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Home My WebLink About198-244 Image~' ,'eject Well History' File Cover I~" ~le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L(~-~,~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: ~ Diskettes, No. ~.'_~ ~~O~ [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERY~WINDY [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY _ Scanning Preparation ~ x 30 = ¢ (~ BY: BEVERLY ROBIN VINCENT SHERY~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: .~~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X~ YES ! - BY: BEVERL~INCENT SHERYL MARIA WINDY DATE~L~~/S/%'~ Stage 2 IF NO IN STAGE i, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES BY: BEVER~INCENT SHERYL MARIA WINDY DATE:~'~~..~/S/~~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDBT: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is/ Quality Checked 12110/02Rev3NOTScanned.wpd _,~ ~~~~ ~~"~ STATE OF ALASKA °'?~~ ~ ~v ALASK~L AND GAS CONSERVATION COM~SION FEB :~ ~ ~O(?~ r^~r ~, WELL COMPLETION OR RECOMPLETION REPORT AND LO~aska pit ~ Gay ~~~~ ~i;cs100 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned~ ^ Suspended zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class: ®Development~ ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband 1/24/2009 12. Permit to Drill Number 198-244 _ 308-302 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 01/01/1999 13. API Number 50-029-20296-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 01/09/1999 14. Well Name and Number: PBU 07-08A 1215 FNL, 166 FEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 1079' FSL, 984' FWL, SEC. 27, T11N, R14E, UM 8. KB (ft above MSL): 64' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1003' FSL, 2372' FWL, SEC. 27, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 8249' 7631' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 676036 y- 5949706 Zone- ASP4 10. Total Depth (MD+TVD) 10948' - 9023' - 16. Property Designation: ADL 028309 TPI: x- 677127 y_ 5952026 Zone- ASP4 Total Depth: x- 678517 y- 5951984 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes t~ No u mi le tonic and tin inf rm i n r 2 AA 2 . 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MEM CNL / GR / CCL, MWD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " H-4 rf 1 rf 11 71 Ar i " 7 7 xA i / " 47 N-80 / S00-95 urf 1 rfa 7 1' 1 -1/4" 12 sx 3-1/2" x 3-3116" / 6.2# - 0 8' 25 ' 4-1/ " 6 x LAR 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6# , 13Cr x 5-1/2", 8530' -9036' 8713' & 8903' MD TVD MD TVD 17# x 41/2", 12.6#, L-80 ~y " ~ ~ { " '1 ~~ [[ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. l '~`~~~ { $ ~ ~ - ' ~ !. ~ ~ DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 8779' Set Cement Retainer 8675' P8~A Perfs w/ 24 Bbls Cement 8270' Set EZSV 8249' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): WA Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes (~ No Sidewal l Cores Ac uired? ^ 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 ; f ~~ ,i Form 10-407 Revised 02/2007 ~ ,, CONTINUED ON t. ° t 6._. 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9149' 8405' None Shublik 9189' 8439' Sadlerochit 9278' 8513' Zone 1 B 10024' 8995' 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 fore ing is true and correct to the best of my knowledge. ~ ~~ D Signed Terrie Hubble Title Drilling Technologist Date PBU 07-08A 198-244 (307 308-302 Prepared eylVameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: E/eazar Eli vazquez, ssa-ss~s 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). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is wmpleted 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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 02/2007 Submit Original Only • • 07-08A, Well History (Pre Rig Sidetrack) Date Summary 08/20/08 WELL S/! ON ARRIVAL. ATTEMPT TO DRIFT W/ 3.805" & 3.70" CENT W/ S-BAILER. UNABLE TO PASS 1194' SLM (S-BAILER FULL OF CARAMEL COLORED,GREASY SUBSTANCE). MADE 4 RUNS W/ 3" PUMP BAILER, WORKED BAILER FROM 1199' SLM TO 1202' SLM THEN DRIFTED TO 8410' SLM. RECOVERED 9 GAL OF WHAT APPEARS TO BE FLOW-PRO/METH. DRIFTED W/ 3/70" CENT, 3.805 G-RING TO 8500' SLM W/ NO PROBLEMS(TARGET DEPTH FOR JET CUT C~1 8310' MD). LEFT WELL SI AND NOTIFIED DSO OF STATUS. 08/24/08 T/I/0= 150/O+NAC. Temp = SI. TBG and IA FL (CTD). TBG FL C~ 1188'. IA FL ~ surface. SV, WV =Closed. SSV, MV =Open. IA, OA = OTG. NOVP. 09/06/08 T/!/0= 100/20/0. Infectivity Test (Rig ST Prep). Step #1 = 1650 psi C~ 0.5 bpm. Step #2 = 1950 psi ~ 1 bpm. Step #3 = 2200 psi C«~ 1.5 bpm. Step #4 = 2350 psi C~3 2 bpm. Leak off rate was 1350 psi / 1st 5 min & 250 psi / 2nd 5 min. Caught fluid after pumping 18 bbls into the TBG. Pumped 5 bbls of neat and 95 bbls of crude during this test. Final WHP= 350/22/0. Annulus casing valves are open to gauges. Verified valve positions with DSO at permit closure. 09/14/08 WELL S/I ON ARRIVAL. DRIFTED TO 8,900' SLM W/ 3.70" CENT. & 1.75" S-BAILER (DID NOT S/D). LEFT WELL S/I NOTIFY DSO. 09/19/08 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0= 0/0/0 SET HES 4-1/2" EZ DRILL SVB SQUEEZE PACKER MID ELEMENT C~1 8780'. TOP OF PACKER C~3 8779'. WELL LEFT SHUT IN, WING CLOSED, SSV OPEN, CASING VALVES OPEN, SWAB CLOSED. DSO NOTIFIED OF VALVE POSITIONS. FINAL T/I/O=0/0/0 JOB COMPLETE. 09/25/08 T/IA/OA=S1/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre Rig side track) PPPOT-T RU 1 HP BT onto THA test void 0 pressure on void. Cycle and torque LDS "Standard" all moved free with no bent pins. Pressure void to 5000 psi for 30 minute test, 4900/ 15 minutes, 4900/ 30 minutes. Bleed THA void to 0 psi. RD test equipment re installed Alemite cap. PPPOT-IC RU 1 HP BT onto IC test void 0 psi, flushed void until clean returns achieved. Cycle and torque LDS "Standard" all moved free with no bent pins. Pressure void to 3500 psi for 30 minute test, 3500/ 15 minutes, 3450/ 30 minutes. Bleed IC void to 0 psi. RD test equipment re installed Alemite cap. '** All LDS on W/H were cycled out 1" ran in and torqued **" 10/03/08 Perform weekly BOP test. RIH with 2.50" JSN asst'. Tagged retainer at 8775' ctmd. PUH 25' and flag pipe. Circulate well with XS KCL w/ SafeLube while POOH. Winds exceeding maximum for man lift operation. Secure well. Begin Standby for Weather at 0800 hrs. 10/04/08 Ended weather standby at 1100 hrs. Unstab from well. Lay down BHA #1. MU and RIH with 2 3/8" WFD MHA and HES stinger assembly. Unable to get past 8715' (pkr). POOH to P/U two weight bars to help straighten the BHA. RBIH with modified stinger asst' (BHA #2). 10/05/08 RIH with modified BHA (retainer stinger). Tagged at 8715' ctmd. Cannot get deeper. Appear to setting down in the area of the packer at 8713' mdBK6. POOH. Add a hydraulic bow spring centralizer in place of the upper solid stabilizer. RIH with stinger BHA #4. Circulate XS KCL above retainer and establish circ pressures. Shut down and stab into retainer at 9778' ctmd. Establish injection under retainer. Saw communication with backside of coil (WHP1. Unsting and re-sting back into retainer. Same results with communication. Opened choke and confirmed returns while stung in to retainer. IAP showing only slight increase. Pump 50/50 down backside while stung into retainer. Pressured up to 3000 psi WHP after 4 bbls pumped. Shut down pump. WHP dropped 1000 psi in 5 min. Made calls, elect to proceed with cement. Pumped 24 bbls cement, squeezing 12.5 bbls under retainer at 3000 psi WHP / 2650 CTP. Bleed down WHP and unsting from retainer. Lay remainin~c 11.5 bbls cement on top of retainer while taking returns to tank. Good 1 for 1 returns. Pull to safe. RBIH contaminating cement with Biozan. Leave 100' of good cement on top of retainer. POOH chasing sweep to surface at 60%. FP well with 50/50 to 2000'. PT well to 1000 psig WHP -rock solid. Secure well. EST TOC C~3 8675'. Job Complete. Page 1 of 2 • • 07-08A, Well History (Pre Rig Sidetrack) Date Summary 10/06/08 WELL SHUT-IN ON ARRIVAL. DRIFT TO 4 1/2" EZ DRILL PKR ~ 8798' SLM W/ 3.67" CENT, (NO SAMPLE). WELL LEFT SHUT-IN. 10/16/08 ""WELL SHUT IN ON ARRIVAL. INITIAL T/I/O=0/0/0 JET CUT 4.5" TUBING AT 8530' USING 3.65" SLB POWERCUTTER. WING CLOSED, SSV OPEN, SWAB CLOSED, CASING VALVES OPEN TO GAUGES, DSO NOTIFIED. FINAL T/I/O=0/0/0 JOB COMPLETE. 10/23/08 T/I/O=0/0/0 Attempt MIT-OA to 2000~si (Rig ST Prep) Start pumping down OA. OAP dropped from i 100 psi to 520 psi while pumping C~ .7 bpm. Call PE. Continued pumping down OA. 10/23/08 TIO= 0/0/0 Temp = SI Circ well, CMIT TxIA PASSED to 3500 psi (Pre sdtrck). Spear w/ 5 bbls of meth followed by 946 bbls 1 % KCL down tbg thru cut up IA to 07-07 flowline. Rig up to IA and pumped 150 bbls of diesel down IA thru cut up tbg to 07-07 flowline. U-tube TxIA to freeze protect well. CMIT TxIA. Pumped 6.4 bbls diesel to achieve test pressure (3rd attempt). T/IA lost 20/20 psi 1st 15 mins and 20/20 2nd 15 mins. Ran test an additional 15 mins and T/IA lost 10/10 psi 3rd 15 mins for a total loss of 50/50 psi in 45 mins. Bled (-8 bbls). Freeze protect surface lines. Final WHP's = 0/0/0 Valve position at departure Wing, SWAB =Closed, SSV, Master and Annular valves all OPEN. 10/24/08 MIT-OA FAILED to 2000 psi, Established a LLR of 5 bpm C~ 1300 psi (Pre sdtrck). Pumped 80 bbls crude down OA while attempting to reach test pressure. Established LLR of 5 bpm C~ 1300 psi for 50 bbls (10 min). OAP=700 psi upon SD, had a leak off rate of 200 psi (700 psi to 500 psi) in 30 min. Bled OAP to 0 psi. OAP increased to 90 psi in 2.5 hrs. (During rig down) Bled OAP to 0 psi. OAP increased to 60 psi in 30 min. Bled OAP to 0 psi. OAP increased to 60 psi in 30 min. FWHP's=0/0/60 Tags hung. Casing valves open to gauges. 10/27/08 T/I/O =VAC/0/60. Temp = SI. Monitor WHPs. WHPs unchanged from 10/24/08. SV, WV = C SSV, MV = O IA, OA = OTG NOVP. 10/29/08 T/I/0= VACNAC/120. Temp= SI. Monitor and FLs (pre RST). OA FL @ surface. SV, WV =Closed. SSV, MV =Open. IA, OA = OTG. NOVP. 10/30/08 T/IA/OA/=VacNac/120 Temp = SI. Bleed WHP to 0 (pre RST). OA FL C~3 surface. No well house, no AL, Flow line is dropped. Bleed OAP to 0+ psi in 10 min (all fluid). SI bleed, monitor OAP for 1 hr. OAP increased 85 psi. Final WHPs = VacNac/85. SV, WV =Closed. SSV, MV =Open. IA, OA = OTG. NOVP. 11/09/08 T/I/O = ONAC/100. Temp = SI. OA FL for fullbore. OA FL C~ surface. Flowline and wellhouse has been removed. Temporary scaffolding around wellhead. