BHA OAL = 71.45'. RIH with BOT whipstock BHA #2 with CoilTrak tools. Open EDC, set pump kickout at 800 psi. Circ at 0.2 bpm while RIH at 80 fpm. Log GR tie-in at 10910'. -8' correction. RIH clean to setting depth. Position top of BOT Gen II Whipstock at 11,570' with a 160ROHS TF. Close EDC. Press up and set whipstock. Stack iK down, Whipstock is set. POH while pumping 1.0 bpm. Flow check at 1900'. No flow. Bullhead 80 bbl Biozan, 2.0 bpm with 550 psi WHP. Shut down pump, monitor well. WHP bleeds off slowly. Crack open choke to check returns, well is dead. POOH, pump 1 bpm through CT. SAFETY MEETING. PJSM for L/D BHA #2 and P/U BHA #3. Well control and crew positions were discussed. Tag stripper and UD whipstock setting tool. Tool has functioned normally. Remove check valves from UOC. Pick up BHA #3 -Big hole Nozzle, 1 jt 2-1/16" CSH, LOC, UOC. BHA OAL = 34.5 ft. RIH BHA #3. Tag whipstock at 11,589 ft twice, correct depth to 11,573 ft. Pull back to 10,880 ft and shut in well, circ min rate. SAFETY MEETING. PJSM for pumping cement squeeze. High pressure and high wind conditions were discussed. Hook up water lines to rig, prep for cmt job. Ready for cement. CT is at 10,880 ft. Isolate reel from rig pump. SLB pump 5 bbls fresh water ahead, then PT lines to 4,800 psi. Start cement down CT, zero In MM on density change. CT is at 10,880 ft. Start cement down CT, zero In MM on density change. Bring rate to 1.5 bpm / 2900 psi CT / 0 psi WHP. In MM CT psi WHP 10 3700 0 20 3400 0 30 3250 120 35 3200 170 Go to 1.0 bpm 40 1100 200 Cmt at nozzle 50 900 220 60 450 256 67 430 260 Go to 0.6 bpm Printed: 3/6/2009 1:44:17 PM • BP EXPLORATION Page 4 of 20 Operations Summary Report Legal Well Name: 05-27 Common Well Name: 05-27 Spud Date: 10/5/1989 Event Name: REENTER+COMPLETE Start: 2/5/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date 'From - To Hours Task Code.' 'NPT Phase. Description of Operations 2/17/2009 00:00 - 01:30 1.50 WHIP P WEXIT 70 460 0 Open choke, start lay in 1.0 bpm 1:1, lose WHP for a moment. Shut in choke, get it back. 80 1690 520 Picking up 60 ft/min 85 1900 700 Last cmt out nozzle at 10,000 ft, pull to safety. 89.5 965 520 WHP Pressure slowly bleeding off 01:30 - 02:30 1.00 WHIP P WEXIT Park at safety depth 9470 ft and squeeze with well shut in. WHP slowly bleeding off. In MM WHP 01:40 91.5 200 Squeeze 2 bbls, no WHP increase 02:00 94.0 103 Squeeze 2.5 bbls, No WHP increase. 02:20 97.0 90 02:30 - 03:30 1.00 WHIP P WEXIT Push away remaining cmt past whipstock, run down to whipstock and circulate. Pull back to 9,000 ft, wait for 2nd batch of cement. Fluid loss will be increased to 80-120 cc/30/min for 2nd batch. 03:30 - 06:30 3.00 WHIP C WEXIT Park at 9,000 ft, wait for 2nd batch of cement. Shut in well, circulate periodically. 06:30 - 08:00 1.50 WHIP C WEXIT Open up well and circ. 1.7 bpm, 1.2 bpm returns, 29% losses. RIH and tag whipstock to confirm no bridge above whipstock. Circ just above whipstock, 1.93 bpm / 1.45 bpm returns, 25% losses. Call SWS and change cement volume to 25 bbl from 50 bbl due to good returns. 08:00 - 12:00 4.00 WHIP N CEMT WEXIT Pilot test on cement done at 0830 hrs. Load out for cement job and perform thickening time test on next cement. Circ 0.5 bpm, 0.2 bpm returns. 18 bph fluid loss. Circ 1.8 bpm, 1.35 bpm returns. No cement ever seen to surface. Tag whipstock pinch point at 11562' and correct depth to 11,573'. Add 9'. 12:00 - 14:00 2.00 WHIP N CEMT WEXIT Circ. while waiting for SWS Cementers for second cement job. 0.4 bpm, 0.1 returns. 14:00 - 16:00 2.00 WHIP N CEMT WEXIT Second cement batch has poor rheology based on lab tests. Testing another cement blend will take 6+ hrs, decision is made not to pump a second cement job and pick up window mill. POOH. 16:00 - 17:20 1.33 WHIP P WEXIT PU milling BHA. 17:20 - 20:20 3.00 WHIP P WEXIT RIH. Log GR down from 11,385 ft. Correct +4 ft. RIH and tag whipstock at 11,573 ft at min rate. - 20:20 - 00:00 3.67 STWHIP P WEXIT Start time milling, 1 fUhr. 20:30 - 11572.5 ft 1.54 / 1.21 bpm @ 3480 psi DWOB = OK 21:00 - 11572.9 ft 1.54 / 1.25 bpm @ 3550 psi DWOB = 0.45K 22:00 - 11573.8 ft 1.53 / 1.31 bpm C~3 3520 psi DWOB = 0.90K 23:00 - 11574.9 ft 1.54 / 1.35 bpm C~ 3630 psi DWOB = 1.78K 00:00 - 11576.0 ft 1.54 / 1.37 bpm @ 3710 psi DWOB = Printed: 3/6/2009 1:44:17 PM TREE_ 4-1/16"CNV V~IEI.LHEAD= CMJ ACTUATOR= AXELSON KB. ELEV = 67' BF. ELEV = KOP = 2561' Max Angle = 96°@11849' Datum MD = 10321' Datum ND = 8800' SS 20 CONDUCTOR, 110' 91.5#, H-40, ID= 19.124" 13-3/8" CSG, 105' 72#, K-55 BTC, ID = 12.347" 4-1/2" TBG, 12.6#, L-80 BTGM, 3020' .0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 3700' Minimum ID =1.81" @ 10172' 3-1 /2" KB LTP SEAL ASSY 9-518" X 7" BKR HY FLO LNR HGR, ID = ? 9191' 9-518" CSG, 47#, L-80 BTGM, ID = 8.681" ~~ 9525' F BTT Deploy. Sleeve, 2.25" bore. 1 .875" min ID 10172' 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 10485' 4-112" LNR, 13.5#, L-80 FL4S, 10651' .0149 bpf, ID = 3.92" 4-1 /2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" 10899' 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: LEE TOOL GR/CCL 6 MAR-09 ANGLE AT TOP PERF: 94° a 12.010' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 12,010'-12.350' Opn 03/09/09 1.56" 6 12,430'-12,820' Opn 03/09/09 1.56" 6 13,030'-13,125' Opn 03/09/09 ITOP OF 2-3/8" LNR-CT ~~ 12327' 4-1 /2" SLTD LNR, 11.6#, L-80 FL4S, 12364' .0155 bpf, ID = 4.00" O 5 ~2 7 B SA NOTES: OIL BASED MUD - 70° @ 10337' CTD Sidetrack 4-1/2" AVA TRSV SSSV NIP, ID= 3.813" 4-1/2" X 3-1/2" XO GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3120 3096 21 MGFMHO DMY RK 16 09/13/08 2 5949 5592 29 MGFMHO DMY RK 20 09/13/08 3 7250 6734 28 MGFMHO DMY RK 0 01/01/00 4 7823 7238 31 MGFMHO DMY RK 0 10/30/96 5 8147 7501 40 MGFMHO DMY RK 0 01/01/00 6 8530 7789 43 MGFMHO DMY RK 0 01/01/00 7 8915 8076 40 MGFMHO DMY RK 0 05/28/08 C:FitMII:H L MH NL1KtLJ ST MD ND DEV TYPE VLV LATCH PORT DATE - 9632' ~ 3-1 /2" OTIS X NIP, ID = 2.813" 10166' 3-1/2" KB Liner Top Packer 10467' 4-1 /2" TNV POLISHED RISER 10477' 7" TNV SS PKR, ID = ? 10479' TMJ MILLOUT EXTENSION w / XO / SO, ID = ? 10496' 7" X 3-1/2" TM/ OVERSHOT SEAL ASSY W/1" IXT (10.75') 10920' I~ 7" ECP 11578' - I~ ~ Tag in Whipstock 11729' ~ Marker Joint--Two 10' Pup Joints w / no turbos I PBTD 13130' ~ ~ ~ ~ ~ ' B ~ ~ 2-3/8" LNR. 4.7#, Cr13. ST-L w I turbos ID = 1.995" 13267' I ESTIMATED TOP OF CEMENT I ~ 4-1 /2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" ~ I 2-318" LNR-CT, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.995" 13600' ` ` ` ~A DATE REV BY COMMENTS DATE REV BY COMMENTS 08116/84 PKR 176 ORIGINAL COMPLETION 06/02/08 ?/ PJC DRAWING CORRECTIONS 10/30/89 AUDI 4 RWO 09/10/08 KDGSV GLV CIO (05/28/08) 11/20196 NOR 1 CTD SIDETRACK (05-27A) 09/21/08 CJWSV GLV C/0 (09/13/08) 08/18/03 CMO/TLP PERF ANGLE CORRECTION 11/05/08 MSE PROPOSED CTD SIDETRACK 05/30/06 DTM WELLHEAD CORRECTION " ' " "~`" 05/29/08 PJGr KDC GLV CIO (05119/Li8i PRUDHOE BAY UNIT WELL: 05-27B PERMfT No: 208191 API No: 50-029-21979-02 SEC 32, T11 N, R15E, 2144' FSL & 1207' FWL BP Exploration (Alaska) TR.A~1/~a11 ~11°~~4L ,~ a _ -- ~. ProActive Diagnostic Services, Inc. Ta: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal fetter to the following BP Exploration (Alaska), Inc. P'etrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 4 ~`. ~~ yob. ~~ :~ ~f ~C~~~' and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907) 245-8952 ~9~0 - /03 1~55~ 1) Injection Profile 23,1an-09 05~27A 1 Color Lag / E13= 50-029-21979.01 2J --~; ~ - - ~~ ~ _~, r~ ~. Signed : Date Print Name: ,a_ , PROACTIVE DIAGNOSTIC SERVICES, INC„ 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL: ~~sancrlor~clsta~rr3es~ssr+r9csa.cam WEBSITE:~rvw~~s,raaes~a®nJlocs.co C:\Documents and Settings\Oavnec\DeslRop\T}ansmit BP.docx • • /ELL L~~' ~~ .