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 12/20/08 T/I/O = +0/0/100 Set 5 1/8" GRAY K BPV pre riq. 01/04/09 T/I/O = NANac/90. Temp = SI. OA FL pre rig. No well house, Flow line or scaffold. Couldn't access swab or wing valves. OA FL C~ surface. SSV, MV = O. IA, OA = OTG. NOVP. 01/05/09 T/I/O=BPVNAC/90. SI. Bleed OAP to 0 psi (PRE RWO). Bled OAP from 90 psi to 0 psi in 3 minutes. Monitored 30 minutes. OAP increased 40 psi. Bled back to 0 psi in 10 seconds 3 more times with the OA increasing to 40 psi each time with a 30 minute monitor. Bled OAP to 0 psi one more time with no monitor. Final WHPs =BPVNAC/0 SV, WV = NA. SSV, MV =open. IA & OA =OTG. 01/11/09 T/I/0=N/A/5/100 Temp = SI. Load OA w/9.8 brine, Freeze protect (Rig ST Prep). Spear in to OA w/3 bbls neat meth followed by 183 bbls of 90° Inhibited 9.8 Brine. Pumped 12 bbls of 50° diesel for freeze protect. FWHP's = N/A/250/340 Notified DSO of valve positions =Swab, Wing =Shut / SSV, Master, IA, OA Open. Page 2 of 2 • BP EXPLORATION Page 1 0~ Operations Summary Report Legal Well Name: 07-08 Common Well Name: 07-08 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I .Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT Spud Date: 12/17/1978 Start: 1 /18/2009 End: 2/7/2009 Rig Release: 2/7/2009 Rig Number: 2ES Phase Description of Operations 1/18/2009 108:00 - 12:00 I 4.001 MOB I P 12:00 - 00:00 I 12.001 MOB 1 P 11 /1 s/2oo9 I oo:oo - os:oo I s.oo I Mob I P 08:00 - 15:00 7.00 RIGU P 15:00 - 16:00 1.00 WHSUR P 16:00 - 17:00 1.00 WHSUR P 17:00 - 20:30 3.50 WHSUR P 20:30 - 00:00 I 3.501 WHSUR I P 1/20/2009 100:00 - 09:30 I 9.501 BOPSUgP 09:30 - 11:00 1.50 BOPSU P 11:00 - 13:30 2.50 BOPSU P 13:30 - 15:30 2.00 PULL P 15:30 - 17:00 1.50 PULL P 19:00-00:00 ~ 5.00 PULL IP 1/21/2009 100:00 - 09:30 I 9.501 PULL 1 P 09:30 - 13:00 1.501 PULL I P 13:00 - 13:30 0.50 PULL P 13:30 - 15:30 2.00 CLEAN P 15:30 - 19:00 3.50 CLEAN P 19:00 - 00:00 I 5.00 I CLEAN I P 1/22/2009 00:00 - 03:00 3.00 CLEAN P 03:00 - 05:00 2.00 CLEAN P 05:00 - 08:30 3.50 CLEAN P 08:30 - 10:30 2.00 CLEAN P 10:30 - 12:00 1.50 DHB P 12:00 - 16:30 4.50 EVAL P 16:30 - 22:30 6.00 EVAL P 22:30 - 00:00 1.50 DHB P 1/23/2009 00:00 - 03:00 3.00 DHB P 03:00 - 04:00 ~ 1.001 DHB 1 P PRE Rig down -blow down pits and rig water system. Blow down steam lines. Bridle up. Lower cattle chute. PRE Remove derrick pins. LD derrick. Move sub off well. Begin moving to DS 7 at 20:00 hrs. PRE Moving Nabors 2ES substructure, pit module, shops, and satellite camp from DS-1 to DS-7. PRE RU Nabors 2ES. Accept riq at 15:00 hrs on 01/19/2009. DECOMP PJSM. Pre-spud meeting with all personnel. DECOMP RU DSM Lubricator. Test to 300 si. Good test. Pull BPV. DECOMP Circ out freeze protect diesel from tubing and IA with seawater until returns are clean. DECOMP Install BPV. Test from below to 1000 psi. Good test. Function all LDS. ND Xmas tree and remove from cellar. ND tubing head adapter. DECOMP NU BOPE install test dart, and test to 250 / 3500 psi. Test annular to 2500 psi. Test witness waived by AOGCC Rep Chuck Scheve. Test witnessed by WSL Dick Maskell and NAD Toolpusher Cleve Coyne. DECOMP LD BOP testing equipment. Clean and clear rig floor. DECOMP RU Lubricator and ull BPV. RD Lubricator and LD tools. DECOMP PJSM. RU to pull 4-1/2" tubing hanger and VamTop tubing. DECOMP Screw into tubing hanger, back out lock-down screws and PU to 200k. No go. Steam wellhead for 30 mins. PU to 210k. No go. Steam wellhead for 15 mins. PU to 220K and pull hanger free. PU to floor 120k. DECOMP Circulate ~ 365 gpm surface to surface. UD hanger. DECOMP POH with 4-1/2" tubin from 8530'to 6242'. Checking OA hourly for 17.0 hours. DECOMP POH & LD 4-1/2" VamTop tubing. Connections and tubulars showin severe external fitting startin at -60 'oints out of hole. 198 jts, 3 pups, 6 GLMs, 1 cut jt out. DECOMP RD casing equipment. RU to run DP. DECOMP Test lower set of BOP rams. Test witness waived by AOGCC rep Chuck Sheve. Test witnessed by WSL Bill Decker and NAD Toolpusher Cleve Coyne. Good Test. DECOMP RD BOP testing equipment. DECOMP RU to run cleanout BHA. DECOMP MU bit &cleanout BHA to 770'. Change out handling equipment for DP. DECOMP TIH with DP singles from 770' to 6322'. Checking OA hourly for 41.0 hours. DECOMP RIH with cleanout BHA to 8530'. PU - 180; SO - 160. DECOMP Dis lace well to 1 .1 LSND. Pump a dry job. DECOMP POH with cleanout BHA to 770'. DECOMP Lay down cleanout BHA. Clear rig floor. DECOMP RU SWS E-line unit. DECOMP PU & run USIT/GR/CCL to . LD tools. DECOMP PU & run 40-arm caliper log. LD tools and download data. DECOMP PJSM. PU & start running EZSV. DECOMP RIH with EZSV. Tie in with USIT log. Set top of EZSV at 8270' 3 feet above 9-5/8" collar. POH. DECOMP Pressure test casin to 3500 si. Test witnessed by WSL Travis Peltier and NAD Driller Matt Turcotte. Good test. 0 psi rnmeu: u iacwa ~ i.~o. ~a nm • BP EXPLORATION Page 2 ~'I' Operations Summary Report Legal Well Name: 07-08 Common Well Name: 07-08 Spud Date: 12/17/1978 Event Name: REENTER+COMPLETE Start: 1/18/2009 End: 2/7/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/7/2009 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To .Hours Task Code NPT Phase' Description of Operations 1/23/2009 03:00 - 04:00 1.00 DHB P DECOMP lost in 30 minutes. 04:00 - 04:30 0.50 DHB P DECOMP RD SWS. 04:30 - 09:30 5.00 WHSUR P DECOMP ND BOPE. ND wellhead at flange between casing head and tubing spool. Replace 9-5/8" pack-off. Install new tubing spool. 09:30 - 11:30 2.00 WHSUR P DECOMP Test void to 5000 psi for 30 minutes. Good test. Install secondary annulus valve on tubing spool. 11:30 - 13:30 2.00 BOPSU P DECOMP NU BOP stack on tubing spool. Test BOPs to 250/3500 psi as per permit. Good test. 13:30 - 15:00 1.50 STWHIP P WEXIT R to run whi stock BHA.- P/U MWD tools from Beaver Slide. 15:00 - 19:00 4.00 STWHIP P WEXIT MU whipstock BHA to 858'. 19:00 - 00:00 5.00 STWHIP P WEXIT RIH with whipstock BHA to 8270'. Orient whipstock to 85 de ress left of high side. PU - 180k. SO - 155k. 480 gpm ~ 2080 psi. 1/24/2009 00:00 - 00:30 0.50 STWHIP P WEXIT Slack off 20k to set anchor. PU - 192k, good set. Slack off 50k to shear whipstock mill bolt, good shear. PU - 175k. TOW - 8249'. - 00:30 - 11:00 10.50 STWHIP P WEXIT Mill window from 8249' to 8266'. Continue milling open hole to 07- O~ ~ 8288'. 11:00 - 11:30 0.50 STWHIP P WEXIT Circulate super sweep ~ 490 gpm - 2280 psi. 11:30 - 12:30 1.00 STWHIP P WEXIT LOT to EMW 12.68 ppg ~ 7665' TVD. Surface pressure - 1025 psi. Monitor well for 10 minutes. MW 10.1 ppg in and out. 12:30 - 14:00 1.50 STWHIP P WEXIT MAD Pass to 8010' ~ 300 fph, logging tool at 7950' MD. Pump a dry job. 14:00 - 17:00 3.00 STWHIP P WEXIT POH from 8010'to 836'. 17:00 - 22:00 5.00 STWHIP P WEXIT LD Drill Collars and Milling Assembly. Johnny Wack BOPE. 22:00 - 00:00 2.00 STWHIP P WEXIT Function test all rams and Hydril. Begin MU 8-1/2" drilling BHA. 1/25/2009 00:00 - 02:00 2.00 STWHIP P WEXIT Finish MU 8-1/2" drilling BHA. Perform shallow function test. 02:00 - 05:00 3.00 STWHIP P WEXIT RIH from 719' to 4155' picking up singles. 05:00 - 07:00 2.00 STWHIP P WEXIT RIH from 4155' to 8288' 07:00 - 09:30 2.50 DRILL P INT1 Drill from 8288' to 8305'. 09:30 - 10:30 1.00 DRILL N SFAL INT1 Leaking top cover of intake pod on #2 pump. Repair same. Circulate and reciprocate on #1 pump while repaving. 07:00 - 12:00 5.00 DRILL P INT1 Drill from 8305' to 8334'. PU - 175k. SO - 150k. 524 gpm ~ 2830 psi. MW - 10.1 ppg. 12:00 - 00:00 12.00 DRILL P INT1 Drill from 8334' to 9023'. PU - 180k. SO - 155k. ROT - 165. 524 gpm ~ 3320 psi. MW bumped to 10.35 ppg as some splintering was seen upon entering HRZ. 1 /26/2009 00:00 - 01:00 1.00 DRILL P INT1 Drill from 9023' to 9082'. PU - 180k. SO - 155k. ROT - 165k. TQ - 7k. 3350 psi ~ 521 gpm. MW - 10.4 ppg. 01:00 - 02:30 1.50 DRILL P INT1 CBU and take samples. Confirm TD. Circulate surface to surface sweep. Small splinters still appearing on shaker screens. Calculated ECD - 10.82 ppg. Actual ECD - 10.93 PPg. MW - 10.4 pPg• 02:30 - 03:30 1.00 DRILL P INT1 POH to 8220'. PU - 190k. No tight spots. 03:30 - 05:00 1.50 DRILL P INT1 Slip and cut drilling line. Service top drive. 05:00 - 06:00 1.00 DRILL P INT1 RIH from 8220' to 9082'. Hole slick, no obstructions. 06:00 - 07:30 1.50 DRILL P INT1 CBU 2x's ~ 521 gpm - 3100 psi. Monitor well -static. 07:30 - 11:00 3.50 DRILL P INT1 POH from 9082' to 8247' - no drag. Pump dry job and drop rabbit. POH to 4993'. 11:00 - 11:30 0.50 DRILL P INT1 Swap DP joint with washout on stand #46. f~nntea: utazuua tt:oo:tyann TREE _ ~ CIW WELLHEAD = GREY AC'iUATOR = BAKE KB. ELEV - 64' BF. ELEV= KOP = 4165' Max Angle = 91° 11321' Datum MD = 9592' Datum TVD = 8800' SS S~ NOTES: WELL ANGLE > 70° @ 9870' 0 ~ ~O ~ ~ ***C~ROME TBG*** ati7 Y D RAT 13-3/8" CSG, 72#, MN-80, BTC, ID = 12.347" ~ 2713' ~ Minimum ID = 3.725" @ 8920' HES XN NIPPLE 9-5/8" CSG, 47#, SOO-95/N-80, BTC, ID = 8.681" $24g' TOP OF WHIPSTOCK $249' 9-5/8" Ezsv 8270' 4-1/2" TBG, 12.6#, 13CR, VAM TOP, .0152 bpf, ID = 3.958" ~ 8933' TOP OF 4-1/2" LINER 8956' 7" LNR, 26#, L-80, BTGM, .0383 bpf, ID = 6.276" ~ 9082' PERFORATION SUMMARY REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 89° @ 10200' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10200-10400 O 02/07/09 2-7/8" 6 10500-11220 O 02/07/09 PBTD I--I 11238' 4-1/2" LNR, 12.6#, L-80, IBT-M, ID = 3.958" I~ 11321' 2200' H4-1/2" HES XNIP (9CR), ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3566 6939 3566 6485 1 33 MMG MMG DCR DMY RKP RKP 0 0 02/07/09 02/07/09 8094' N 9-5/8" BKR TIEBACK SLV 8105' 9-518" x 7" BKR ZXP LT PKR, ID = 6.28" 8110' 9-5l8" x 7" BKR HMC LNR HGR, ID = 6.31" 9-5/8" MILLOUT WINDOW (07-086) 8249'-8268' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09/79 ROWAN ORIGINAL COMPLETION 01/12199 D16 SIDETRACK (07-08A 08/03/07 D14 RWO 02/07/09 N7ES SIDETRACK (07-08B) 02/11/09 /SV DRLG CORRECTIONS $7$4' 4-1/2" HES X NIP (9CR), ID = 3.813" 8814' 7" x 4-1/2" BKR S-3 PKR, ID = 3.87" $$47' 4-1/2" HES XNIP (9CR), ID = 3.813" 8920' 4-1/2" HES XN NIP (9CR), ID = 3.725" 8924' 7" BKR TIEBACK SLV 8933' 4-1/2" WLEG, ID = 3.958" 8936' 7" x 5" BKR Z~' LT PKR, ID = 4.40" 8946' 7" x 5" BKR FLEX LOCK LNR HGR, ID = 4.44" 8956' 5" x 4-1/2" XO, ID = 3.96" PRUDHOE BAY UNIT WELL: 07-O8B PERMIT No: °2070190 API No: 50-029-20296-02 SEC 33, T11N, R14E, 1215' FNL & 166' FEL BP Exploration (Alaska) 01 /23/09 i~ Schlumbe~ger Alaska Data & Consulting Services a(~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 0~ , ATTN: Beth -p G~J W® oll 1 O Inh e 1 .... n___..:.