~ ~ _ TI~,4NSM/1~1",4L ~:~,.; y .._ .. ~p, i ProAetive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907a 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe iLastufka L.R2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.8952 ~~~1~~ 1) Leak Detection - WLD 10,Jan-09 05-27A 2) 1 Color Log / EDE 50-029-21979-01 ~; Signed : ~ ~L---~ Date Print Name: tl~=~~i4 7; ib ~~~~s~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUn'E C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~tisa~eri~r~~~rrlernorvloL~ cot~i WEBSITE: wvdwv.r~'et;raa~l~~t~C.a~,~cra . R `~ i:t ZC~~ti~ .--^~.~ _- C:\Documents and Settings\Owner\Desktop\Transmit_BP.docx • • L1i/A-7~~ oaL ~ ~ 333 W. 7th AVENUE, SUITE 100 Co1~T5ERVA1'IO1~T coMAII55IO1~ ANCHORAGE, ALASKA 99501-3539 , PHONE (907) 279-1433 . John McMullen FAx (907) 276-7542 Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ;.~~;,~~?~~~, ; ~~ ' ~ t~; ~ ~4 ~~, Anchorage, AK 99519-6612 ~D~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-27A r~ ~' Sundry Number: 308-444 ~ vl Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further tame as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Commissioner DATED this "day of December, 2008 Encl. ,~ ,~ ~1~~ ALA OIL AND GAS CONSERVA ON COIV~SION ~t~ fry ~~~ ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 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 196-103 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-21979-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU OS-27A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028328 ~ 67' ~ Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13600' - 9045' - 13600' 9045' None None s'n Len h Si MD TVD B r Colla s Stru ral r 11 11 11 14 47 rf ce 70 ' 13-3/ " 37 0' 3 15' 37 0 2 In rmediate 5 5' 9- /8" 9 2 ' 85 1' 87 47 Pr i n Liner 1963' 7" 191' - 111 2 0' - 1 7020 Lin r 1 4-1/2" 1 77' - 1 4 9' 891 '- 90 4 7 0 L' 1 7' 1 T- 1 11 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted: 10899' - 13599' 9038' - 9045' 4-1/2", 12.6# x 3-1/2", 9.3# L-80 10496' Packers and SSSV Type: 7" TIW SS packer Packers and SSSV MD (ft): 10477' 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: February 1, 2009 ®Oil ~ ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. 1 hereby certify that th going is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Joh Ifen Title En ineering Team Leader Prepared By Name/Number. Signature Phone 564-4711 Dated ,$~ ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: _ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 7~`n~ p ~ ~ ~~ ~ -~-~ ~~- Subsequent Form Required: ~~~ APPROVED BY Z ~s A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 0/2006 " ~` r aa,~ ~ ' ~ . ~QO~ L Submit In Duplicate _~ ~~-io-o8 ~'~ /b • • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: December 2, 2008 Re: OS-27A Sundry Approval by Sundry approval is requested for well OS-27A. Well OS-27 was originally drilled and completed in Zone 1 with a 1250' 4-1/2" slotted liner in 1989. In November 1996, the 5-27A coiled-tubing sidetrack extension was drilled and completed in Zone 1 with a 1250' 2-3/8" slotted liner. The new 2-3/8" slotted liner top was set at the base of the 4-1/2" slotted liner. Following the sidetrack, a total of 2450' of Zone 1 was open to flow. The CTD extension increased the production rates initially and produced full-time until late 2004 when it reached marginal GOR. The well cycled poorly in 2005-2006. The poor cycle performance was partially caused by the increased water cut due to the extended SI time. In 2007, the well was POP'd and flowed for 5 months to determine if the water cut would drop and the oil rates improve enough to make the well competitive. After flowing for 5 months, the oil rate improved and the water cut dropped to 90°Io; however, the GOR remained above 50,000 scf/bbl and the well was shut-in for high GOR. REASON FOR SIDETRACK: Well OS-27A produces above marginal GOR with minimal remaining value. The proposed plan for OS-27A is to drill a through tubing sidetrack with the SLB/Nordic Coiled Tubing Drilling rig on or around May 1, 2009. The existing slotted liner will be isolated by the primary cement job after drilling the well and running liner. The sidetrack, OS-27B, will exit the existing 4.5" slotted liner and drill a 180 deg turn back to the west. 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. Report any losses in AWGRS. 5. C Set 2-3/8" CIBP in solid liner ~ 12400' 6. O AC-LDS; AC-PPPOT- T 7. O PT MV, SV, WV 8. O Bleed gas lift and production flowlines down to zero and blind flange 9. O Remove wellhouse, level pad 4. C Dummy whipstock drift (2.7" x 15') to 11650'. Circulate well to KCl at maximum rate. Pre-Rig Work: (scheduled to begin February 1, 2009) 1. S Caliper tubing as deep as possible (60 deg at 9800'). 2. S Dummy GLV's 3. O MIT-IA Rig Work: (scheduled to begin on May 1, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mi112.8" window at 11600' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 3" OH, 400' (40 deg/100 planned) 4. Drill Lateral: 3" OH, 1540' (12 deg/100 planned) ~~~~~ 5. Run 2-3/8" solid chrome liner leaving TOL at 10400' • . 6. Pump primary cement leaving TOC at 11400', 40 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (~ 1000' ) 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE= 4-1/16" CM/ WELLHEAD = - CNV ACTUATOR = AXELSON 20 CONDUCTOR, 110' KB. ELEI/ = 6T 91.5#, H-40, BF. ELEV = KOP = 2561' ID = 19.124" Max Angle = 95° @ 12511' 13-3/8" CSG, 105' Datum MD = 10321' 72#, K-55 BTC, Datum TV D = 8800' SS ID = 12.347" 4-1/2" TBG, 12.6#, L-80 BTGM, 3020' .0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 3700' Minimum ID =1.995" @ 12327' 3-1/2" G SUB 9-5/8" X 7" BKR HYFLO LNR HGR, ID = ? 9191' 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.681" 9525' O ~ -~ ~~ S NOTES: OIL BASED MUD - 70° @ 10337' ~4-1/2" AVA TRSV SSSV NIP, ID = 3.813" ~ 3020' ~4-1/2" X 3-1/2" XO i GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3120 3096 21 MGFMHO DMY RK 16 09/13/08 2 5949 5592 29 MGFMHO DMY RK 20 09/13/08 3 7250 6734 28 MGFMHO DMY RK 0 01/01/00 4 7823 7238 31 MGFMHO DMY RK 0 10/30/96 5 8147 7501 40 MGFMHO DMY RK 0 01/01/00 6 8530 7789 43 MGFMHO DMY RK 0 01/01/00 7 8915 8076 40 MGFMHO DMY RK 0 05/28/08 (:FitIVIK;AL MANUKtLS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9632' --~ 3-1/2" OTIS X NIP, ID = 2.813" 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 10485' 10467' 4-1/2" TNV POLISHED RISER 10477' 7" TNV SS PKR, ID = ? 10479' TM/ MILLOUT EXTENSION w / XO / SO, ID = ? 4-1/2" LNR, 13.5#, L-80 FL4S, 10651' -10496' 7" X 3-1/2" TM/ OVERSHOT S .0149 bpf, ID = 3.92" ASSY W/1" EXT (10.75') 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" 10899' ~ 10920' 7" ECP (34') 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" ~ 11154' , ~ ~ ' ' TOP OF 2-3/8" LNR-CT ~ 12327' ~ , 12327' 3-1/2" G SUB, ID = 1.995" 4-1/2" SLTD LNR, 11.6#, L-80 FL4S, ~ 12364' ~ ~ .0155 bpf, ID = 4.00" ? ESTIMATED TOP OF CEMENT 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" 12409' MILLOUT WINDOW (05-27A) ' PERFORATION SUMMARY REF LOG: MWD/EWR/CNO ON 10/31/89 ANGLE AT TOP PERF: 86° @ 12903' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-112" SLTD 10899-12364 S 11/05/89 2-3/8" SLTD 12903 - 13599 O 11/20/96 2-3/8" LNR, 4.6#, L-80 FL4S, 12903' .0039 bpf, ID = 1.995" 2-3/8" DRILLED LNR, 4.6#, L-80 FL4S, 13599' .0038 bpf, ID = 1.995" 2-3/8" LNR-CT, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.995" 13600' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16/84 PKR176 ORIGINAL COMPLETION 06/02/08 ?/ PJC DRAWING CORRECTIONS 10/30/89 AUD14 RWO 09/10/08 KDGSV GLV GO (05/28/08) 11/20/96 NOR 1 CTD SIDETRACK (05-27A) 09/21/08 CJN/SV GLV GO (09/13/08) 08/18/03 CMO/TLP PERF ANGLE CORRECTION 05/30/06 DTM WELLHEAD CORRECTION 05/29/08 PJG KDC GLV GO (05/19/08) PRUDHOE BAY UNIT WELL: 05-27A PERMff No: 1961030 API No: 50-029-21979-01 SEC 32, T11 N, R15E, 2144' FSL & 1207' FWL BP 6cploration (Alaska) TREE= 4-1/16"CM/ WELLHEAD = CM/ ACTUATOR = AXELSON KB. ELEV = 67' BF. ELEV = KOP = 2561' Max Angle =95° @ 12511' Datum MD = Datum ND = 10321' 8800' SS 20 CONDUCTOR 91.5#, 1+40, ID = 19.124" 13-3/8" CSG, 72#, K-55 BTC, ID = 12.347" .0152 bpf, ID = 3.958" O 5 ~2 7 B S NOTES: OIL BASED MUD - 70° @ 10337' 110, Proposed CTD Sidetrack 4-1/2" AVA TRSV SSSV NIP, ID = 3.813" 1 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" ~ 3700' Minimum ID =1.995" @ 12327' 3-1 /2" G SUB 9-5/8" X 7" BKR HY FLO LNR HGR, ID = ? 9191' 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.681" 9525 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" ~-{ 10485' 3020' H 4-1 /2" X 3-1 /2" XO GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3120 3096 21 MGFMHO DMY RK 16 09/13/08 2 5949 5592 29 MGFMHO DMY RK 20 09/13/08 3 7250 6734 28 MGFMHO DMY RK 0 01/01/00 4 7823 7238 31 MGFMHO DMY RK 0 10/30/96 5 8147 7501 40 MGFMHO DMY RK 0 01/01/00 6 8530 7789 43 MGFMHO DMY RK 0 01/01/00 7 8915 8076 40 MGFMHO DMY RK 0 05/28/08 CHEMICAL MANDRELS -i 9632' H3-1/2" OTIS X NIP, ID = 2.813" i 10400' 3-1/2" KB Liner Top Packer ID=? 4-1/2" LNR, 13.5#, L-80 FL4S, .0149 bpf, ID = 3.92" 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = PERFORATION SUMMARY REF LOG: MWD/EWR/CNO ON 10/31/89 ANGLE AT TOP PERF: 86° @ 12903' Note: Refer to Production DB for historical pert date SIZE SPF INTERVAL Opn/Sqz DATt 4-1/2" SLTD 10899 - 12364 S 11/0`. 2-3/8" SLTD 12903 - 13599 O 11 /2l TOP OF 2-3/8" LNR-CT ~~ 12327' 4-112" SLTD LNR, 11.6#, L-80 FL4S, 12364' .0155 bpf, ID = 4.00" 4-1/2" LNR, 11.6#, L-80 FL4S, .0155 bpf, ID = 4.0" i r TNV MILLOUT EXTENSION w / XO / SO, ID = ? 7" X 3-1/2" TM/ OVERSHOT SEAL ASSY W/1" EXT (10.75') 7" ECP (34') 11600' Mill Window off Mechanical 90° inc 30R trayface ' ~- B ..~_ . _ -. of u . W_. ~ ___ ' 2-3/8" 13Cr80 Liner, Cemented 8 Perf'd 13540' 12400' H2-3/8" CIPB i ? ~ ESTIMATED TOP OF CEME7VT 2-3/8" LNR-CT, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.995" 13600' ` ` ` ~A DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16/84 PKR 176 ORIGINAL COMPLETION 06/02/08 ?/ PJC DRAWING CORRECTIONS 10/30/89 AUDI 4 RWO 09/10/08 KDGSV GLV GO (05!28/08) 11120/96 NOR 1 CTD SIDETRACK (05-27A) 09/21/08 CJN/SV GLV GO (09/13/08) 08/18/03 CMO/TLP PERF ANGLE CORRECTION 11/05/08 MSE PROPOSED CTD SIDETRACK 05/30/06 DTM WELLHEAD CORRECTION 05/29/08 PJG KDC GLV GO (05/19/08) PRUDHOE BAY UNfr WELL: 05-278 PERMfT No: API No: 50-029-21979-02 SEC 32, T11N, R15E, 2144' FSL 8 1207' FWL BP Exploration (Alaska) ON OR BEFORE W C :LOi~I'~B~~v~'DOC reproducible logs for ds 05-27A ...... . Subject: reproducible logs for ds 05-27A Date: Tue, 24 Nov 1998 13:19:24 -1000 From: "Sandra D Lemke" <SLEMKE@mail.aai.arco.com> TO: howard_okland@admin.state.ak, us CC: "Richard T Owens" <DOWENSl@mail.aai.arco.com>, "Mark M McDermott" <MMCDERM@mail.aai.arco.com> Howard, Dick Owens conveyed the story on this PBU well. DS05-27A was one of the first coil tubing slim hole wells drilled out from an existing horizontal wellbore. As you can see from the approx. 1100' drillout MD, not much "new hole" was made. Anadrill delivered digital data but no reproducible logs to anyone; either AAI, Shared Services or AOGCC. This may have occurred on several of the first slim hole wells that are slated for release(1996 wells) over the next few months - call if you have questions on other early CTU jobs and I'll check them out. If you still have questions, you can call Dick Owens, PBU Geologist at 263-4982. Hope this helps out. Let me know. Sandy '"' ^'~ ~ 11/25/98 8:51 AM PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 11/05/98 RUN RECVD 96-103 96-103 96-103 SRVY CALC ~510-13600 DIR SRVY ~12510.70-13600. 8134 '~%HLUM GR 10-407 ~COMPL~.TION DAT~, /;/~0/ ~/ DAILY WELL OPS R ;~ / ~%~/~/ TO ;;/~ 0/ ~/ Are dry ditch samples required? yes ~_.~_~d received? Was the well cored? yes n~~iysis & description received? Are well tests required? ~ ~eeeived? Well is in compliance initi~al - COMMENTS 03/14/97 04/29/97 1 10/02/97 yes ..... nO .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well Oil_X Gas__ Suspended__ Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 96-103 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 !"'~-77;:,:~..- ~ ~ ,:..~ ~ 50-029-21979-01 4 Location of well at surface ~ ..... ,i: i -,, ~l~l~i 9 Unit or Lease Name 2144' FSL, 1207' FWL, Sec 32, T11N, R15E, UM.i, ~'~-'~,/ ;/~,/~,~ ~ ,,, ~ PRUDHOE BAY UNIT At Top Producing interval I~~ 10 Well Number 408' FNL, 1549' FEL, Sec 5, T10N, R15E, UM. ~' '~,'c~;i;:,i-, 5-27A At Total Depth'? .... ' ....~ 11 Field and Pool 2630' FNL, 3844' FEL, Sec 4, T10N, R15E, UM. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 67' RKB ADL 28328 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 11/13/96 11/19/96 11/20/96 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+'I-VD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 13600' MD / 9045' TVD 13600' MD / 9045' TVD YES_X NO__ 2010' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 110' 30" 2850# Poleset 13-3/8" 72# K-55/L-80 Surf 3700' 17.5" 2000 Sx CS III & 600 Sx Class G 9-5/8" 47# L-80 Surf 9825' 12.25" 375 Sx Class G 7" 29# L-80 9191' 11154' 8.5" 500 Sx Class G 4-1/2" 11.6/13.5# L-80 10477' 12409' 6" Uncemented 2-3/8" 4.6# FL4S 12327' 13600' 2.75" Uncemented 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SiZE DEPTH SET MD PACKER MD 4-1/2" Tbg 3020' 10477' 4-1/2" Slotted Liner: 3-1/2" Tbg 10485' 11154 - 12364' MD; 9058 - 9031' TVD. I 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 2-3/8" Pre-Drilled Liner: DEPTH INTERVAL MD AMT & KIND MATERIAL USED 12903- 13599' MD; 9019- 9045' TVD. 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/14/96 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 12/15/96 4 TEST PERIOD --I 2465 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 539 - 24 HOUR RATE _X 3108 7662 468 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 6/4/96 (Permit # 96-103)..~ E ~, ~ ~ ~.f li~ ~ f: 1997 41aska,Ojj.& 6as 00r~s. C0mmiss~o,' Anchora,qe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL NAME Top Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 9555' TRUE VERT DEPTH 8518' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS Summary of 5-27A Coil Tubing Wellbore Extension Drilling Operations. 321 hereby cedify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 5-27A DESCRIPTION OF WORK COMPLETED COIL TUBING DRILLED WELLBORE EXTENSION 11/10/96: MIRU CTU & PT equipment. Killed the well w/280 bbls 1% KCI Water, followed by FIo Pro mud. 11/11/96: Well went on vacuum taking mud at 30 bbls/hr. RIH w/nozzle to slotted liner top at 11154' MD & circulated two Hi Vis pills followed by an LCM pill attempting to stop lost circulation. 11/12/96: Circulated additional LCM pills to control lost circulation. Circulated & monitored mud loss rates. 