-.:_ N0.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 H-35 11970840 PRODUCTION PROFILE 08/12/08 1~ vV,V~ 1 -11 12111927 IBP & CROSS-FLOW STP ~ l 11/24/08 1 1 MPS-41 11966291 SCMT - ~ 11/24/08 1 1 K-O5C AWJB-00016 MEM PROD PROFILE ~ ~5a 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE 0 -~ ~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~''- 12/30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - b ~ J 01/10/09 1 1 01-29 AP30-00011 USIT a - j 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP -~ [,~ 01/15/09 1 1 N-i8A AZCM-00005 JEWELRY LOG/PRESS/TEMP - 01/06/09 1 1 R-24 AY3J-00004 USIT 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILE/WFL .T (~'~ 01/08/09 1 1 07-OS'~A AYOO-00009 USIT - L 01/22/09 1 1 N-12 12014053 RST - 09/30/08 1 1 E-326 AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) i )Z.4! 06/15/07 1 B-27A 11999059 RST ®~~ ~ ~~ 11/07/08 1 1 12-37 40018138 _ OHM D/LWD EDIT _~C ~~-- 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT ~Q~j ~ '-' 12/24/08 2 1 H-38 OSAKA0031 OH MWD/LWD EDIT C 12/07/08 2 1 -~ ' IL ~o DI CACC Al~VGin\en ~nnc r~r n~~n~r n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 _ ,~ ~,~ Anchorage, AK 9950 ~~~N' ~ ' ATTN: Beth ~ ~ ~~~~ Received by: ~ ,,;. t, ~ . ,~ 4~ .,,. - . • L~ _ ~ ~:a ~ ~T, ~~~ • • A 7 "~ ~ ! 1 F ~ " {]~E~ 3 ~ ~~ r"h i F W ~ } T n~4 q f ~~ d A y 9E ry y fj (,mg ll iit ,4 y da..f I I ~C j~` Jj I ~ ti ~:mm~ ~ ~ A.~~ ~ ~ ~ ~PP~,-.~ ~ ~ I I ~ a ~ ~ ~ ~ yV { ~ ~ ~ ~~ ~ I 9 ~ ~ , ~~ SARAM PALIN ~ ~ ~ ~ ~ ~ µ~ ~ ~ ~ ~ ` ; 1~~ , GOVERNOR C01~5~It~,iCIOH ~ ~c~-~ 333 W 7th AVENUE, SUITE 100 is i` l~o~~l•••~~~aaaiit~~'~~iiii----777 Qi~ ANCHORAGE, ALASIC/~ 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska ~. ~, PO Box 196612 `~'`~~~~~ ~F' ~ 200$ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-08A Sundry Number: 308-302 I~g"~' Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. - f-,~ Chair DATED this day of August, 2008 Encl. „(~' ~D~ STATE OF ALASKA ~ ~ ~ (/t 1 ALA OIL AND GAS CONSERVATION COMMISSION ~~ ~ ~ ~ 200 N ,v ~f~4 ~ APPLICATION FOR SUNDRY APPROVAL Alas~a Gil & Gas Cons. Gommissiorl 20 AAC 25.280 ~..,,-,,,r.,,,,, 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 198-244 (307-051) 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20296-01-01) 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 07-08A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028309. 64' ' Prudhoe Bay Field / Prudhoe Bay Pool i2• 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): 10948 ~ 9023 ~ 9920 8949 9920 8937 Casin Len th Size MD TVD Burst Colla se Structural and r 119' 20" 119' 119' 153 520 Surface 2712' 13-3/8" 2712' 2712' 4930 2670 Intermediate 9610' 9-5l8" 9610' 8781' 6870 4760 Production Liner 1978' 3-1/2" x 3-3/16" 8968' - 10939' 8250' - 8840' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Above Pluq: 9760' - 9802' 8878' - 7868' 4-1/2" x 5-1/2" x 4-1/2" 13Cr80 / L-80 9036' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 8713' 9-5/8" x 5-1/2" Baker'SAB' packer 8903' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: October 10, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the fore~oin is true and correct to the best of my knowledge. Contact E~Qazar'e~'' Vazquez, ss4ss,6 Printed Name Greg H ~ ~` Title Engineering Team Leader ~ ~ Prepared By NamelNumber. ~t Terrie Hubble, 564-4628 Signature ~ 'r Phone 564-4191 Date ~°'~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Piug integrity ~80P Test ^ Mechanical Integrity Test ^ Location Clearance Other: '~~ eS\ `~V ~ ~C S~ \ ~`S 0.Q 'CO~flt~ S LD Q~~SE~CJ\S ~~ - ®~ ~ ~ Q \ Subsequent Form Required: 1 APPROVED BY Q~ ,/ Z ~ J A roved B : COMMISSIONER THE COMMISSION Date Form 1.0-403 R ve s~6/2006 Submit In Duplicate s.w. 5 ~:~ ~~P ~ ~~ 2DD~ by GP 07-08A • Well Type: Producer Current Status: This well is completed with 4-1/2" 13Cr tubing and is currently shut-in. Request: In preparation for the proposed 07-08B rotary sidetrack, approval is requested for the P&A of PBU 07-08A perforations. Furthermore, I would like to draw your attention to the fact that we have a previously approved application for Sundry Approval (Approval Number 307-051). This work was originally planned to be conducted by CTD but due to the fact that CTD could not get into the 3-1/2" liner top to reach the desired KOP due to junk left by the workover rig, a rotary sidetrack is our only option. The plan to P&A this well has been modified accordingly. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPS when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Scope of Work: Cut and pull the existing 4-1/2" completion f/--8310' MD, set an cement retainer at 8780' MD and P/A the existing perforations (9760' - 9802' MD) in preparation for setting a 9-5/8" whipstock on an EZSV bridge plug at 8284' MD for the proposed 07-08B rotary sidetrack (an Ivishak Zone 1 B producer). MASP: 2389 psi Estimated Start Date: October 10th, 2008 Pre-riq prep work: S 1 RU, drift for cement retainer. F 2 Fluid ack the tubin and inner annulus w/seawater/diesel. F 3 Conduct In'ectivit Test down tubin for P & A cement desi n. E 4 Set a cement retainer inside the 4-1/2" tubing at 8,780' MD. Cement retainer is desired to be laced in the middle of the first full 4-1/2" ~oint above the XN Ni le. C 5 P&A the perforations thru the cement retainer. Squeeze ~10 bbls of cement into perfs and fill the tubing from 9,920' MD up to 8,780' MD. Unsting and lay 100' of cement (~1.5 bbls) on top of retainer. a. 15.8 ppg class G cement calculations: i. 4-1/2" tubing above cement retainer = 100' x 0.1521 = 1.52 bbls ii. 4-1/2" tubing = 8843' - 8780.4', 63.4' x 0.01521 = 0.965 bbls iii. 5-1/2" tubin = 8914.7' - 8843.4', 71.25' x 0.0232 = 1.66 bbls • n iv. 4-1/2" tubing = 8961' - 8914.7', 46.3' x 0.01521 = 0.705 bbls v. 4-1/2" tbg x 3-1/2" = 8998' - 8961', 37' x 0.0033 = 0.123 bbls vi. 4-1/2" tbg x 3-3/16" = 9024' - 8998', 26' x 0.0053 = 0.139 bbls vii. 3-1/2" liner = 8998' - 8961', 37' x 0.0087 = 0.322 bbls viii. 3-3/16' liner = 9920' - 8998', 922' x 0.0076 = 7.01 bbls ix. Cement squeezed into perfs = 10 bbls Total with 0.6 bbls excess = 23 bbls S 6 RU, drift for Jet Cutter E 7 Jet cut the 4-1/2" tubin in the middle of a full ~oint at 8310' MD. F 8 Circulate the well to sea water and freeze rotect with diesel to 2,200' MD. F 9 CMIT - T x IA to 3,000 psi for 30 minutes. MIT - OA to 2,000 psi for 30 minutes (previous test failed 3/13/07 and conduct an in'ectivit test to obtain a LLR. D 10 Bleed all casin and annulus ressures to zero si. W 11 Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT - IC and PPPOT - T. W 12 Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well re aration cost on the handover form. Proposed Procedure: 1. MI / RU Doyon rig 14. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Set BPV using a T-bar and test from below to 1,000 psi for 10 minutes. 4. Nipple down tree. Install a test dart in the top of the BPV so the plug can hold pressure from above. Nipple up and test BOPE to 3,500 psi. Pull test dart and BPV. 5. RU and pull the 4-1/2", 12.6#, 13Cr Vam Top tubing from the pre-rig jet cut at 8310' MD. Test the lower set of pipe rams. 6. RU E-line. MU 8-1/2" GR/JB & GR/CCL. RIH and tag tubing stump at 8310' MD to confirm access to run an EZSV bridge plug. If gauge ring /junk basket indicates a scraper run is needed, PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to 8280' MD. POOH. 7. With E-line, seta 9-5/8" EZSV bridge plug at 8284' MD to allow fora 8260' MD whipstock KOP. 8. Pressure-test the 9-5/8" casing to 3,500 psi for 30 charted minutes. 9. Bleed 9-5/8" annulus pressure. 10. ND BOPE and set back. 11. ND and remove the tubing spool. Y~`f7 12. Pull existing pack-off. Install Gray Gen 2 to New Standard Conversion pack-off. ~~ 13. Install new tubing spool and test to 5,000 psi or as recommended by Cameron Rep. 14. NU and test BOP. fj'~ 15. P/U and RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly on 4" drill pipe. Orient whipstock per Schlumberger Rep and set on EZSV bridge plug. Shear off the whipstock. 16. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to _ be inning the milling operations. i i. mm wmaow m y-5ia~~ casing at ± ts,~tiu~mu, pws approximately ~u~ neyona miaaie or winaow. Circulate well bore clean. 18. Pull up into 9 5/8" casing and conduct an LOT. POOH. 19. M/U 8-'h" GR/RES/MWD assembly. RIH, kick off and drill the 8Yz" intermediate section with 10.1 ppg LSND drilling fluid. 20. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the well clean, short trip to THRZ or higher as needed. POOH. 21. Change out to 7" rams, and test. 22. MU and run 980' of 7", 26#, L-80, BTC-M liner to bottom on drill pipe. Circulate and condition the hole. • ~ 23. Cement the entire 7" liner through the 8-1/2" hole and back 150' into the 9-5/8" casing at 8,110' MD. Set the hanger and packer, displace cement with mud. 24. Circulate bottoms up, POOH, UD liner running tool (LRT). 25. M/U the first 6-%8' Dir/GR/Res assembly with a roller cone bit and RIH. Wash down to the cement plug in the 7" liner. 26. Test the liner to 3,500 psi for 30 charted minutes. 27. Drill out of cement and float equipment to shoe. 28. Displace to 8.4 ppg Flo Pro Fluid. 29. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT. Drill the 6- 1/8" production interval as per directional plan to end of the build section. 30. POOH for PDC bit. 31. POOH, PU second 6-1/8" Neu/Den/GR/Res BHA with PDC. 32. RIH, MAD pass build section in "UP" direction. Drill ahead to TD. 33. POOH. UD BHA. 34. Run and fully cement 2,180' of 4-1/2", 12.6#, L-80 solid liner. This will include 150' liner lap inside the 7" drilling liner. Cement the liner. A pert pill will be left in the 4-1/2" liner. 35. Set liner top packer and displace well to clean seawater above the liner top. 36. POOH, UD LRT. 37. Pressure test casing and liner to 3,500 psi for 30 minutes. 38. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset. 39. R/U and run a 4~/2", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-1/2" liner tie back sleeve. 40. Space out and make up tubing hanger per Cameron Rep. 41. Land the tubing hanger, and run in lock down screws. 42. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 43. Set a BPV. 44. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 45. Freeze protect the well to --2,200' TVD. Secure the well. 46. RD and Move Off. Drilling Engineer: Eli Vazquez (907) 564-5918 Production Engineer: Alice Kaminski (907) 564-5676 Geologist: Doug Stoner (907) 564-5652 ATTACH: Current Schematic Proposed Pre-rig Schematic Proposed Schematic TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR= AXELSON KB. ELEV = 64' BF. ELEV = KOP= 4165' DRLG DRAFT Max Angle = 96 @ 10444' Datum MD = 9736' Datum TVD = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" H 2712' Minimum ID = 2.80" @ 8998' TOP OF 3-3/16" LNR 4 1/2" 12.6 #/ft 13Cr VamTop 8843' ~TOPOF4-1/2"TBG ~ 8915' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.95" 8915' TOP OF 3-1 /2" LNR I-I 8965' 3-1 /2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" TOP OF 3-3116" LNR TOP OF CEMENT 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, N-80, ID = 8.681" PERFORATION SUMMARY REF LOG: MEM CNL ON 02/04/99 A NGLE AT TOP PERF: 59 @ 9760' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/4" 6 9760 - 9779 O 07/20!03 2-1 /4" 6 9782 - 9802 O 05/31 /03 2" 4 10299 - 10576 C 02/05/99 2" 4 10768 - 10907 C 02/05/99 07-08A • ~'~"~~ ~ 2090' 4-1/2" X-NIP ID=3.813 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3329 3328 1 410SS DMY RK 0 08/01/07 4 4783 4733 29 410SS DMY RK 0 08/01/07 3 2 1 6323 7528 8644 5982 6994 7971 36 28 31 410SS 410SS 410SS DMY DMY DCR RK RK RK 0 0 0 08/01/07 08/01/07 08/01/07 8683' ~ 4-1/2" X-NIP ID=3.813 8713' 9 5/8" X 4-1/2" BAKER S-3 Cr PKR 8748' 4-1 /2" X-NIP ID=3.813 $$21' 4-1/2" XN-NIP (MILLED 12/5/07), ID=3.80" 8843' 9-5/8" x 4-1/2" UMI Chrome Overshot 8853' S-1/2" BAKER SBR ASSY, ID = 4.875" 8903' 9-5/8" X 5-1 /2" BAKER SAB PKR ID = 4.223" 8915' 5-1/2" X 4-1/2" XO 8937' SLM JUNK FROM 8/2007 RWO (TAGGED 09/29/07) 8961' 3-3/4" X 3" BAKER DEPLOY SLV, ID = 3.000" 8975' 4-1/2" BAKER NIP, ID = 3.759" BEHIND 3-1/2" LNR) 8998' I~ 3-112" X 3-3/16" XO, ID = 2.992" I 8998' I 9035' I~ 4-1/2" SHEAR OUT SUB, ID = 4.125" I (BEHIND 3-3/16" LNR), MILLOUT WINDOW - 9610' - 9620' 9920' CIBP SET 05/31/03 10903' PBTD -BAKER LANDING COLLAR, ID = 2.992" 10937' BAKER FLOAT SHOE 9024' 9036' 9610' TD I-1 10948' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09179 ORIGINAL COMPLETION 08/02/07 SV DRLG CORRECTIONS 01/12199 SIDETRACK (07-08A) 09/29/07 RCT/TLH JUNK FROM RWO 05/15/01 RWTP CORRECTIONS 12/19/07 NORDIC1 MILLED XN NIP (12/5/07) 05/31/03 SRB/TLP CLOSE/NEW PERFS, CIBP 07/20/03 SRB/TLH ADD PERFS 08/03/07 D14 RWO PRUDHOE BAY UNrf WELL: 07-08A PERMfT' No: 1982440 API No: 50-029-20296-01 SEC 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL BP Exploration (Alaska) it TREE = GRAY GEN 2 WELLHEAD = . . GRAY .~~. ~ ACTUATOR = AXE]..SON KB. ELEV = 64'j BF. ELEV = KOP = 4165'; Max Angle = 96 @ 10444' Datum MD = 9736'; Datum TVD = 8800' SS' 07-08A ~ PRE-RIG 13-318" CSG, 72#, N-80, ID = 12.347" H 2712' Minimum ID = 2.80" @ 8998' TOP OF 3-3/16" LN R Pre-rig tubirg et cut 8310' Expected Top of Cement 8680' Cement Rataina- 8780' 4 1/2" 12.6 #/ft 13Cr VamTop 8843' TOP OF 4-1 /2" TBG ~ 8915' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.95" 8915' OF 3-1/2" LNR ~-~ 8965' 3-1 /2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" ~--~ 8998, TOP OF 3-3/16" LNR 8998' TOP OF CE7v1ENT 9024' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9036' 9-5/8" CSG, 47#, N-80, ID = 8.681" 9610' PERFORATION SUMMARY REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 59 @ 9760' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/4" 6 9760 - 9779 O 07/20/03 2-1/4" 6 9782 - 9802 O 05/31/03 2" 4 10299 - 10576 C 02/05/99 2" 4 10768 - 10907 C 02/05/99 r r . ,I •• .„ ii. SAFETYf~i6: 2090' 4-1/2" X-NIP ID=3.813 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3329 3328 1 410SS DMY RK 0 08/01/07 4 4783 4733 29 410SS DMY RK 0 08/01/07 3 6323 5982 36 410SS DMY RK 0 08/01/07 2 7528 6994 28 410SS DMY RK 0 08/01/07 1 8644 7971 31 410SS DCR RK 0 08/01/07 8683' -1 4-1/2" X-NIP ID=3.813 8713' 9 5/8" X 4-1/2" BAKER S-3 Cr PKR 8748' 4-1/2"X-NIP ID=3.813 8821' 4-1/2" XN-NIP (MILLED 12!5/07), ID=3.80" 8843' 9-5/8" x 4-1/2" UMI Chrome Overshot 8853' S-1/2" BAKER SBRASSY, ID = 4.875" 8903' 9-5/8" X 5-1/2" BAKER SAB PKR, ID = 4.223" 8915' 5-112" X 4-1/2" XO i37' SLM JUNK FROM 8/2007 RWO (TAGGm 09/29/07) 8961' 3-3/4" X 3" BAKER DEPLOY SLV, ID = 3.000" 8975' 4-1/2" BAKER NIP, ID = 3.759" (BEHIND 3-1/2" LNR) 8998' ~~ 3-1/2" X 3-3/16" XO, ID = 2.992" 9035' ~ 4-1/2" SHEAR OUT SUB, ID = 4.125" I (BEHIND 3-3/16" LNR), MILLOUT WINDOW - 9610' - 9620' 9920' CIBP SET 05/31/03 10903' PBTD -BAKER LANDING COLLAR, ID = 2.992" 10937' BAKER FLOAT SHOE ~ ~ I-~ 10948' ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" 10937' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09/79 ORIGINAL COMPLETION 08/02/07 SV DRLG CORRECTIONS 01/12/99 SIDETRACK (07-08A) 09/29!07 RCT/TLH JUNK FROM RWO 05/15/01 RWTP CORRECTIONS 12/19/07 NORDIC1 MILLED XN NIP (12/5/07) 05/31/03 SRB/TLP CLOSE/NEW PERFS, CIBP 08/12/07 EV Proposed Pre-rig 07/20/03 SRBlTLH ADD PERFS 08/03/07 D14 RWO PRUDHOE BAY UNff WELL: 07-08A PERMrf No: 1982440 API No: 50-029-20296-01 SEC 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL BP Exploration (Alaska) TREE= 4-1/16 5K Gray WELLHEAD =Grey New Std: ACTUATOR = KB. ELEV = 55.5'( BF. ELEV = KOP= 8260'] Max Angle = 90 @ 9955'] Datum MD = 9736'1: Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" o7-oss PROPOSED S~AFE~YNOiPS: 2100' 4-1/2" X-NIP ID=3.813 GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DATE 8110' -1 T' LNR Top Packer (BOT HCM/ZXP) 8260' KOP/Top 9-5/8" Window 9 5/8" EZSV Bridge Plug Pre-Rig Jet Cut Expected Top of Cement 9 5/8" X 4-112" BAKER S-3 Cr PKR Cement Retainer 8284' 8310' 8680' 8713' 8~8~ °~' .. ,; , '• .~ ~./ 9-518" CSG, 47#, N-80, ID = 8.681 " ~-~ 9610' PERFORATION SUMMARY REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 59 @ 9760' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE CIBP SET 05/31 /031 9920' 11124' ~-~4.5", 12.6#, 13Cr-80, VamTop, Liner I ~' ~ TD 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" 10937' I 10948' I DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09179 ORIGINAL COMPLETION 08/02/07 SV DRLG CORRECTIONS 01/12/99 SIDETRACK 07-08A 09/29/07 RCT/TLH JUNK FROMRWO 05115/01 RN/TP CORRECTIONS 12119/07 NORDICI MILLED XN NIP 1215/07 05131/03 SRBlTLP CLOSEINEW PERFS, CIBP 05113/OS EV 07-08B PROPOSED SIDETRACK 07120/03 SRB/TLH ADD PERFS 08103/07 014 RWO PRUDHOE BAY UNIT WELL: 07-08A PERMfT No: 1982440 API No: 50-029-20296-01 N, R14E, 2905.82' FEL & 427° BP Exploration (Alaska) 4.5", 12.6#, 13-CR, VAM TOP, TBG. Fuly Cemented Liner 15.8 ppg Bass G \ 8830' 4.5" HES X Landing Nipple ID=3.813" 8870' 7" x 4-1/2" Baker S-3 Packer $900' 4.5" HES X Landing Nipple ID=3.813" 8930' 4.5" HES XN Landing Nipple ID=3.75" 8940' 4.5" LNR Top Packer (BOT HCM2XF 9088' T', 26/f, L-80, BTGM, Liner c oraae 1. Operations Performed: o Abandon o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 198-244 .,.. 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20296-01-00.... 7. KB Elevation (ft): 64' 9. Well Name and Number: PBU 07 -08A - 8. Property Designation: 10. Field / Pool(s): ADL 028309 Prudhoe Bay Field / Prudhoe Bay Pool - 11. Present well condition summary Total depth: measured 1 0948 / feet true vertical 9023 / feet Plugs (measured) 9920 Effective depth: measured 9920 feet Junk (measured) None true vertical 8949 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 119' 20" 119' 119' 1530 520 Surface 2712' 13-3/8" 2712' 2712' 4930 2670 Intermediate 9610' 9-5/8" 9610' 8781' 6870 4760 Production Liner 1978' 3-1/2" x 3-3/16" 8968' - 10946' 8250' - 9022' 10160 10530 Perforation Depth MD (ft): 9760' - 10907' SCANNED AUG 2 82007 Perforation Depth TVD (ft): 8878' - 9017' 4-1/2", 12.6# x 5-1/2", 17# x 4-1/2", 13Cr80 / L-80 9036' Tubing Size (size, grade, and measured depth): 1? n# Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer; 8713' 9-518" x 5-1/2" Baker 'SAB' packer;' .....' .."~" 8903' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from -8605'. Mill down collapsed tubing. Cut and pull tubing again from -8847'. Run new completion with overshot to 8853'. 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Te¡rie Hubble Title Technical Assistant /1() .. , ~ 4. giln f:B7Z2/c. Prepared By Name/Number: êignature I f'AIV Q ~ Phone 564-4628 Date 07Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 "RBDMSSflAUG >-"7 Submit Original Only í ~ I \L..\.Jt:1 V t:U . STATE OF ALASKA _ J:':¡;:¡;f~ AU ALA~OILAND GAS CONSERVATION COM~ION M/;}-,-\ G 2 2 2007 REPORT OF SUNDRY WELL OPERATIONS Alaska O~ & Gas Cons. Commission An h ORIGINAl .2 lDD7 TREE =. GRA Y GEN 2 . I I WELLHEAD = GRAY 07 -08A SAFETYOOŒS: A CTUA TOR = AXEL80l\ KB. ELEV = 64 BF ELEV = ~ nk%1 (~ nRA I - --I 2090' H 4-1/2" X-NIP ID=3.813 I · _., ~_.__. u ~. GAS LIFT MANDRELS Datum.MD=.... ...... 8T MD ND DEV TYÆ VLV LATCH PORT DATE Datum ND = -- 5 3329 3328 1 41088 DMY RK 0 08/01/07 µ LJ ~ 4 4783 4733 29 410SS OMY RK 0 08/01/07 13-3/8" CSG, 72#, N-80, ID = 12.347" 2712' 3 6323 5982 36 410SS OMY RK 0 08/01107 2 7528 6994 28 410SS OMY RK 0 08/01/07 1 8644 7971 31 410SS OCR RK 0 08/01/07 Minimum ID = 2.80" @ 8998' 1__ ---L 8683' -1 4-1/2" X-NIP ID=3.813 I :::;¡a: I 8713' -1 95/8" X 4-1/2" BAKER S-3 Cr PKR I TOP OF 3-3/16" LNR _ ....2:5 I · 8748' -1 4-1/2" X-NIP ID=3.813 I I · -1 I I 41/2" 12.6 #/ft 13Cr VamTop I 8843' J--~ , 8821' 4-1/2" XN-NIP ID=3725 I 8843' -1 9-5/8" x 4-1/2" UMI Chrome Overshot I "'" ---i 8853' -1 5-1/2" BAKER SBR A8SY, 10 = 4875" I I 8903' -19-5/8" X 5-1/2" BAKER SAB PKR, ID = 4.223" I TOPOF 4-1/2" TBG I 8915' I -1 , I 8915' 5-1/2" X 4-1/2" XO I I 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.95" I 8915' ~...... I 8961' -13-3/4" X 3" BAKER DEPLOY SLY, ID = 3.000" I I TOP OF 3-1/2" LNR I 8965' I r--- 8975' 4-1/2" BAKER NIP, ID = 3759" II (BEHIND 3-1/2" LNR) I 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I 8998' I 8998' -1 3-1/2" X 3-3/16" XO, ID = 2992" I I TOP OF 3-3/16" LNR I 8998' -¡.