11/13/96: Continued circulating while standing in hole at 10000' MD. POOH w/nozzle. RIH w/drilling BHA to tag PBTD at 12424' MD. Drilled through fill below the liner shoe to original TD at 12597' MD. POOH w/BHA. RIH w/2.8" milling BHA & milled out the 2.605" ID Packoff bushing at 12364' MD. RIH to mill shoe. 11/14196: Milled out the liner shoe at 12407' MD & backreamed OOH w/BHA. wellbore extension from 12597' to 12754' MD. POOH w/BHA. RIH w/drilling BHA & staded drilling 11/15/96: RIH w/drilling BHA & reamed open hole to bottom. Resumed drilling 2-3/4" hole to 12811' MD. w/BHA due to rise of LC to 30 bbls/hr. RIH w/nozzle & circulated a LCM pill. POOH 11/16/96: PU to 10000' MD & circulated LCM OOH; LC rate fell to 2 bbls/hr. SD circulation & squeezed LCM to 900 whp. Bled off whp & RIH to bottom w/nozzle. Jetted OOH w/nozzle w/no fluid loss. Swapped mud to clean FIo Pro. RIH w/drilling BHA & reamed hole to 12800' MD. POOH w/BHA. 11/17/96: RI H w/drilling BHA. Drilled 2-3/4" hole from 12811'to 13185' MD. POOH w/BHA. 11/18196: RIH w/drilling BHA. Reamed to bottom & drilled horizontal 2-3/4" hole to 13445' MD. 11/19/96: Drilled to TD at 13600' MD. Total mud loss to LC since RU - 700 bbls. RIH with a 2-3/8" pre-perforated liner assembly. 11/20/96: Landed liner shoe at 13600' MD, to put the pre-perforated liner interval at: 12903 - 13599' MD Circulated OOH w/BHA. MU & Released liner, displaced well to KCI Water, & POOH. FP top 2500' w/Meth Water. RDMO CTU. Placed the well on production & obtained a valid welltest. 05-27A DIRECTIONAL SURVEY API500292197901 Survey Type: SINGLE SHOT Company: SCHLUMBERGER Survey Date: 10/30/89 Survey Top: 0' MD Survey Btm: 12,511' MD Kickoff Depth: 2,276' MD Max. Dogleg: 27.8°/100' @ 12,611' MD Survey Type: MEASURED WHILE DRILLING Company: ANADRILL Survey Date: 11/19/96 Survey Top: 12,598' MD Survey Btm: 13,600' MD Avg. Angle below KOP: 49° Max. Angle: 95.20 @ 12,611' MD MD TVD SS INCLINE AZIMUTH DOGLEG ASPX ASPY 0 0.00 -67.00 0.00 0.00 0.0 698,296.5 5,948,338.2 200 200.00 133.00 0.00 258.90 0.0 698,296.5 5,948,338.2 437 437.00 370.00 0.40 168.10 0.2 698,296.7 5,948,337.4 958 957.55 890.55 1.31 194.98 0.2 698,295.8 5,948,329.8 1,453 1,452.70 1 385.70 0.99 165.36 0.1 698,295.6 5,948,320.2 1,960 1,960.21 2,144 2,143.73 2,276 2,275.66 2,371 2,370.30 2,466 2,464.87 2,561 2,558.67 2,815 2,806.29 3,010 2,992.27 3,197 3,167.34 3,387 3,340.70 1 893.21 2 076.73 2 208.66 2 303.30 2 397.87 2 491.67 2,739.29 2,925.27 3,100.34 3,273.70 3,514 3,453.46 3,386.46 3,609 3,536.39 3,469.39 3,921 3,807.85 3,740.85 4,305 4,145.69 4,078.69 4,717 4,509.38 4,442.38 1.1 5 143.60 0.1 698,300.0 5,948,312.0 0.50 178.00 0.4 698,301.2 5,948,309.7 3.00 111.40 2.2 698,304.4 5,948,308.0 5.86 138.47 3.7 698,310.1 5,948,303.6 8.49 130.80 2.9 698,318.9 5,948,295.6 11.13 124.50 3.0 14.55 128.36 1.4 18.72 136.53 2.5 22.45 136.53 2.0 26.13 131.91 2.2 28.86 131.16 2.2 30.41 131.30 1.6 28.62 132.33 0.6 27.97 131.73 0.2 28.20 132.67 0.1 698 332.0 698 378.1 698 419.7 698 466.1 698 523.7 698 568.7 698 605.0 698 722.2 698.860.4 699.007.6 5,948,286.1 5,948,253.6 5,948,216.9 5,948,170.4 5,948,117.6 5,948,079.8 5,948,049.7 5,947,95O.3 5,947,832.1 5,947,705.6 5.132 5 322 5512 5 923 6210 6493 6712 7,118 7,307 7,492 7,840 7 8,090 7 8,277 7 8,467 7 8,655 7 4,875.15 5,041.79 5,209.15 5 568.97 5 820.51 4,808.15 4,974.79 5,142.15 5,501.97 5,753.51 28.22 132.89 0.0 699,155.0 5,947,576.2 28.60 133.67 0.3 699,222.3 5,947,516.1 28.56 132.37 0.3 699,290.5 5,947,455.7 28.93 134.50 0.3 699,437.3 5,947,323.9 29.18 133.23 0.2 699,540.6 5,947,229.7 067.73 259.74 617.21 784.48 948.60 253.00 457.28 600.58 742.07 879.83 28.75 133.38 0.2 699,642.6 5,947,138.5 28.25 133.63 0.2 699,720.1 5,947,068.8 28.39 134.46 0.1 699,862.0 5,946,938.5 27.79 134.07 0.3 699,927.6 5,946,877.9 26.91 135.37 0.6 699,989.5 5,946,819.8 6,000.73 6 192.74 6 550.21 6 717.48 6 881.60 7 186.00 7 39O.28 7 533.58 7 675.O7 ? 812.83 7 955.25 8,124.97 8,256.92 8,427.38 8,505.33 31.05 138.63 1.3 700,107.4 5,946,699.4 39.01 135.63 3.3 700,207.8 5,946,597.4 41.15 135.46 1.1 700,294.5 5,946,513.5 42.50 137.93 1.1 700,383.6 5,946,423.7 43.40 138.00 0.5 700,472.0 5,946,330.8 8,845 8,022.25 39.40 137.22 2.1 700,559.0 5,946,240.3 9,069 8,191.97 41.92 139.93 1.4 700,658.2 5,946,133.5 9,254 8,323.92 47.39 144.27 3.4 700,740.8 5,946,032.7 9,515 8,494.38 51.00 141.00 1.7 700,864.7 5,945,879.1 9,645 8,572.33 55.30 142.00 3.4 700,931.6 5,945,799.5 9,741 8,625.46 8,558.46 57.75 139.66 3.3 700,984.0 5,945,738.5 Page 1 of 3 05-27A DIRECTIONAL SURVEY MD TVD SS INCLINE AZIMUTH DOGLEG ASPX ASPY 9,864 8,685.90 8,618.90 63.20 137.00 4.8 701,057.0 5,945,660.8 9,959 8,727.68 8,660.68 64.72 135.60 2.1 701,117.7 5,945,600.6 10,056 8,767.79 8,700.79 66.22 134.43 1.9 701,181.4 5,945,540.1 10,148 8,803.94 8,736.94 67.52 134.59 1.4 701 243.3 5,945,482.3 10,244 8,839.70 8,772.70 68.80 133.72 1.6 10,337 8,872.57 8,805.57 69.84 133.06 1.3 10,426 8,902.16 8,835.16 71.28 133.10 1.6 10,521 8,932.74 8,865.74 71.20 134.40 1.3 10,614 8,962.75 8,895.75 71.17 137.44 3.1 10,710 8,992.00 8,925.00 73.43 137.82 2.4 10,806 9,017.34 8,950.34 76.00 138.13 2.7 10,902 9,038.36 8,971.36 78.66 137.33 2.9 10,995 9,052.76 8,985.76 83.55 136.97 5.3 11,091 9,059.47 8,992.47 88.37 135.67 5.2 701 309.0 701 373.8 701 436.5 701 503.2 701 566.1 701 629.6 701 693.5 701 758.1 701 822.5 701,889.9 5,945,421.9 5,945,363.8 5,945,308.1 5,945,247.6 5,945,186.0 5,945,119.9 5,945,052.7 5,944,985.2 5,944,919.4 5,944,852.5 11,191 8,991.30 92.97 135.48 4.6 11,285 8,986.40 93.01 135.83 0.4 11,379 8,982.25 92.01 136.12 1.1 11,472 8,979.64 91.20 135.91 0.9 11 566 8,978.60 90.07 135.56 1.3 11 661 11 757 11 849 11 943 12 040 12134 12,228 12,322 12,417 12,511 12,598 12,611 12.639 12.671 12.701 12 732 12 760 12 805 12 835 12 865 12,895 12,925 12,955 12 985 13 022 13 055 13 086 13 121 13 161 13 191 13 221 13,251 9,058.30 9,053.40 9 049.25 9 046.64 9 045.60 9 046.10 9 047.01 9 046.54 9 044.06 9 040.69 9 038.34 9 036.99 9 034.63 9 029.36 9 021.73 9 013.82 9 012.64 9 010.54 9 008.61 9 007.28 9,007.14 9,008.39 9,012.08 9,014.56 9,016.76 9,018.85 9,020.60 9,021.93 9,023.03 9,O24.26 9,025.35 9,026.89 9,029.42 9,032.56 9,035.15 9,038.26 9,041.14 8,979.10 8,980.01 8,979.54 8 977.06 8 973.69 8 971.34 8 969.99 8.967.63 8 962.36 8 954.73 8 946.82 8 945.64 8 943.54 8 941.61 8 940.28 8 940.14 8 941.39 8,945.08 8,947.56 8,949.76 8,951.85 8,953.60 8,954.93 8,956.03 8,957.26 89.33 134.65 1.2 89.59 132.50 2.3 91.00 133.14 1.7 92.04 133.63 1.2 91.91 133.86 0.3 90.95 133.60 1.1 90.70 134.14 0.6 92.19 133.83 1.6 94.15 133.27 2.1 95.20 132.10 1.7 95.20 132.10 0.0 95.20 128.47 27.81 93.40 129.17 6.9 93.50 126.97 6.9 91.60 125.87 7.3 88.90 125.07 9.1 86.00 122.07 14.89 84.60 116.67 12.4 85.90 113.57 11.2 85.70 111.87 5.7 86.30 109.57 7.9 87.00 107.87 6.1 87.90 105.87 7.3 87.90 103.87 6.7 88.30 101.07 7.6 8,958.35 87.90 99.37 5.3 8,959.89 86.40 96.27 11.1 8,962.42 85.30 94.57 5.8 8,965.56 85.70 91.37 8.0 8,968.15 84.40 88.57 10.3 8,971.26 83.70 86.37 7.7 8,974.14 85.30 83.57 10.7 701,961.7 702,029.0 702,096.5 702,163.0 702,230.2 702,298.7 702,370.2 702,439.1 702,508.8 702,581.0 702,650.8 702,720.1 702,789.0 702,859.7 702,930.0 702 996.0 703 006.1 703 028.3 703 054.0 703 078.6 703 104.3 703 128.0 703 167.6 703 195.0 703 222.9 703 251.1 7O3 279.8 703 308.7 703 337.8 703 374.1 703 406.7 703 437.5 7O3.472.3 703.512.2 703.542.0 703.571.8 703,601.5 5,944,783.O 5,944,717.6 5,944,651.3 5,944,586.0 5,944,520.7 5,944,455.4 5,944,39O.8 5,944,330.3 5,944,267.8 5,944,202.2 5,944,138.9 5,944,O75.8 5,944,012.6 5,943,948.9 5,943,887.4 5,943,830.8 5,943,822.7 5,943,805.8 5,943,786.8 5,943,769.6 5,943,752.3 5,943,737.5 5,943,716.5 5,943,704.6 5,943,693.7 5,943,683.9 5,943,675.0 5,943,667.1 5,943,660.1 5,943,653.1 5,943,648.1 5,943,644.7 5,943,642.3 5,943,641.3 5,943,642.1 5,943,644.2 5,943,647.6 Page 2 of 3 05-27A DIRECTIONAL SURVEY MD TVD SS INCLINE AZIMUTH DOGLEG ASPX ASPY 3,281 9,043.23 8,976.23 86.70 80.07 12.5 703 631.0 5,943,652.7 3,311 9,044.56 8,977.56 88.20 78.37 7.6 703 660.2 5,943,659.0 3,351 9,045.36 8,978.36 89.50 74.87 9.3 703 698.9 5,943,669.3 13,381 9,045.44 8,978.44 90.20 73.07 6.4 703 13,411 9,045.07 8,978.07 91.20 75.87 9.9 703 13,441 9,044.36 8,977.36 91.50 77.97 7.1 703 13,471 9,043.91 8,976.91 90.20 81.57 12.8 703 13,501 9,044.12 8,977.12 89.00 83.67 8.1 703 13,531 9,044.85 8,977.85 88.20 85.67 7.2 703 !3,561 9,045.27 8,978.27 90.20 89.27 13.73 703 13,586 9,044.99 8,977.99 91.10 89.27 3.6 703 13,600 9,044.72 8,977.72 91.10 90.07 5.7 703 727.5 5,943,678.4 756.2 5,943,687.1 785.2 5,943,694.7 814.5 5,943,700.8 844.2 5,943,705.4 874.0 5,943,709.0 903.9 5,943,711.1 928.9 5,943,712.1 942.9 5,943,712.6 Page 3 of 3 PAGE ~4ADRtLL ********** SCHLUMBERGER *********~ ******.