--~ ITOPOF CEMENT H 9024' ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9036' [ 9035' 4-1/2" SHEAR OUT SUB, ID=4.125" I I (BEHIND 3-3/16" LNR), I 9-5/8" CSG, 47#, N-80, ID = 8.681" H 9610' ~ I MILLOUTWINDOW - 9610' - 9620' I PERFORA TION SUMMARY 9920' H CIBP SET 05/31/03 I REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP ÆRF: 59 @ 9760' 10903' PBTD - BA KER LA NDING I Note: Refer to Production DB for historical perf data COLLAR. ID = 2.992" SIZE 8PF INTERVAL Opn/Sqz DATE 2-1/4" 6 9760 - 9779 0 07/20/03 r 10937' BAKER FLOAT SHOE I 2-1/4" 6 9782 9802 0 05/31/03 A ~ 2" 4 10299 - 10576 C 02/05/99 ~~ 2" 4 10768 - 10907 C 02/05/99 I TDH 10948' I 3-3/16" LNR, 6.2#, L-80 .0076 bpf, ID = 2.80" H 10937' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 01/09/79 ORIGINAL COM PLETION 12/21/06 OOB/PAC CORRECT 9-5/8" CSG DEPTH WELL: 07-08A 01/12/99 SIDETRACK (07 -08A) 08/02/07 SV DRLG CORRECTIONS ÆRMIT No: J"1982440 05/15/01 RN/TP CORRECTIONS API No: 50-029-20296-01 05/31/03 SRB/TLP CLOSE/NEW ÆRFS, CIBP SEe 33, T11 N, R14E, 2905.82' FEL & 4275.96' FNL 07/20/03 SRB/TLH ADD ÆRFS 09/10/03 CMO/TLP ÆRF ANGLE CORRECTION BP Exploration (Alaska) Digital Well File . . Page 1 of 1 Well: 07-08 Well Events for SurfaceWell - 07-08 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS3 -> 07 -> 07-08 Date Range: 01/Ju1!2007 to 22/Ju1!2007 Data Source(s): AWGRS Events Source Well Date AWGB5 07-08A 07/22/2007 AWGRS 07-08A 07/21/2007 AWGRS 07-08A 07/21/2007 Description T/I/O=VAC/VAC/VAC. Temp=SI. Bleed WHP's to 0 psi. (Pre-RWO). Well on VAC no bleed needed. SET BPV / PRE RIG Continued from 7-20-07 OA brine load (Rig prep) - Bleed TxIA to 0 psi, Load OA W/ 298 bbls 9.8 Brine, 7 bbls diesel. Freeze protect F.L. W/ 6 bbls meth, 70 bbls crude, 20 bbls Diesel. FWHP= 10/10/340 AWGRS 07-08A 07/20/2007 T/I/O=O/O/O Circ Out (Pre-RWO) - Spear in tbg w/5 bbls neat methanol, 1086 bbls 2% kcl. taking returns up the IA to casasco loop to production. Pumped 148 bbls diesel down IA taking returns up tbg to Fl., Start U-Tube Job continued on 7-21-07 AWGRS 07-08A 07/19/2007 INITIAL WHP: 0/0/0/ RIH WITH 4.15" POWER CUTTER, MAX 00=4.15", WEIGHT=175 LBS, LENGTH=13.6 FT JET CUT 5-1/2" TUBING IN MIDDLF OF FIRST JOINT AROVF rOil AP~Fn pIN (cù APPROX 8661 FT. THERMAL NEUTRON LOG USED AS CORRELATION AND DATED 19 FEB 1999. TUBING CUT IN THE MIDDLE OF FIRST JOINT AT 8600 FT. FINAL T/IA/OA = 0/0/0. ***JOB COMPLETED*** AWJ;jF..S 07-08A 07/18/2007 INITIAL WHP: 0/0/0/ RIH WITH 4.15" POWER CUTTER, MAX 00=4.15", WEIGHT=175 LBS, LENGTH=13.6 FT JET CUT 5-1/2" TUBING IN MIDDLE OF FIRST JOINT ABOVE COLLAPSED TBG @ 8600ft. THERMAL NEUTRON LOG USED AS CORRELATION AND DATED 19 FEB 1999. TUBING CUT IN THE MIDDLE OF FIRST JOINT AT 8600 FT. ***JOB CONTINUED NEXT DAY*** AWGRS 07-08A 07/01/2007 T/IA/OA= 0/0/0 Temp SI PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T (PASS) RU high pressure bleed tool onto THA test void 0 pressure on void. Cycle and torque LDS "Standard" all moved free with no bent pins. Pressure void to 5000 psi for 30 minute test, 4900/ 15 minutes, 4900/ 30 minutes. Bleed THA void to 0 psi. RD test equipment re installed Alemite cap. PPPOT-IC (PASS) RU high pressure bleed tool onto IC test void 0 psi, flushed void until clean returns achieved. Cycle and torque LOS "Standard" all moved free with no bent pins. Pressure void to 3000 psi for 30 minute test, 2900/ 15 minutes, 2850/ 30 minutes. Bleed IC void to 0 psi. RD test equipment re installed Alemite cap. http:// di gital weUfile. bpweb. bp .comfW el1E vents/Home/Default. asp x 8/22/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -08 07-08 WORKOVER DOYON DRilLING INC. DOYON 16 Start: Rig Release: Rig Number: 7/20/2007 8/1/2007 Spud Date: 12/17/1978 End: 712312007 102'30 - 09,00 6.50 MOB P PRE Rig released on OS 5-15B RWO @ 02:30. Prep Rig for move to OS 7-08. Moved rig off well, stage in center of Pad, remove BOPE stack, RID rig floor, UD Derrick, install booster wheels. 09:00 - 18:00 9.00 MOB P IPRE Wait on Field crew to finish setting matting boards on access Rd. 18:00 - 19:30 1.50 MOB P PRE Wait on Security to Crew Change and arrive on location. 19:30 - 20:30 1.00 MOB P PRE 24 hour notice given to AOGCC (Chuck Scheve) regarding upcoming BOPE testing on OS 7-08. Move rig down OS 5 Access road to end of Rig Mats. 20:30 - 21 :00 0.50 MOB P PRE Wait to have Rig Mats moved to front of Rig. 21 :00 - 00:00 3.00 MOB P PRE Continue to move rig up west dock rd. to OS 7. 7/24/2007 00:00 - 06:00 6.00 MOB P PRE Moving rig across OX Bow rd enroute to OS 7-08 06:00 - 16:00 10.00 RIGU P PRE MIRU on OS 7-08. Layout Herculite, spot and center Rig over well. Raise Derrick. DSM installed additional valve on OA and also R/U Herculite Berm, separate circulation manifold, and Tiger Tank. Connect DSM circulation manifold to OA and IA and to Tiger Tank. Take on hot seawater to Pits. Accept Rig at 1200-hours. Install Halliburton 1502 valve immediately upstream of Tiger Tank inlet valve. Test lines between tree and DSM manifold between DSM manifold and Tiger Tank to 4,000-psi. 16:00 - 18:30 2.50 KILL P DECOMP Hold PJSM for Well Kill circulation with Veco truck drivers, MI engineer, Rig Crew, Tool Pusher and WSL. Discuss the addition of the Tiger Tank to handle wellbore fluids. Recheck manifold valve alignments and ensure correct connections are utilized for the Tiger Tank. DSM pull BPV with Lubricator. T/lNOA pressures are 01010. Get ready to start circulation and Wells Superintendent asks to hold a meeting with all the crew I to introduce Paul Everest and Jerry Sweeney, BP, to discuss I the three Top Drive incidents experienced by Doyon 16 as well as the gas release incident on Nordic 1. Allow Rig Crew to take dinner before starting Well Kill circulation. 18:30 - 21 :30 3.00 KILL P DECOMP PJSM Circulate out Diesel Freeze Protection, Pumped 20 bbl Safe Surf-O pill, followed by 20 bbl Hi-Vis Sweep. Displaced well to 8.6 ppg 120 deg Sea Water at 5 bpm with 380 psi. Pumped 10 bbls to catch fluid. 21 :30 - 22:00 0.50 KILL DECOMP Open up the tubing and IIA to check for flow. Well Bore dead. 22:00 - 22:30 0.50 KILL DECOMP BID Lines in Cellar and drain Production Tree. 22:30 - 23:00 0.50 KILL DECOMP R/U DSM Lubricator to set BPV, UD DSM Lubricator. 123:00 - 00:00 1.00 KILL DECOMP R/U and Test BPV to 1,000 psi for 10 minutes. 7/25/2007 00:00 - 00:30 0.50 BOPSU DECOMP ¡Test BPV from below to 1,000 psi for 10 charted minutes. Held 1000-psi solid. B/D lines. 00:30 - 01 :00 0.50 BOPSU DECOMP Bleed off Control lines and install Blank Flanges. 01 :00 - 02:30 1.50 BOPSU DECOMP N/D Production Tree and Adapter Flange. 02:30 - 03:00 0.50 BOPSU DECOMP Install Test Dart 03:00 - 05:00 2.00 BOPSU DECOMP N/U BOPs and Flow line. 05:00 - 06:30 1.50 BOPSU DECOMP R/U to test BOPE, AOGCC witness was waived by Chuck Scheve. 06:30 - 11 :30 5.00 DECOMP Test BOPE to 250-psi low, 3,500-psi high. All tests recorded on chart. 11 :30 - 12:30 1.00 PULL P DECOMP RID BOPE test equipment. R/U Schlumberger Camco spooling unit 12:30 - 13:30 1.00 PULL P DECOMP PJSM for pulling test dart and BPV. Check IA and OA Printed: 8/14/2007 4:23:24 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-08 07 -08 WORKOVER DOYON DRilLING INC. DOYON 16 Start: Rig Release: Rig Number: 7/20/2007 8/1/2007 Spud Date: 12/17/1978 End: pressures, both O-psi. Line up to pump seawater into IA. Took 0.5-Bbls to fill. Hold PJSM with DSM and rig crew to discuss use of lubricator extension and dry rod to pull test dart. Check IA and OA pressures and find O/O-psi. 13:30 - 14:00 0.50 PULL P DECOMP Pull test dart with dry rod. IA/OA = OIO-psi. Install lubricator on , top of extension and hydraulically RIH with pulling tool, engage BPV and pull from hanger. Tubing on very slight vacuum. 14:00 - 15:00 1.00 PULL P DECOMP PJSM for PIU MIU Baker 4-1/32" 00 Spear and pulling Hanger. PIU and M/U double spear to single joint of 4" DP. Back out lock down screws. Cameron Tech reported that the bleeder was slightly spitting, then sucking indicating a slight u-tubing in fluid level, tubing by IA. Engage spear in Hanger and work up to 165K, slack off and work up to 165K; repeat cycle 3-times and hanger pulls free at 165K-lbs. Pull Hanger to floor with 165K. Connect sash cord to 1/4" SS lines and tie off to tugger. Cut lines and one of the lines slips downhole through the top clamp. The clamp is a three-strap clamp that applied no clamping tension to the SS lines. Call town engineer and report same. 15:00 - 15:30 0.50 PULL P DECOMP PJSM to BIO and UD Baker spear and hanger. 15:30 - 16:00 0.50 PULL P DECOMP Backoff Baker spear from hanger. Use power tongs to break hanger pup from string. Install 5-3/4" RH Acme x 4-1/2" IF XO with lifting cap into Hanger to prevent hanger from turning turtle when it's backed out UD hanger. Breakout and UD spear. 16:00 - 17:00 1.00 PULL P DECOMP Service Drawworks, Top Drive, and Pipe Skate. 17:00 - 18:00 I 1.00 PULL P DECOMP POH and UD tubing and spool-up SS control line. Circulate Bottoms up before POH and UD tubing. Used 3-1/2-Bbls to tag fluid, but most of the volume is between Pump #1 and the tubing string. Got full returns to the Pits. 18:00 - 21 :30 3.50 PULL P DECOMP POH and UD tubing. Spool up control line. Recovered 24 control line clamps, several just hanging on when pulled to rig floor. 21 :30 - 22:00 0.50 PULL P DECOMP RID control line spooling unit 22:00 - 00:00 2.00 PULL P DECOMP Continue to POOH f/6,450' to 4,500'. 7/26/2007 00:00 - 04:30 4.50 PULL P DECOMP Continue to pull and lay down 5.5" completion. Recover 1-SSSV, recover all of SS control line, 2-flow-couplings, 204 jts 5.5" tubing and 1 cut jt, length 18.20', Flare 6 5/8" clean cut Tubing In good condition slight pitting and on inside of pin Ip ends. Places stub at -8,605' Doyon-16 RKB. 04:30 - 05:00 0.50 PULL DECOMP RID 5.5" Tongs, CIO elevators and Slips. 05:00 - 05:30 0.50 PULL P DECOMP Clear and Clean Rig Floor. Install Wear Ring. 05:30 - 08:30 3.00 PULL P DECOMP P/U and MIU 2nd BHA: 6-5/8" 10 x 8-1/2" OD Washover Shoe, 4-joints 8-1/8" Wash Pipe, Washover Boot Basket, Bumper Sub, Oil Jar, and 9-ea 6-1/4" Drill Collars. 08:30 - 09:30 1.00 PULL P DECOMP Slip and cut drilling line. 09:30 - 17:30 8.00 PULL P DECOMP RIH with 2nd BHA to make Gage Ring run over the collapsed I pipe at +/- 8,665'. Joint #66 RIH at 1230-hours. Jt #97 at Ip 1310-hrs. Hold Kick While Tripping drill. Jt #161 @ 1500-hrs. Jt #180 @ 1530-hrs. Jt #210 @ 1615-hrs. Jt #258 @ 1730. 17:30 - 18:30 1.00 PULL DECOMP P/U joint #259 and MIU to Top Drive. Get parameters: PIU wt 185K, S/O wt 155K, 5-BPM, 160-psi, 50-RPM, Rot wt 166K, 4-5K Ib-ft Stop rotating, wash down and tag stub 6' in on #259 for 8,598' 0-16 RKB. PIU and start rotating at 50-RPM and Printed: 8/14/2007 4:23:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . 07-08 07-08 WORKOVER DOYON DRilLING INC. DOYON 16 Start: Rig Release: Rig Number: Spud Date: 12/17/1978 End: 7/20/2007 8/1/2007 7/26/2007 17:30 - 18:30 1.00 PULL P DECOMP 18:30 - 19:00 0.50 PULL P DECOMP 19:00 - 00:00 5.00 PULL P DECOMP 7/27/2007 00:00 - 09:30 9.50 PULL P DECOMP 09:30 - 12:30 12:30 - 13:30 slowly burn down over stub for 5'. Stop rotating and continue to wash down with #259. P/U joint #260. Continue to PIU DP and wash down to 8,666', Start to burn over collapsed tubing at 8,666' to 8,669' at 70 rpms with 7,000 ft-Ibs torque, pumping at 5 bpm, with 480 psi. Pumped 20 bbl Hi-Vis sweep. Continue washing over tubing from 8,669' to 8,695'. Parameters are 5-25,000# WOB, 10-12,000 ft-Ibs Torque, 70-100 RPM, 13 bpm, with 2,300 psi, pumping sweeps as needed, 3 gals of fine metal shavings recovered from ditch magnets, sweeps bring up small pieces of rubber and sand. 0645-hours, torquing up and bouncing while drilling at 8,705'. Call Engineer to discuss options due to fact that the Shoe has been in use since 1830-hrs last night. Baker has dressed a I more aggressive shoe and is sending it to the rig. Decide to . wash to No-Go, another 20', but make progress to 8,712' and lose torque again. Decide to POH and SIB DP and DCs in Derrick to changeout the Shoe. DECOMP POH and SIB DP in Derrick. Stand #30 out at 1025-hrs. Total of 85-stands in the Derrick. DECOMP POH and SIB 3-stands of DCs in Derrick. B/O and UD Boot Basket, find 4 chunks of metal deformed to the profile of the 10 of the 9-5/8" casing. Also get 2-gallons of metal shavings and bits of rubber. B/O and UD first joint of wash pipe and see the top of the 5-1/2" cutoff looking up about 5' down inside the second joint of wash pipe. Call town and leave message with engineer, and call Wells Superintendent about running a spear inside the fish captured inside the wash pipe. DECOMP Clear and clean Rig Floor and wait on Baker spear for 5-1/2" tubing. DECOMP Hold PJSM to discuss how the 5-1/2" spear would be deployed, how the wash pipe would be secured above the slips, and how the 5-1/2" fish would be secured above the top of the wash pipe as it was being pulled out of the wash pipe. DECOMP Pulled the cut joint and the first full joint of 5-1/2" tubing from the wash pipe. A partly collapsed collar was recovered on the bottom of the full joint, with shoe marks on the extremes of the ovalled collar indicating that the tubing below the collar was collapsed. It was decided to stand back the remaining three wash pipe joints as a single stand. When the shoe was exposed, the shoe was jammed full with chunks of twisted tubing. When the shoe sub was broken and UD, large chunks of twisted tubing came with it. A mirror and camera were utilized to look up inside the hanging stand and it was discovered that a large chunk of twisted metal was inside the tubing. A steel thread protector for the wash pipe was taken to the rig shop and a face plate welded over it. The protector was screwed back onto the bottom of the wash pipe and the wash pipe lowered into the floor in order to break out each joint of wash pipe safely without losing any of the fish inside. One half of the bottom 30' joint of wash pipe is crammed full with the collapsed, twisted 2nd full joint of 5-1/2" tubing. The chunks of twisted metal inside the shoe are thought to be the 4.20' long 3.00 PULL P 1.00 PULL P 13:30 - 14:00 0.50 PULL P 14:00 - 14:30 I 0.50 PULL P 14:30 - 16:00 1.50 PULL P Printed: 8/14/2007 4:23:24 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-08 07 -08 WORKOVER DOYON DRilLING INC. DOYON 16 Start: 7/20/2007 Rig Release: 8/1/2007 Rig Number: Spud Date: 12/17/1978 End: 712712007 14:30 - 16:00 1.50 PULL P DECOMP Sliding Sleeve. 16:00 - 17:00 1.00 PULL P DECOMP Break out and UD spear from cut-off joint. The cutoff joint is 24.20', and the full joint is 43.30' including both collars. 17:00 - 18:00 1.00 PULL P DECOMP PIU and MIU new standard-dressed washover shoe to 4-joints of wash pipe . 18:00 - 22:00 4.00 PULL P DECOMP RIH with BHA #2, f/434' to 8,595' 22:00 - 23:00 1.00 PULL P DECOMP MIU TID to Jt 262 and obtain parameters, up weight=185,000#, down weight=155,000#, rotating weight=170,000#, 60 rpm. Washed down from 8,669' tagged fish at 8,708', continued to wash over to total depth of 8,835'. NO-GO out on 126' of wash pipe. 23:00 - 00:00 1.00 PULL P DECOMP CBU at 14 bpm w/2550 psi. 7/28/2007 00:00 - 00:30 0.50 PULL P DECOMP CBU at 14 bpm with 2450 psi, wI 45% return flow. At 5300 stks( anticipated BU was 5500 stks ), flow increased to 60 %. Shut down pumps, well flowing, shut in Annular Preventer. Driller notified night WSL and Tool Pusher. Night WSL!:~ day WSL, Drilling Superintendent Jim Willingham, AOGCC re resentative Chu t. Monitor Pressures, O-psi on Drill pipe and O-psi on Annulus. Held PJSM with rig crew and mud engineer to discuss forward plan. Opened super choke, no flow or gas, Staged open super choke to the full open position with no flow or gas, monitored for 10 minutes. PJSM, Opened Annular Preventer. 00:30 - 01 :30 1.00 PULL P DECOMP CBU at 14-BPM with 2550-psi, monitor well bore, well static. Possible cause of "kick" was air liberated from the seawater during washover operations. No fluid gains from or losses to the formation have been experienced. 01 :30 - 05:00 3.50 PULL P DECOMP PJSM. Pump 10-Bbl dry job, POOH and SIB DP. 05:00 - 06:00 1.00 PULL P DECOMP SIB DCs. Break off, UD Jars, Bumper Sub, 2-jts Washpipe, and empty Boot Basket; small amount of cuttings and debris dumped from basket. Break off and UD washover shoe. Shoe appeared to be in very good shape. 06:00 - 07:30 1.50 PULL P DECOMP P/U and MIU Outside Cutter and Cutlip Guide to bottom of two joints of Washpipe and SIB. Pull Wear Ring. 07:30 - 08:00 0.50 BOPSU P DECOMP Pressure test Annular Preventer 250-psi low, 3,500-psi high due to actuating Annular Preventer at -0015-hrs. 08:00 - 09:00 1.00 PULL P DECOMP RIH Outside Cutter BHA on 3-stands DCs from Derrick. 09:00 - 12:30 3.50 PULL P DECOMP Continue RIH on DP from Derrick. Stop above stub at -8,705' and get parameters: Up wt 180K, On wt 157K, Rot wt 168K @ 20-RPM and 2K free torque. Called for and received permission from WSL Superintendent to allow Baker Fisherman to operate the Rig during tubing cutting operation. 12:30 - 13:30 1.00 PULL P DECOMP Stop rotating and swallow stub, run Cutlip Guide to -8,767', 0-16 RKB, which puts cutters -8,761'. Start with rotating wt 160.3K-lbs at 30-RPM and 3-4K-lb-ft torque, slowly P/U string to ease cutter kick-out fingers up against bottom of collar. See weight increase about 500 to 600-lbs plus PIU of 300 to 400-lbs to -161.4K-lbs and torque increase to 5K-lb-ft. Cut-through complete at 1315-hrs. Stop rotating and continue to P/U slowly and see that the additional weight is still in string. Calculated additional weight in air is - 750-lbs. Cut depth is 8,756',0-16 RKB. 13:30 - 16:00 2.50 PULL P DECOMP POH and SIB DP in Derrick. Stand #25 in Derrick at 1420-hrs; Printed: 8/14/2007 4:23:24 PM . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -08 07-08 WORKOVER DOYON DRilLING INC. DOYON 16 Start: 7/20/2007 Rig Release: 8/1/2007 Rig Number: Spud Date: 12/17/1978 End: P P . ···.·tr_Phâ I DECOMP 1#45 @ 1455-hrs; #60 @ 1520-hrs; #70 @ 1535-hrs. ! DECOMP POH and SIB DCs in Derrick. IDECOMP Break out and UD Boot Basket, nothing inside. PJSM. Break off first joint of wash-pipe and cutoff fish is inside. Place Dog Collar on 5-1/2" fish, set aside wash-pipe, and use hand cutter to cut 5-1/2" tubing. This cutoff also has the Landing Collar intact on top of it. Note: the 00 of the Sliding Sleeve is the same 00 as the 5-1/2" tubing collars. UD first joint of wash-pipe, Break off and UD 2nd joint of washpipe and the Outside Cutter. Prepare to PIU Overshot Grapple. DECOMP MIU Overshot Grapple Assembly, BHA consists of Cut Lip Guide, Over Shot Bowl, Top Extention, Top Sub, Bumper Sub, Oil Jar, XO, 9-Drill Collars, XO, Accelerator Jar, XO. BHA Lenght=322.83 DECOMP RIH wlovershot BHA to 8,673'. DECOMP Slip and Cut Drilling line DECOMP Obtain Parameter: up weight=180,000-lbs, down weight=156,000-lbs, rotating weight=169,000-lbs, 40 rpm, RIH and washed over fish at 8,756'. Latched onto fish and began jarring on SBR at 120,000-lbs over string weight. Pulled SBR free after 30 minutes. DECOMP CBU at 7-BPM with 1, 150-psi. DECOMP Continue to CBU at 9-BPM with 1540-psi. Slacked off and tagged top of slick stick. Monitor well and O-psi, all around. DECOMP POOH from 8,724' to 7,057' with significant drag, up to 75,000# over string weight, worked pipe through this interval. The over-pull reduced as we POOH, then got rough with 20-stands remaining, worked pipe for 20-minutes and resumed pulling easily. DECOMP POH and SIB DCs. Pit watcher reported possible fluid loss from slop tank to O/A via 2" Bleed off line from O/A to slop tank. It was thought to be from well bore contraction. DECOMP B/O and UD Jars and Bumper Sub with extension. Hold PJSM to describe how the fish inside the Overshot and Grapple would be handled. Break out and UD the cutoff joint and Baker Landing Nipple attached to the O/S and Grapple. BIO and UD full joint of 5-1/2" tubing. BIO and UD 5-1/2" pup joint. PIU on SBR and it started dragging through wellhead. Drain Stack and see that a 3'-long chunk of pipe has lodged between the Wear Ring and the Guide Bell at the bottom of the SBR, dragging the Wear Ring with it. Use sledge hammers and a few well-placed blows to the chunk of iron and Wear Ring comes free. UD the SBA. Call Cameron to inspect the Wear Ring and function the LDSuonly 3-LDSs had been run-in to hold the Wear Ring in place. 00 of the Wear Ring was inpsected by Cameron Tech, Rodney Jones, who also functioned LOSs. Cameron instructed us to re-dress the Wear Ring with a grinder in our shop. PIU Grapple and run the cutoff joint back through rotary table, B/O the Grapple and UD Grapple and cutoff joint with Baker Landing Nipple. Lengths of fish: Cutoff= 38.85'; Landing Nipple = 2.62'; Full jt = 41.12'; pup joint = 4.77'; SBR = 39.17'. Total length = 126.53'. The length of the inner seal stem remaining in the well looking up is -35'. Top of this seal stem is - 8,847'. 