***** SURVEY PR~RAM *********** COMPANY ARCO ALASI<A INC WELL NAME 5-27A LOCATION ! PRUDHOE BAY LOCATIC~ 2 ALASEA ~A~ETIC DECLINATION 28.76 GRID CONVERG~CE ANGLE 0~00 DATE: I?-NOV-% WELL ~]MBER 27A APl: 50-029-21979-01 APE: APLI37 WELL HEAD LO,TI84: LAT(N/-S) 0,00 DEP(E/-W) 0,00 ~RT. SECT~ ORtGIN~ LAT(N/-S)-45Zi,21 DEP(E/-W) 4514.27 AZt~]~H FR~M VB~T. SECT. ORIGIN TO TARGET iS 116,16 TIE IN POINT(TIP) MEA~]RED D~'TH I~10~70 TR~E VERT D~'TH 9021.83 iNCLINATION 95.20 AZIMUTH ~t0 LATiTUDE(N/-S) -4571,2i DEPARTURE(E/-W) 4514,27 SURVEY AT 12598' INTERJECTED FROM ~IGINAL WELL FILE BY DRILEX SU~ AT i~00~ F$~OJECT~ ~ "TD' PAGE NO. ~ASURED IN?B~:VAL VERTICAL D~PTH ft ft ft 12510.70 0.0 9021,83 12598,00 87.3 12611,00 13,0 ~12,74 12639.00 28,0 9010.64 12671,00 32.0 12701,00 12732,00 12760,00 12805,00 12835,00 12865.00 12895,00 12925.00 12f55,00 12985.00 13022.00 13055,00 13086,00 13121,00 13161,00 13191,00 13221,00 13251,00 13281.00 13311,00 13351+00 13381,00 13411.00 13441.00 13471,00 1350t,00 13531,00 13561,00 13586.00 13600,00 30,0 9007.38 3i.0 9007,24 28.0 9008,49 45,0 90i2,18 30,0 30.0 9016,86 30,0 9018.95 30,0 9020,71 30.0 9022.04 30.0 90~.I4 37,0 9024,37 33,0 9025,46 31,0 9027,~ 35,0 9029°54 40.0 9032,68 30.0 9035,27 30,0 9038,38 30,0 9041,25 30.0 9043.35 ~0 9044,68 40.0 9045,48 30.0 9045.~ 30.0 9045.20 30.0 9044.49 30.0 9044.04 30.0 9044,25 30,0 9044.99 30,0 9045,40 25.0 9045.12 14.0 9044,85 ~************ ANADRILL ************** SURVEY CALCU~TIONS ********m~*** CIRCUL~R ARC ME?HOD******** V~TICAL STATION AZIMUTH LATITUDE S~CTION INCLN. N/-S ft deg deg. ft 0.00 95,20 132,10 -4571.21 83.60 95,20 132.10 -4629.50 96,15 95,20 128.47 -4637,87 123,~ 93,40 129,17 -4655.37 154,64 93.50 i26.97 -4675.06 184,13 91,60 1~,87 -4692.86 214,72 ~,90 125.07 -4710,84 242.45 86.00 122.07 -4726.31 287,21 84,60 116,67 -4748,30 317,10 85.90 113.57 -4760.98 346,97 85,70 111.87 -4772.54 376.76 86,30 109.57 -4783,13 406,45 87,00 107,87 -4792.74 436.03 87,90 105.87 -4801,44 465,43 87,90 103.87 -480~,13 501.35 88,30 101,07 -4817.11 533.06 87,~ 99.37 -4822.96 562,45 86,40 96,27 -4827.18 595,09 85,30 94,57 -4030,47 631.74 85,70 91.37 -4832.54 658,56 84,40 88,57 -4832.52 684,73 83,70 86,37 -4831,21 710.27 85,30 83,57 -4828,59 734,98 86.70 80.07 -4824,33 758.'~ 88.20 78.37 -4818.73 789,77 89.50 74,87 -~09,47 81i.99 90,20 73,07 -~01,19 834,39 91,20 75,87 -4793,i6 857,62 91,50 77.97 -4786,37 88i,76 '?0,20 81.57 -478i~04 906,77 8%00 83,67 -4777.19 932.34 88,20 85,67 -4774,41 958,65 90,20 89.27 -4773.08 980.94 91,10 89.27 -4772.76 ?~3,47 91,10 90,07 -4772,68 5-27A D~TUR£ DISPLACeMeNT at Ed-W ft ft 4514,27 6424.53 4578.78 6511.33 4508.65 6524,23 4610.41 6551.97 4635.55 6583,66 AZIMUTH deg 135,36 135.32 135,31 135.28 135.24 4659,67 ~13,27 135.20 4684,91 6643,83 135.16 4708,21 ~71,22 135,11 4747,28 6714.39 1~.01 4774,34 6742.50 134.92 DLS deg/ lOOft 0,00 0.03 27.81 6,89 6.87 7,32 9,08 14,89 12.36 11,17 4801.94 6770,21 134.82 5.69 4829.93 6797,54 134,72 7.90 4858,29 6824.47 134,61 6,12 4886.97 6851.01 134,49 7,30 4915,95 6877,08 134.37 6.66 4952,05 6908.50 134.21 4984.51 69~.87 134.06 5015,18 6960,86 133,91 5049,93 6988,~ 133,73 5089,75 7018,47 133,52 5119,63 7040,16 133,35 5149,44 7060.97 133.17 5179.18 7~0,90 132.99 5208,80 7099.70 132,81 5238.24 7117,53 132,61 5277.14 71.39,97 !32,35 5305,97 7155,75 132.14 5334,87 7171.83 131.94 5364,08 7189,07 131,74 5393,59 7207.58 131,55 5423,34 7227,32 131.38 5453,20 7247.92 131,20 5483,16 7269.62 131.04 5508,16 72~,28 130.91 5a~,16 7298,82 130.84 7,64 5.29 11,10 5.77 8.04 10.26 7.66 10.71 12,54 7.55 9.33 6,44 9,91 7.07 12,76 7,18 13.73 3.60 5,71 Anadrill November 21, 1996 Larry Grant ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Dear Mr. Grant, I am enclosing two (2) copies of the survey calculations for the well DS 5-27A. Also enclosed is a copy of the Anadrill performance letter fi-om this well.. Please let me know if you have any questions or problems. You can reach me or Bill Perry(Field Service Manager) at 349-4511. Sincerely, Chris Tzvetcoff Anadrill CM NOVEMBER 21, 1996 ARCO Alaska Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Attn: Mr. Bruce Smith Following is a summary of Anadrills' performance on DS 5-27A. SERVICES PROVIDED: Anaddll's Slim1 with Gamma Ray was picked up to drill Arco's first attempt at ddlling through 3- 1/2" tubing with the 2-3/8" BHA on 11/13/96 at a depth of 12598'. The shoe was ddlled on this run with minimal problems present. The bit run was cut short due to the jars hanging up when passing through the casing in the up direction. The 180' of open hole past the shoe was prepared for ddlling on the next bit run. The second run was started at a depth 12606' on 11/14/96 and ended on 11/15/96 at a depth of 12753'. High pump pressure was evident on this run which made ddlling a concern. The run was ended when high pump pressure readings were present when on bottom drilling. MWD run #3 was started on 11/15/96 at a depth of 12753' and ended at a depth of 12811' on 11/15/96. This run lasted only 58' due to a large fluid loss over a short period of time. MWD run ~ had Anaddll's only MWD failure due to massive shocks down hole causing the tool to reset. The shocks were registered when the BHA was reaming to bottom. The fifth run was started at 12811' on 11/17/96 and ended on 11/18/96 at a depth of 13188'. High shocks were evident on this run like on the previous runs.This run ended due to a bad bit. The last MWD run was picked up on 11/18/96 at a depth of 13188' and completed to TD at 13600' on 11/19/96. Anaddll's Slim1 with Gamma Ray tool was configured for surveys on bottom. This configuration was used on all of the runs. On the last bit run this made the D&I survey package 13.69' back from the bit and the gamma ray sensor package 21.44' back from the bit. OPERATING STATISTICS: MWD battery operating time for the well: 142.5 hours MWD footage totaled 994' accomplished in 6 MWD runs. Total pump time over the length of the well: 75 hours RECE,VED MAR 14 1997 JOB PERFORMANCE AJ~t~a 0ii & Gas Cons, Gomrr~ssior~ Anchorage DIRECTIONAL The well plan asked for a drop out of the shoe from 95.2 degress to 88.00 degress within 200' then holding it at that angle to TD. A graudual left turn from 132 deg AZ to 90 degrees AZ was also made to hit the target. Continuous TFO updates and MWD surveys were provided to the Directional Ddller throughout the well. The close proximity of the D&I package to the bit enabled the directional driller to adjust for any correction needed to hit the target. A total of 33 surveys were utilized by the directional driller. Anaddlls' final MWD survey station yielded: MEASURED DEPTH 13600.00' INC 91.1 degrees TVD 8977.7' AZM 89.8 degrees LAT -4768.05'S DEP 5522.9' E DISP 7296.3' at Azm 130.80 degrees FORMATION EVALUATION Slim1 Gamma Ray was used throughout the horozontal section to provide realtime data for corrolation. The realtime Gamma log aided the geologist in corrolating and maintaining the well bore in the target zone. The close proximity of the gamma ray package to the bit enabled the geologist to determine where the zone of interest was at all times. SHOCK ANADRILL continually measures and monitors in realtime downhole shock in excess of 25 g's on the SLIM1 Gamma Ray tool. This measurement provides an indication of adverse downhole conditions. Excessive high shocks were seen while drilling with the PDC bits, and Tandem and Single stage motors. These high shocks were seen on all of the Slim1 Gamma Ray runs on this well. ANADRILL appreciates the opportunity to help develope and support Arco Alaska in their first attempt at ddlling through 3-1/2" tubing with the 2-3~8" BH^. If you have any questions on this well or any further wells in the furture then please call Anaddll at 349-4511. Sincerely, Chris'-I'zvetcoff Cell Manager TONY KNOWLES, GOVERNOR ALA$1~ OIL ~ ~S CONSERVATION CO~M~ISS~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279~1433 FAX: (907) 276-7542 June 4, 1996 Erin Oba, Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 5-27A ARCO Alaska, Inc. 96-103 2144'FSL, 1207'FWL, Sec 32, T11N, R15E, UM 2998'FNL, 1582'FWL, Sec 04, T10N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W~,Jg. hnston Chairman BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,51ON PERMIT TO DRILL 2O AAC 25.OO5 I la. Type of Work Drill __ Redrill __ I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil Re-Entry__ Deepen XI Service _ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 67' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510~0360 ADL 28328 -~ Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2144' FSL, 1207' FWL, Sec 32, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 408' FNL, 1549' FEL, Sec 5, T10N, R15E, UM 5-27A #U-630610 At total depth 9. Approximate spud date Amount (proposed) 2998' FNL, 1582' FWL, Sec 4, T10N, R15E, UM June, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 2560 Acres 13871' MD / 9057' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A Maximum hole angle 95° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 1521' 12350 9033' 13871' 9057 Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12598 feet Plugs (measured) true vertical 9015 feet Effective depth: measured 12589 feet Junk (measured true vertical 9016 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 11 0' 2 0" 2850# Poleset I 1 0' 1 1 0' Surface 3633' 13-3/8" 2000 Sx CS 111/600 Sx Cl G 3700' Production 9458' 9-5/8" 375 Sx Cl G 9525' 8500' I'~l,..'~k..,,I. I1 I.. I.~ Liner 1963' 7" 500 Sx Cl G I I 154' 9058' Slotted Liner 1932' 4-1/2" Uncemented 12409' 9029' MAY 2 8 1996 Perforation depth: measured Slotted Liner: 11154 - 12364' true vertical Slotted Liner: 9058 - 9031' AI~E~ 011 & Gas Cons. Commission Anchorage 20. Attachments Filing fee ~x Property plat __ BOP Sketch ~x Diverter Sketch _ Drilling program x_~ Drilling fluid program__ Time vs depth plot_ Refraction analysis __ Seabed repod _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢,~,~ '~4 ' ~ Titlle Date al'- Commission Use Only ~ ~0 "l 0 ~ 5 0- 0~ '" ¢ [ q ~ ~ -- b ~. (¢'-' (~t" other requirements Conditions of approval Samples required __Y e s _~ N o Mud Icg required Y e s _~' N o Hydrogen sulfide measures ~ Y e s N o Directional survey required _~Y~-s __ N o Required working pressure for BOPE __2M; __ 3 M - ~ 5 M ' __ 1 0 M · __ I 5 M T~3500 psi for CTU Other: Original Signed By Dav'd W. J0hnst0n by order of ~,/~'_ / , Approved by Commissioner the commission DateC-,'~~,,~. -- _ . Form 10-401 Rev. 7-24-89 in triplicate DS 5-27A CT Extension and Completion Intended Procedure Object|ye: Directionally drill ~1200', 2-3/4" horizontal extension from the existing wellbore. Complete with 2-3/8" slotted liner. Intended Procedure: RU CTU/Nabors 3S. RIH and mill out shoe in 4-1/2" slotted liner. Load well with +8.9 ppg polymer mud. Directionally drill ~1200' of 2-3/4" horizontal hole to access Romeo reserves. Run 2-3/8" slotted liner to TD. RD CTD, return well to production. Anchorage May 16, 1996 DS 5-27A Proposed Wellbore Sketch Extension of Wellbore & Completion 4-1/2" AVA TRSSSV 7" Liner top 3-1/2" Otis "X" Nipple 9191' 4-1/2" Production Tubing 3-1/2" X 4-1/2" XO @ 3020' 3-1/2" Production Tubing 3-1/2" MC-FMHO GLMs 2.375" Slotted Liner 7" Liner Shoe 11,1 54' 4-1/2" Slotted Liner to 12,407' 10,496' MD TIW Overshot Seal Assy, SS Packer 2.375" TOL ~12,300' 2.75" Openhole +/-1200' 12,407' TD +/- 13,900' DS 5-27A Potential Drilling Hazards POST ON RIG The last test for H2S production was 11 ppm on 3/07/96. BHP: 3430 psi @ 8800' ss (7.5 ppg EMW), BHT 195 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/ full column of gas' 2800 psi. RECEIVED MAY 2 8 1996 Alaska 011 & Gas Cons. Commission Anchorage May 16, 1996 ~u~l doi u~d0 ~u~l doi uedo ~u~i ~8!1 Sperry Sun MV~D/ Logging TrailerI REC£1'V£D MAY 2 8 1996 Alaska Oil & Gas Cons. Anchorao~ C T Drilling Wellhead Detail Head ~ I ~ Stuffing Box (Pack-Off), 10,000 psi Worldng Pressure --- 7" Riser I Methanol Injection 7-1/16", 5M Ram Type Dual Gate BOPE ! . Cutters or Combination Cutter/Blinds Slip/Pipe rams ,,~nular BOP (Hyddl),7-1/16" ID 5,000 psi working pressure Alignment Guide Flan Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Flanged Fire Resistant Kelly Hose To Dual ~ ChokeManifold Manual VaNes Drilling spool 7-1/16", 5M by 7-1/16", 5M 0.458' (5.5") Manu~Va~e / HCR Manual Hanger 9-5/8" Annulus 13-3/8" Annulus X Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree Rrr..C lV£O Gas Cons. ~mm~ss~o~ ~cho~e 2 St-00 5/16/963:57 PM 13020.001 '87.73 97,08P 8958.50 6564.50 -4821.00 4945.60 0.10 '-10.00 10.00 5943'649.00 703367.10 13050.00 87.76 94,07 8959.70 6592.50 -482~-~9--~4975.40 0.10 -10.00 10.00 5943647.0'0 703397.10 13080.00 87.80 91,07 8960.90 6620.00 -4825.20 5005.40 0.10 -10.00 10.00 5943646.50 703427.00 -~-~-1101'00 87.85 88,07 -8962.00 6646.80 -4825.00 5035.30 0.20 -10.09-'1--(~.00 5943647.50 703457.00 13140.00 87.90 85,0~- 89631'10 6672.90 -4823.20 5065-~3--~'- 0.20, -10.00 10.00 5943650.00 703486.80 . -, . 13160.40 87.94 83,03 89631~0 6690.10 -4821.10 5085.50 --0.2© -10.00 10.00 5943652.50 703507.10 5. Stop Turn left, flop over ass, 13170.00 87.93 83,99 8964.20 6698.20 -4820.00 5095.10 ' -~).20 10.00 10.00 5943654.00 703516.60 to the right and drill at 9,98° dis 13200.~00~ 87.87 86,98 8965~'30 6724.00. -4817.7'0- 5125.00 .o.2ol 10.00 10.00 5943657.00 703546.40 91,1° TF 13230.00 87.83' 89,98 8966.50 6750.50 -4816.90 5154,90 ,0.20 10.00 10.00 5943658.50 703576,30 13260.00 87.78 92,97 "8-967.'60 6777.80 -481¥.60 5184.90 ,0.10 10.00 10.00 5943658.50 703606.30 13290.00 87.75 95,97 8968.80 6805.60 -4820.00 5214.80 ,0.10 10.00 10.00 5943657.00 703636.20 13320.00 87.72 98,97 -8970.00 6834.00 -4823.90 5244.50 ,0.10- 10.07-- lm(~.00 5943654.00 703666.00 13350.00 87.70 101,96 8971.20 6862.90 -4829.30 5274.00 ,0.'10 10.00 10.00 5943649.50 703695.60 13380.00 87.68 104,96 8972.401 6892.10 -4836.30 5303.10 -0.10 10.00 10.00 5943643.00 703724.90 13410.00 87.67 107,96 8973.60 6921.70 -4844.80 5331.90 0.00 10.00-' 10.00 5943635.50 703753.90 13440.00 87.67 -1-10,95 ~-974.80~--6951.40 -4854.80 53~0.10 ~).00 10.00 10.00 5943626,~)0 703782.40 13470.00 87.67 113,95 8976.00 6981,30 -4866.20 5387.80 0.00- 10.00-' i0.00 5943615.50 703810.40 13500.00 87.68 116,9~- .... 8'977.20 701:1.30 -4879.10 5414.90 0.00' 10.00 10.