18:00 - 19:00 1.00 PULL I P 19:00 - 21 :00 21 :00 - 22:00 22:00 - 23:00 2.00 PULL I P 1.00 PULL P 1.00 PULL P 7/29/2007 23:00 - 00:00 00:00 - 01 :00 1.00 PULL P 1.00 PULL P 01 :00 - 06:30 5.50 PULL P 06:30 - 07:00 0.50 PULL P 07:00 - 11 :00 4.00 PULL P Printed: 8/14/2007 4:23:24 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-08 07 -08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: Spud Date: 12/17/1978 End: 7/20/2007 8/1/2007 install Wear Ring. DECOMP PIU and M/U Overshot and 9-5/8" Scraper BHA: 5-1/2" 10 Shoe as Overshot, 1-jt wash pipe, washover boot basket, 2-ea Boot Baskets, 9-5/8" Casing Scraper, Bumper Sub, Oil Jar, and 9-ea 6-1/8" DCs. 13:00 - 15:00 2.00 PULL P DECOMP RIH 9-5/8" Scraper BHA on DP from Derrick. 15:00 - 16:30 1.50 PULL P DECOMP Yo-Yo Scraper from 8,730' to 8,781' for setting the Baker packer during completion. 16:30 - 17:30 1.00 PULL P DECOMP Monitor well due to slight flow well out of balance. CBU at 5 BPM wl440 psi. Pit watcher reported what appeared to be Arctic Pack and diesel coming over the shakers. 17:30 - 18:00 0.50 PULL P DECOMP Continue to wash down to 8,877', NO GO out 13' in on jt 270, Verified slick stick is at 8,844' 18:00 - 19:30 1.50 PULL P DECOMP Pumped a 20 bbl Hi-Vis sweep at 10 bpm with 1,270 psi. 19:30 - 20:00 0.50 PULL P DECOMP Monitor well, pump dry job, BID T/D. Called Howard West to discuss situation with the Arctic Pack, and relayed the rig team's concerns of the possiblity of opening an FO sliding sleeve on the previous trip. Baker Fishing Hand and WSL Superintendent researched the well archives at PBOC and found a tally with two FOs installed in the 9-5/8" casing string at 2,342' and 2,468',0-16 RKB. Decision made to RIH with the planned RBP and test the casing from between the two FOs. 20:00 - 22:30 2.50 PULL P DECOMP POOH w/BHA #6 from 8,877' to 355'. 22:30 - 23:30 1.00 PULL P DECOMP Stand back Drill collars UD over shot assembly. 23:30 - 00:00 0.50 PULL P DECOMP Clear and Clean rig floor. 7130/2007 00:00 - 00:30 0.50 PULL P DECOMP Clear and Clean rig floor of baker tools 00:30 - 01 :30 1.00 PULL P DECOMP PIU MIU RBP and RIH wlDrill Collars. 01 :30 - 02:30 1.00 PULL P DECOMP RIH with Drill Pipe to 2,181' and set RBP, up weight 83,000-lbs, down weight 85,000-lbs. 02:30 - 03:30 1.00 PULL P DECOMP Test 9-5/8" Casing above the top FO at 2,342',0-16 RKB. Staged-up pumps, checking pressures on annulus, test to 3,500 psi for 5 mins, good test. Released RBP. 03:30 - 04:00 0.50 PULL P DECOMP Continue to RIH to below the 1st FO and set RBP at 2,370', up weight=86,000#, down weight=90,000#. RIU and attemped to test casing and FO #1, staged-up pump to 500 psi and observed 450 psi on Annulus, Contacted Howard West to discuss options. Released RBP. 04:00 - 04:30 0.50 PULL P DECOMP RIH to below the 2nd FO at 2,468' 0-16 RKB and set the RBP at 2,560'. 04:30 - 05:30 1.00 PULL P DECOMP POOH with RBP Running tool. SIB DP in Derrick. 05:30 - 06:00 0.50 PULL P DECOMP POOH stand back DCs, UD RBP Running Tool. 06:00 - 07:30 1.50 PULL P DECOMP P/U Halliburton FO shifting tool and RIH. Up wt 88K, Dn wt 1.50 I DHEQP 85K. 07:30 - 09:00 P DECOMP Slowly tag top FO at 2,351' and set down 5,000 to 6,000-lbs and FO shifts. PIU to re-tag, but don't see the FO when setting back down. Pressure test casing working up in stages, see 500-psi on tubing and OA. SID and bleed off. Continue RIH to tag 2nd FO at 2,475'. Shifted the FO with 10,000-lbs, PIU and RIH to verify and didn't see FO. Pressured up to 3,500-psi and it held rock solid for 10 chart-recorded minutes. 09:00 - 10:30 1.50 PULL P DECOMP POOH with Halliburton FO shifting tool. 10:30 - 15:00 4.50 ì PULL P DECOMP PIU RBP running tool and RIH to unseat RBP at 2,559' and continue RIH to re-set at 8,760'. Printed: 8/14/2007 4:23:24 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -08 07 -08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 7/20/2007 8/1/2007 Spud Date: 12/17/1978 End: 21 :00 - 22:00 1.00 RUNCO PT 9-518" casing to 3,500-psi. Hold and record 3,500-psi test 30-minutes. Rock solid test. OA O-psi. Bleed down lines. P/U RTTS and Storm Valve, RIH and set 10' below wellhead. Test from above to 1 ,OOO-psi and hold for 10-minutes. Rock solid test. Cameron Techs change-out 9-5/8" Packoffs. RIH and pull two piece pack off, Install new 9 5/8" pack off and secure with lock down screws, Test new pack off to 5,000 psi for 30 minutes, good test. Install wear ring and UD running tool. P/U single DP and RIH to retrieve RTTS, UD RTTS. RIH for 8,454' to 8,760' and latch onto RBP and Pull 25,000-lbs over string wt to release RBP. String wt 180,000-lbs. M/U Topdrive to circulate bottoms up at 8-BPM with 820-psi. POOH from 8,760' to 8,260' laying down drill pipe through Pipe Shed. Continue to POOH from 8,260', Laying down drill pipe through Pipe Shed. POH and UD Dcs through Pipe Shed. Clear and clean Rig Floor. RID DP handling equipment. R/U tubing handling equipment to prepare for RIH with new 4-1/2", 12.6#, 13Cr-80, VamTop tubing completion. PJSM to run new completion. RIH with new completion. M/U all connections below Baker S-3 Production Packer with BakerLok. Use Jet Lube Seal Guard pipe dope on all connections and torque same to 4,440-lb-ft. Joint #75 RIH at 1440-hours. 110-jts @ 1600-hrs. Replaced joint #119 with identical length joint from spares kept outside the Pipe Shed. 130-jts @ 1800-hrs. 190-jts @ 2000-hrs. RIH with joint #203. RUNCMP P/U #204, P/U wt 135K, SIO wt 125K. Slowly RIH to tag stub at 8,844' Continue in and see pins shear at 4-5K. NolGo out at 8,853'. Spaced out with 5' of swallow with Unique overshot, 3' above No/Go. Ran a total of 202 joints of 41/2", 12.6#, 13Cr-80, Yam Top Tubing. RID tubing handling equipment and install 4" DP elevators. M/U Gray tubing hanger and landing assembly. Land tubing hanger. P/U wt 135K, S/O wt 125K. Run in lock down screws, R/U to reverse circulate. Reverse in 150 bbls of 140 degree 8.5 seawater followed by 470 bbls of 140 degree 8.5 ppg seawater with EC-1124A corrosion inhibitor. 3 bpm with 130 psi. Pressure up on tubing to 3,500 psi to set packer and test tubing. Hold test for 30 minutes. Good test. Bleed tubing pressure to 1,600 psi. Pressure up on the 4 1/2" x 9 5/8" annulus to 3,500 psi for 30 minutes. Good test. Bleed down tubing pressure. OCR valve sheared at 800 psi. Circulate both directions through DCR valve. RUNCMP Break out and UD crossover and Landing Joint. RUNCMP Suck out BOP stack. P/U and test DSM lubricator to 500-psi. During this test, the extension moved up against the bottom of the Hydril a greater distance than the Driller had measured, so the test was curtailed when the pressure reached 500-psi. 16:00 - 17:00 1.00 DHB P DECOMP 17:00 - 20:00 I 3.00 WHSUR P DECOMP 20:00 - 20:30 0.50 WHSUR P DECOMP 20:30 - 21 :00 0.50 WHSUR P DECOMP 21 :00 - 21 :30 0.50 DHB P DECOMP 21 :30 - 22:00 0.50 DHB P DECOMP 22:00 - 23:00 1.00 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 7/31/2007 00:00 - 06:00 6.00 CLEAN P DECOMP 106:00 - 07:00 1.00 CLEAN DECOMP 107:00 - 08:00 1.00 CLEAN DECOMP 08:00 - 09:30 1.50 RUNCO RUNCMP 09:30 - 10:00 0.50 RUNCO RUNCMP 10:00 - 21 :00 11.00 RUNCO RUNCMP 22:00 - 22:30 0.50 RUNCO RUNCMP 22:30 - 23:00 0.50 RUNCO RUNCMP 23:00 - 00:00 1.00 RUNCO RUNCMP 8/1/2007 00:00 - 04:00 4.00 RUNCO RUNCMP 04:00 - 06:00 2.00 RUNCO P RUNCMP 06:00 - 06:30 06:30 - 08:30 0.50 RUNCO P 2.00 BOPSU P Printed: 8/14/2007 4:23:24 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-08 07 -08 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/20/2007 Rig Release: 8/1/2007 Rig Number: Spud Date: 12/17/1978 End: 06:30 - 08:30 P Bleed down lubricator, break it off, P/U tools, M/U lubricator to 108:30 - 10:00 I extension, install BPV and dart and test to 1 ,OOO-psi from I underneath. RID DSM. 1.50 BOPsur RUNCMP N/D BOP and set it back on the BOP stump. 10:00 - 13:00 3.00 WHSUR P RUNCMP N/U adaptor flange and tree. 13:00 - 14:00 1.00 WHSUR P RUNCMP Pressure test neck seal and void on adaptor flange to WHSUR I P 5,000-psi, retorque LOSs and gland nuts and hold for 30-minutes. Solid test 14:00 - 16:00 2.00 RUNCMP Fill tree with diesel and test to 5,000-psi. Swab valve flange I leaked, retightened stud nuts with PowerTorq wrench and re-test tree; successfully flat-lined at 5,000-psi for 10-minutes. P/U DSM lubricator and pull the dart and the BPV. 16:00 - 18:30 2.50 WHSUR P RUNCMP R/U Lil Red Hot Oilers to freeze protect with 170-Bbls of diesel. Pump diesel freeze protect 2 bpm with 700 psi. 18:30 - 19:30 1.00 WHSUR P RUNCMP Line up hoses and U-tube diesel freeze protect 19:30 - 21 :00 1.50 WHSUR I P RUNCMP R/U DSM lubricator and install Gray BPV. Test BPV to 1,000 psi for 10 minutes. 21 :00 - 00:00 3.00 WHSUR P RUNCMP Blow down and remove lines from tree. Remove secondary annulus valve. Secure well and cellar. Rig released at 24:00 hrs. 8/2/2007 00:00 - 06:00 6.00 MOB P PRE Move Doyon 16 off of well DS7 -08. Spot rig on pad and lower derrick. Move rig around pad and spot next to camp. Remove spreader beam. 06:00 - 20:30 14.50 MOB P PRE Remove tire from Driller's-side Planetary. Replace Planetary Clean and install wheel assembly. 20:30 - 23:00 2.50 MOB P PRE Clean and install tire assembly. 23:00 - 00:00 1.00 MOB P PRE Install stearing arm assembly. 8/3/2007 00:00 - 07:30 7.50 MOB P PRE Install rear spreader beam. Hook up hydraulic lines to moving system. Install Kill line, heaters, cellar pump lines. Install frame for booster wheels, install booster wheels. Printed: 8/14/2007 4:23:24 PM 07-08A (PTD #1982440) Classified as Problem well . All, Well 07-08A (PTO #1982440) failed an MITIA with a sudden loss of pressure on 3/15/07. On 03/16/07 the TIOs were found to be SSV/2450/10 psi and an IA bleed was attempted to no avail. Given the high GaR of the well and that the IA fluid level was found at 8565' MO, it appears the well has compromised tubing. The plan forward for the well is as follows: /' 1. S: Caliper and Set WRP The well has been classified as Problem. ."- A well bore schematic has been included for reference. «07-08A.pdf» Please call with any questions. Thank you, Sr:ANNED MAR 2 '1 2007 Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 07-08A.pdf 07-08A.pdf Content-Type: application/octet-stream Content-Encoding: base64 I of I 3/19/200712:01 PM TREE'" GRf\ Y GEN 2 WELLHEAD = GRA Y ~""',=^=~w.w,~y,·,""'''=~ ACTUA TOR = AXELSON 13-318" CSG, 72#, N-80, ID = 12.347" Minimum ID ::: 2.80" @ 8998' TOP OF 3-3/16" LNR I TOP OF 4-112" TBG I 5-112" TBG, 17#, L-80, .0232 bpf. ID'" 4.95" I ITOP OF 3-1/2" LNR I 13-112" LNR. 9.3#, L-80, .0087 bpf, ID = 2.992" I I TOP OF 3-3116" LNR I I TOP OF CEMENT H 14-112" TBG, 12.6#, L-80, .0152 bpI, 10= 3.958" I 9-5/8" CSG, 47#, N-80, ID = 8.681" H . 