-00-5943603.50 703837.80 13530.00---87.69 119.94 8978-.40 7041.30 -4893.40 5441.20 0.10 10.00-' 10.00 5943590.00 703864.50 13560.00 _ 87.72 122,~-1---8_979.70 70'~1.10 -4909.00 5466.80 0.10 1_0.00 1~.00 -5943_5.75.00 7__0.3860.50 13590.00 87.7~-'-- 125.93 8980.80 710-0.80'-4926.00 5491.50 0.10 -- 10.00 10.00 5943558.50 75~915.70 13620.00 87.78 128,93 8982.00 7130.20 -4944.20 551-5.30 0.10- 10.001 10.00 5943541.00 703939.90 13650.00 -~87.82 -131.93 8983-.20 7159.20 -4963.60 5538.10 0.10 1-0.00 10.-~ 5943522.00 703963.30 13680.00 87.86 134.92 8984.30 7187.80 -4984.20 5559.90 0.20 10.00 10.00' 5943502.00 703985.60 --- 13710.00 87.92 137.92 8985.40 7216.00 -5005.90 5580.60 0.20 10.00 10.00 5943481.00 704006.80 - 13740.00 87.97 140.91 §986.50 7243.50 -5028.70 5600.10 0.20 10.00 10.00 5943458.50 704026.90 -~3770.00 -88.04 143.91 8'987.50 7270.40-'-5052.40 5618.40 0.20 10.00 10.00 5943435.50. 704045.80 13800.00 88.11 146.90 8988.50 7296.50 -5077.10 5635.40 0.20 10.00 10.00 5943411.00 704063.40 13830.00 88.18 149.90 8989.50 7321.90 -5102.70 5651.10 0.20 10.00 10.00 5943386.00 704079.80 13860.00 -88.26 152,89 8990.40 7346.40 -5129.00 5665.50 0.30 10.00 10.00 5943360.00 704094.90 -- 13871.00 -88.29 ~-53.99 8990.80 7355.10 -5138.80 5670.40 0.30 10.00 10.00 5943350.501 704100.106. TD!!!!!!I ---- North Rel', to True ARCO ALASKA INC. ~ --' '~- '_ -.: ·:, I~HOEBAY East/West Scale 1 Inch: 200 ft .... '~.. :~ :.,~ .--" .:..:.'- g g g o ~ g g g o ~= . oo '"" '"':' "'::'" ..' . '.... 'O'~~ summary o~~p~: ........... : .: .' :.~ . ~' '. :.']' ................. ~'~T-~F ........... :: ...... -:7'7'~':"'"'-:-"': ~-~~'-,-:~ ,,,.::. '... ~--:~ ~ .................. ~2""~ .... =.: ;. :.'... .." , ..:..:~.:......; : .: :.,.., . :......'.'. :~.,~, ; .' :.,~ ..., ."':',' Mp~eticDeclinati~n _: .................... - ~. '..' '...: .. : ' : .... ' : ~..... ..... ~ ............ ~. ~~. : .. ...... : ~ ...... :'' ...... ~.~--~----,--~ ~,-~-~ --~ -~ ....... : :': .~..... : ' .' .'., 'l.''*.:,".'~:'r: ''~. :: I~:: .~,, : ,':';" , ~.' :.~' ~'; . ~:. ~'.. '".:.' .............................. ~~ a~ --~ ~ . .... :. ~ . · ~ .... ...:. .. . ; ~ ........ . . .... . . . ~.. :. . , : · . . ............................. m~ ...... : ' : :. .... ... . .'." : ..~. ". .... ~ .~. ..... . ...'.~ . .... : ~'-~--~'~.~~"~'~ ~.~ ~94~u~,~ [~.~ ~o~qu~uu'~g' ~ -- , . ' .~ '... .~ ... : ' ...... ' : · .. , ] ' '.' . ~ . '.. ~.' .: ~.'..G : : .. :': .... ~ ~,~, ~.~'-~o~-~:~'=~ --~ -~~ ~o,~,4, ,, ,~o~~-' -6200 ~:.-:-.; .......... ~:.:--: .............. ~68~--~a'~~'--~ ~ ................. ............. ~ ~r~~ .... ' ... : :.' ]... "... . .'~. "'. ~ .':'...'..' ' ::'..'. '~T~O -~= ~' ~.~ ~0' ~' ~6:~' ~ ~;0O' --~- ~' ~ ~a~ ,. : ' , ' · ' ' ; . .~ .... :.. . ' · .: '. . r I ' ; "' ': . ' :' ' ' .... ~ ............ ~--~r~~' : . :.: . ' · ':. .: '. ' · ." ri '" ·" '":' ~'' :'''' '': '': : ' " ' ......./ ~ ............~-' ~'-- ' -6400 ~ ...: ............ :-:-:-'-.:'- .......... ::.: ........ :--.i:.~ ....... :.-i..--:::-.-..-:....LJ-:...--:-..: -.-: ..... : .... i: .......... : ........... ~:- ,..~,-*.:....--:---~ ~ ..... _ ..... : ~ · · ...[ , . .. /': . · ... . : .. . .' ..' : , .. ..:, .. ..: .i' ,= . .. ~.~ ~ . · . ] . . . . . ~ . : ~ : .: . · ...... I ..... I .... _ , ~600 ............................ :-. ~ 8800 ................................... ~.: .............. ~ .......... ~ ............ - ............ ~ ......... - .................................. : ................ : ........ - , · . 2 Di ~0o/100 Tf 180~ KOp 4 D.10/100 ~ 64t7 VS · · ~ - ~ i . . . . C ~ ~ ,, . MD 1~698 96.2~ 8~ SS 6161VS MD 12868 8~.6~ 8962 SS . ~ , ~ : ~ ' ~ . .~ ~r~ ~- ~ .' ~ :,... ~ ,~ · ~, , ...... 3 pi 10,100 Tf ~.4 8~6 SS ; ....~ .... so .890 · . MD 13871 68.~ 7365 VS ~ : ORIGINAL WELL BORE 5-27 MD 12~!0 e6.2: ee6~ sS MD 12670 88 0~ 6220 vs "'~ '~[' ........ ~ ' ' [ ' ~ ~ - . . ~, . , , . . . o 8 8 o Ve~ical Section Scale 1 inch: 200 ~ FILE NAME D~WN BY : BI~O HADEPU~O P~NE OF VERT SECTn 116.16° Reference to True No~h from Su~ace to TD o~ :~7.~ I I II 1 ST-00sum 5/16/96 3:59 PM One Minute sUmmarY'of the Well plan. ARCO 5-27 DRILL OUT SIDETRACK PREPARED FOR DAN KARA (ARCO ALASKA) VERTICAL SECTION USED ' 116.160 True North NOTE · Relative Coordinates are off ofirue North/ASP are relativeto grid North Magnetic DeclinatiOn '29.72° ' ..... , --, M-D- InC~ Dir SS DEP¥~- VS N/~S EI-W-~ BUild Turn Dogleg ASP Y ASP X Comments ft deg deg ft ft ft ft degll00 deg/100- de----~/-;100 ........ ft ft 12510.70 95.20 132,10 8954.70 6067.50 -4571,20 4514.60 0.00 0.00 0.00 5943887.50 702929.80 1. Tie in Point drill outto proj. ected TD of old well at 12598' MD 12598.00 95.20 132,10 8946.80 --6151.10 -4629.50 4579.10 0.00 0.00 0.00 5943831.00 702995,80 2. KOP 10°/100' 180° TF 12670.00 88.00 -:1-3-~,-~0 '%94---4~'80 6220.30, -4677.70 4632.50 -10.00: 0.00 10.00 5943784.00 703050.40 3. Stop Drop Turn Left at 10° --, Dogleg -9i.4° TF 12868.40 --87.64 112,25 8952.40 6416.50 -47§2.80 4799.50 -0.10' -10.00 10.00 -5943683.50 703220.10 4. Continue Turning Left at 10° -90° TF for 292' MD 13160.40 87.94 83,03 8963.90 6690.10 -4821.10- 5085.50 ~).20 -10.00 10.00 5943652.50 703507.10 5. Stop Turn left, flop over ass. ..... to the right and drill at 9.98° dis 91.1 o TF 13871.00 -88.29 153.99 8990.80 7355.10 -5138,80 5670.40 0.30 10.00 10~00 5943350.~0 704100.106. 1 St-00 5/16/96 3:57 PM ARCO 5-27 DRILL OUT SIDETRACK PREPARED FOR DAN KARA (ARCO ALASKA) VERTICAL SECTION USED · 116.16° True North RKB tt ...... ._67,1 NOTE/ [ · Relative C~)or~i~a-te--~-ar--~-~ff of true North/ASP are relative to grid North ..... Magnetic Declination ........ .29.72° MD Inc. Dir SS DEPTH VS N/-S E/.W BUild Turn Dogleg ASP Y ASP X Comments ff deg deg ff ft ft ft deg/100 deg/100 degll00 ft ft 12510.70 95.20 132,10 8954.70 6067.50 -4571.20 4514.60 0.00 -- 0.00 0.0~TM5943887.50 702929.80 1. Tie in Point drill out to proj, 12540.00 95.20 132.{0 -8952.00 6095.60 -4590.80 4536.30 0.00 0.00 0.00 5943868.50 702951.90 ected TD of old well at 12570.00 95.20 132.10 8949.30 6124.30 -4610.80 4558.50 0.00 0.00 0.00 5943849.00 702974.60 12598'MD 12598.00 95.2~ 132.10--8946.'80 6151.10 -4629.50 457'9.10 0.00 -- 0.00 -----~.00 5943831.00' 7'02995.80 2, KOP 10°/100' 180° TF -1~-600.00 95.00 '-~32,10 8946.60 6153.10 -4630.80 4580.60 -10.00 -- 0.00 10.00 5943829.50 702997.30 ~._ 12630.00 92.00 132,10 8944.~0 6181.80 -4650.90 4602.80 -10.00 0.00 10.00 594381~.~0~ 703020.00 12660.00 89.~0 132,10 8944.50 6210.70 -4671.00 4625.10 -10.00--0.00 10.00 5943790.50 703042.80 12670.00 88.00 132,10 8944.80 6220.30 -4677.70 4632.50 -10.00 0.00 10.00'-5943784.00 ' '~03050140 3. Stop Drop Turn Left at 10° 12690.00 87.95 -130.10 8945.~0 6239.60 -4690.80 4647.60 -0.20 -10.00 10.00 5943771.50 703065.80Dogleg-91.4°TF 12720.00 87.89 -127,10 8946.60 6268.90--4709.50 4671.00 -6.20-' -10.00' 1~i'00-5943753.00 703089.70 12750.00 87.83---124,10 8947.~70 6298.40 -4727.00 469'5.40 -0.20 -10.00 10.00 5943736.50 7031~-4,60 -i~)780.00 87.77 121.~-~- ' 8948,80 6328.20 -4743.10- 4720.60 -0.20 -10.00 10~00 5943721.00 703140.20 12810.00 87.72 118.09 8950~00 6358.20 -4757.90 4746.70 -0.20 -10.00 10.00 5943707.~)- 703166.60 12840.00 87.6-8 115.09 8951.20 6388.10 -4771.40 4773.50 -0.10 -10~00 10.00 5943694.00 703193.80 12868.40 87.64 112,25 8952.40 6416.50 -4782.80 4799.50 -0.10 -10.00 10.00 5943683.50 703220.10 4. Continue Turning Left at 10° -90° TF for 292' MD -12870.00 87.64 1-12.09 8952.50 6418.10 -4783.40 4801.00 0.00 -10.00 10.00 5943683.00 703221.60 12900.00 87.65 109.09 8953.70 6447.90 -4793.90 4829.00 0.00 -10.00 10.00 5943~673.00 703249.90 12930.00 87.66 106.08 8954.90 6477.50 -4803.00 4857.60 0.00 -10.00 10.00 5943665.00 703278.70 12960.00 87.67 103.08 8956.10 6506.90 -4810.50 4886.60 0.10 -10.00 10.00 5943658.00 703307.90 12990.00 87.70 100.08 8957.30 6535.90 -4816.50 4916.00 0.10 -10.00 10.00 5943652.~)0 703337.40 -- __ · WELL PERMIT CHECKLIST COMPANY (~.~ WELLNAME ,~,- c-A '-) ~ FIELD &'POOL -~ '~~. , .~2'~.~,L~ INIT CLASS '~ ~ v' - ~ - 0; \GEOL AREA ADMINISTRATION 1. Permit fee attached ....................... ~N 2. Lease number appropriate ................... (~ N 3. Unique well name and number ................. ~ N 4. Well located in a defined pool .................. ~ N 5. Well located proper distance from ddg unit boundary ..... ~} N 6. Well located proper distance from other wells ......... ~) N 7. Sufficient acreage available in drilling unit ........... ~ N 8. If deviated, is wellbore plat included .............. ~ N 9. Operator only affected party .................. ' N 10. Operator has appropriate bond in force ............ .~ N 11. Permit can be issued without conservation order ...... i.~]~ N 12. Permit can be issued without administrative approval .... N 13. Can permit be approved before 15-day walt ......... N ENGINEERING PROGRAM: exp I-1 dev I-! redfllA serv [] wellbore seg [] ann. disposal para req [] 'I ' ~ q ~ UNIT# 11 6__~"~(''') ON/OFFSHORE ~ ,, REMARKS GEOLOGY APPR DATE 15. Surface casing protects all known USDWs .......... Y 16. CMT vol adequate to circulate on conductor & surf csg .... Y 17. C MT vol adequate to tie-in long string to surf cs g ....... Y N_.// .. ~/ /.) .~ ' 18. CMT will cover all known productive hodzons .......... Y 19. Casing designs adequate for C, T, B & permafrost ...... (~ N 20. Adequate tankage or reserve pit ................ ~ N 21. Ifare-drill, hasa 10-403 for abndnmnt been approved .... --Y-N'-)U~ ~ ~ ~' ~ ~)C,'L~ ~'~ -- ~ '~~/~ 22. Adequatewellboreseparat~onproposed ............ ~ ~~~~'~-', ~/'-""-~ ~2_~/~ 23. If diverter required, is it adequate ................ /'J'~-' 24. Ddlling fluid program schematic & equip list adequate .... ~ N 25. BOPEs adequate ........................ ""(,~ N ~^ ~ 26. BOPE press rating adequate; test to _'~ ~-c~:> psig. ~' N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ,-,.,.'Y-'N"~ 28. Work will occur without operation shutdown .......... 29. is presence of H2S gas probable .............. .(_.~) N 30. Permit can be issued w/o hydrogen sulfide meas~ 31. Data presented on potential overpress~.~e-zorl~ ...... Y N 32. Seismic analysis of sh~es .... /~ {' ! ~ '_' ' _Y_ N 33. Seabed co~ (if off-shore) . _ 41,J./(~.... _Y_ N 34~ekl~ progress report~, ,.-. ..... Y N lexp~oramry on~yj GEOLOGY: HOW/~jb- A:~FORMS~cheklist rev 4/96 ENGINEERING: COMMISSJ.ON: JDH ~. JDN TAB Comments/Instructions: 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. * ALASKA COMPUTING CENTER , ****************************** . ............................ * ....... SCHLUMBERGER ....... , ............................ ****************************** COMPANY NAFJ~ : ARCO ALASKA, INC. WELL NAME '. DS 5-27A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUlVJ~ER : 50-029-21979-01 REFERENCE NO : 97422 R CEIV'ED OCT 02 199~' Oil & Gas Oo;~s. C. ororr.~i.s,.~on A~omge * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAlVlE : ARCO ALASKA, INC. WELL NAM~ : DS 5-27A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21979-01 REFEREI~CE NO : 97422 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 PAGE: **** REEL HEADER **** SERVICE NAMiE : EDIT DATE : 97/09/19 ORIGIN : FLIC REEL NAME : 97422 CONTINUATION # : PREVIOUS REEL : COb~qT : ARCO ALASKA INC., PRUDHOE BAY DS 5-27A , API #50-029-21979-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/09/19 ORIGIN : FLIC TAPE NAME : 97422 CONTINUATION # : 1 PREVIOUS TAPE : COt4FiE~T : ARCO ALASKA INC., PRUDHOE BAY DS 5-27A , API #50-029-21979-01 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 5-27A 500292197901 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 19-SEP-97 BIT RUN1 ......... 97422 TZVETCOFF BIT RUN 2 BIT RUN 3 .................. 32 lin 1SE 2144 1207 67.00 67.00 30.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2. 750 LIS Tape Verikication Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 3RD STRING PRODUCTION STRING THIS IS DATA FROM THE MWD GR RUN ON COILED TUBING. NO DEPTH SHIFTS WERE APPLIED. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUBIBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREFZENT: 0.5000 FILE SUMFLARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 12580.0 13600.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: THIS IS DATA FROM THE MWD GR LOGGED ON COILED TUBING 13 TO 19-NOV-96. NO DEPTH SHIFTS HAVE BEEN APPLIED. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. FiERGE TOP MERGE BASE .............................. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAFiE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRRWMWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 GRIN MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13600.000 GRRW. MWD -999.250 GRIN.MWD -999.250 ROP.MWD DEPT. 13500.000 GRRW.MWD 33.500 GRIN. MWD 33.500 ROP.MWD DEPT. 13000.000 GRRW.MWD 27.500 GRIN. MWD 27.500 ROP.MWD DEPT. 12580.000 GRRW. MWD 310.250 GRIN. MWD 310.250 ROP.MWD 55.100 30.800 20.300 -999.250 ** END OF DATA ** LI~S Tape Verification Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 PAGE: **** FILE TRAILER **** FILE NAIViE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NA24~ : EDIT .002 SERVICE : FLIC VERSION · OOiCO1 DATE : 97/09/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NOlViBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREFIFJF~ : 0.5000 FILE SU~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12580.0 13600.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY $ 19-NOV-96 ADVISOR 4.0C MEMORY 13600.0 12580.0 13600.0 83.7 95.2 TOOL NUMBER MWD GR LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) '. MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT ~AS~ TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE '. MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX '. MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE~IAP~S: BIT TO GR: 21.44' $ LIS FORMAT DATA 2. 750 FLO- PRO 0.000 0.000 0.000 0.0 0.0 0.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 PAGE: 6 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR RAW CPS O0 000 O0 0 2 1 1 4 68 0000000000 GR MWD AAPI O0 000 O0 0 2 1 1 4 68 0000000000 GR INT AAPI O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ROP5MWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 INT F/HR O0 000 O0 0 2 1 1 4 68 0000000000 VDEPMWD FT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13600.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT -999.250 ROP.MWD 65.900 ROPS.MWD 55.100 ROPS.INT 55.100 VDEP.MWD 9044.900 DEPT. 13500.000 GR.RAW 33.500 GR.MWD ROP.MWD 28.800 ROP5.MWD 30.800 ROP5.INT 33.500 GR.INT 33.500 30.800 VDEP.MWD 9044.201 DEPT. 13000. 000 GR.RAW ROP.MWD 20.200 ROPS.MWD 27.500 GR.MWD 20.300 ROPS.INT 27.500 GR.INT 27.500 20.300 VDEP.MWD 9023.600 DEPT. 12580.000 GR.RAW 310.300 GR.MWD 310.250 GR.INT 310.250 ROP.MWD -999.250 ROPS.MWD -999.250 ROP5.INT -999.250 VDEP.MWD 9015.500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-SEP-1997 10:03 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 97/09/19 ORIGIN : FLIC TAPE NA~E : 97422 CONTINUATION # : 1 PREVIOUS TAPE : COffk4ENT .. ARCO ALASKA INC., PRUDHOE BAY DS 5-27A ,API #50-029-21979-01 **** REEL TRAILER **** SERVICE NANZE : EDIT DATE : 97/09/19 ORIGIN : FLIC REEL NAME : 97422 CONTINUATION # : PREVIOUS REEL : COFlVZENT : ARCO ALASKA INC., PRUDHOE BAY DS 5-27A , API #50-029-21979-01