07 -08 ~ SAFETY NOTES: 8965' 9024' ~ 9036' 9610' ~ PERFORA TION SUMivlARY REF LOG: MEM CNL ON 02104199 ANGLE AT TOP PERF: 59 @ 9760' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-114" 6 9760 - 9779 0 07120/03 2-114" 6 9782-9802 0 05/31/03 2" 4 10299 - 10576 C 02/05/91J 2" 4 10768 - 10907 C 02/05/99 DA TE REV BY 01109179 01112199 5101 RN/TP 05/31- 07/20103 SRBIT 09/10/03 CMOfT COMMENTS ORIGINAL COM PLETION SIDETRACK (07-08A) CORRECTIONS RFS, CIBP . 5-112" CAMCO BAL-O SSSV NIP, ID = 4.581" 2151' 8718' --1 5-1f2"BAKERSLlDINGSLV,ID=4.313" 8804' -l 5-1/2" BAKER LANDING NIP, 10 = 4.223" -j 5-1/2" BAKER SBR ASSY, ID = 4.875" I -j 9-5/8" X 5-1/2" BA KER SAB PKR, ID = 4.223" 8915' -l 5-1/2"X4-1/2"XO I 8961' -l3-3/4" X 3" BAKER DEPLOY SLV,ID= 3.000" I 8975' 4-1/2" BAKER NIP, ID = 3.759" (BEHIND 3-1/2" LNR) 8998' -l 3-112" X 3-3/16" XO, 10 = 2.992" I 9035' 4-1í2" SHEAR OUT SUB. ID = 4.125" (BEHIND 3-3/16" LNR), MILLOUT WINDOW - 9610' - 9620' PBTD - BAKER LANDING COLLAR, ID = 2.992" BAKER FLOA T SHOE 13-3/16" LNR, 6.2#, L-80, .0076 bpf, 10= 2.80" H 10937' 10948' PRUDHOE BA Y UNIT WELL: 07-08A PERMIT No: '1982440 API No: 50-029-20296-01 SEC 33, T11N, R14E, 2905.82' FEL & 4275.96' FNL OA TE REV BY COMMENTS 12í21/06 OOBIPA CORRECT 9-5/8" eSG DEPTH CTION BP Exploration (Alaska) . . SARAH PALIN, GOVERNOR AIfASIiA. OIL AND GAS CONSERVATION COMMISSION Garret Staudinger CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99507 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07 -08A Sundry Number: 307-051 5CAHNED FEO 1 4 2007 lb"~4' \q Dear Mr. Staudinger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, . DATED this tJ day of February, 2007 Encl. I d.. \J..... " .... U 0tfr.l (J 101 a STATE OF AfJ!l.J'¡Z-O 7 ..¿:f~ FEE.O 6 Z007 1\ ~ I ALA~ OIL AND GAS CONSERVATION COM~ION ~h,,>- APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons Commission prJ 2/13/7 20 MC 25.280 Anchorage 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 198-244 f 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20296-01-00 ¡ .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 07 -08A ¡ Spacing Exception Required? DYes ~No 9. Property Designation: í 110. KB Elevation (ft)¡ 11. Field / Pool(s): ADL 028309 64' Prudhoe Bay Field / Prudhoe Bay Pool < .t2'.>V..... .... 'W¡:::¡I 'Jii /.>~ ..··.··c-·V.·/ 1>:/1> i> .....·.1 ....... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10948 9023 9920 8949 9920 None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 119' 20" 119' 119' 1!'i10 520 Surface 2712' 13-3/8" 2712' 2712' 4930 2670 Intermediate 9610' 9-5/8" 9610' 8781' 6870 4760 Production Liner 1978' 3-1/2" x 3-3/16" 8968' - 10946' 8250' - 9022' 10160 10530 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9760' - 10907' 8878' - 9017' 5-1/2",17# x 4-1/2",12.6# L-80 9036' Packers and SSSV Type: 9-518" x 5-1/2" Baker 'SAB' packer I Packers and SSSV MD (ft): 8903' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: March 15, 2007 DOil DGas D Plugged ~ Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garret Staudinger, 564-4242 Printed Name Garret Staudinger Title CT Drilling Engineer Signature .,¿) c.-::k' ~ A Date 2/{;/O1 Prepared By Name/Number: ~~ Phone 564-4242 Terrie Hubble. 564-4628 '" Commission Use On Iv I Sundry Number: ?1(j - ðS I Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: 3500 \,s1 ~\> ~S\- Subsequent Form Required: ~\:J ~~OMMISSIONER APPROVED BY 2-13/ð'f Approved Bv: THE COMMISSION Date Form 10-403 Revised 06/2006 L/ \./' - Submit In Duplicate .. U¡~'G I~AL RBDMS 8Ft J ¿{ 2DOí . . Obp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Garret Staudinger CTD Engineer Date: February 1, 2007 Re: Prep Prudhoe 07 -08A for CTD sidetrack Sundry approval is requested to prepare 07-08A for a sidetrack. Well 07-08A was sidetracked in February as a horizontal Zone lB producer. It has an 800' long 3-3/16" horizontal section with 416' perforated. CTD had problems while cementing the liner. They then shot the initial perfs without pressure testing the liner top. Based on the inability of the well to flow, the liner top is not leaking. The well had a very difficult time coming on line initially due to low flow and 5-1/2" tubing without GLV's. In August 1999, a 6800' 2-3/8" coil string was run in the well to provide AL to be pumped down the coil x tubing annulus with production up the coil string. This was an attempt to avoid shooting POGLM holes in good tubing. The plan was to produce the well up the CT string using gas lift until the formation GOR rose and the well was able to flow unassisted before pulling the AL coiled tubing string. The well came on line at 700 BOPD at less than 10,000 GOR and initially appeared to be OK, however production started slugging between 100-200 BOPD shortly thereafter. They continued to play with it trying to maintain stable production when it was decided to reverse flow on December 20, 1999 to improve hydraulics. This was a bad decision because the well had a history of sand production and had already blown out a bend on the downcomer (09/16/00) and a drain line in the manifold building (03/08/99). On February 19, 2001 the well blew out after the gate valve connected to the 2" side port on the tubing head spool piece eroded and leaked. The well was killed, the valve was pulled, and the side port was blinded. During the initial kill of the well control incident, they pumped 165 bbls of 9.8 ppg brine followed by 25 bbls high viscosity fluid/17 bbls sized salt pil1l24 bbls high viscosity fluid and 253 more bbls of 9.8 ppg brine. The well did not flow. The Wells Group returned on 2/26/01 and pumped a 38 bbl CaC03 pill in the well. They figured 12 bbls went behind pipe and the final CaC03 top was 8454'. The tree, flowline, S riser, and manifold piping were all checked by CIC or the valve shop; everything looked fine mechanically. The coil AL spool was removed on 4/16/01 and the well was returned to a "typical" configuration. A Kinley caliper run on 5/19/01 showed the 5-1/2" tubing to be in good condition with only 10- 20% damage The decision was made to abandon the horizontal section. In addition to operations being uncomfortable producing the well due to historical sand production/surface erosion, it is highly likely that formation damage was caused during the well kill operations. A CffiP was then set at 9920' on 5/31/03 to isolate the horizontal and a 30' Zone 2B lens was perforated; the lens would not flow on its own. An additional 20' of perforations were added on 7/20/2003 and the well came on at 2000 BOPD with less than 10,000 GOR. 07-08A remained a full-time producer for the next 7 months before hitting marginal and has been a cycle well since. . . REASON FOR SIDETRACK: 07-08A is a high gas rate cycle well with very little on-time production (-30%). Due to the ability to defer most of the existing lens perf value and the lack of wellwork options remaining in the horizontal section, the well is recommended for a coil sidetrack. The proposed plan for 07-08A is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around May 10,2007. The sidetrack, 07-08B, will exit the existing 3-3/16" liner and kick off in zone 2 and land in zone lB. The existing perforations will be isolated by a CffiP below the WS initially, followed by the cement job on the 07-08C production liner cement job. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (Scheduled to begin March 15,2007) 1) S Drifted liner to 9801' SLM 2) S Passed tubing caliper inspection 3) 0 Passed MIT-IA and MIT-OA. 4) 0 AC -LDS; AC-PPPOT-IC, T 5) E Set Cast Iron Bridge Plug at 9750' 6) E Set 3-3/16" Baker Monobore WS wi LS orientation at 9685' 17) 0 SetBPV 8) 0 PT MV, SV, WV 9) 0 Bleed gas lift and production flowlines down to zero and blind flange 10) 0 Remove wellhouse, level pad July 1, 2006 July 1, 2006 July 11, 2006 ~ ~ ~~~\.)~\, 1 Rig Work: (Scheduled to begin May 10, 2007) 1) MIRV Nordic 1 and test BOPE to 250psi low and 3500psi high. 2) Mill 2.74" window at 9685' and 10' of rat hole. Swp the well to Flo-Pro. 3) Drill Build: 3.0" OH, 465' (30 degllOO planned), with resitivity 4) Drill Lateral: 3.0" OH, 1100' (12 degllOO planned), with resistivity 5) MAD pass with resistivity tools in memory mode 6) Run solid 2-3/8" liner leaving TOL at 9400' 7) Pump cement leaving TOC at 9400' 8) Cleanout liner and MCNLlGRlCCL log 9) Test liner lap to 2000 psi 10) Perforate liner per asset instructions (~800') 11) Well will be left with extra diesel in the fluid column to lighten the load for initial kickoff. 12) Freeze protect well and RDMO ~Cè ~ "-'.<:J ~ \t~~,~J . Post-Rig Work: 1) Install well house, flow line and gas lift valves. 2) Test Separator (~800' of perfs) Garret Staudinger CTD Drilling Engineer 564-4242 CC: Well File Sondra StewmanlTerrie Hubble TREE'= 'RAY GEN2 WELLHEAD = GRAY 07 -08A SAÆ1YNOTES: I ACTUATOR= AX8.SON KB. a.BI = 64' BF. a.BI = KOP= 4165' Max Angle = 36 @ 10444' Datum M) = 9738 Datum lVD = 8800' 55 2151' 5-1/2" CAMCO BAL-O SSSV NIP, ID= 4.581" I . I 13-3/8" CSG, 72#, N-SO, ID = 12.347" 2712' ~ ~ Minimum ID = 2.80" @ 8998' I I 8718' 5-112"BAKERSLIDINGSLV,ID=4.313" I TOP OF 3-3/16" LN R I . 8804' 5-1/2" BAKER LANDING NIP, ID = 4.223" I ~ t~ 8853' -l 5-1/2" BAKERSBRASSY, ID=4,875" I 8903' 9-5/8" x 5-1/2" BAKER SAB PKR, ID = 4,223" I TOPOF 4-112" TBG I 8915' 8915' -I 5-1/2" X 4-1/2" XO I '}-- ~ I 5-1/2" TBG, 17#, L-80, .0232 bpf, ID= 4.95" 8915' I 8961' 3-3/4" x 3" BAKER DEPLOY SLV, ID = 3,000" TOP OF 3-112" LNR I ~ - 8965' . 8975' 4-1/2" BAKER NIP, ID = 3,759" I (BEHIND 3-112" LNR) 13-1/2" LNR, 9.3#, L-80, ,0087 bpf. ID = 2.992" 8998' 8998' H 3-112" X 3-3116" XO, ID = 2.992" I I TOP OF 3-3/16" LNR 8998' -¡...--- TOP OF CEMENT H 9024' ~ 14-112" TBG, 12.6#, L-80, ,0152 bpf, ID = 3.958" I 9036' ~ 9035' 4-112" SHEAR OUT SUB, ID = 4.125" I I (BEHIND 3-3/16" LNR), I 9-518" CSG. 47#, N-BO, ID = 8.681" 1-1 9610' ~ I I it MLLOur WlNOOW - 9610' - 9620' PERFORA ìlON SUIllfMRY REF LOG: MEPJI O\IL ON 02104I99 9920' H CIBP SET 05131103 I ANGLE A T TOP PERF: 59 @ 9760' Note: Refer to A'oduction DB for historical perf data 10903' PBTD - BAKER LANDING I SIZE SPF INTERVAL OpnlSqz DATE COLLAR, ID = 2.992" 2-114" 6 9760 - 9779 0 07r2lJ/03 2-114" 6 9782 - 9802 0 05131103 10937' BAKER FLOAT SHOE 2' 4 10299 - 10576 C 02I05J99 A ~ 2' 4 10768 - 10907 C 02I05J99 " 91 TD -I 10948' I 13-3/16" ~ R 7j I _An nn78 bnf = an" ~ 4 na.'7' I DATE REV BY COP/fÆNl"S DATE REV BY CONrv'ENTS PRUDHOE BAY UNrr 0110'"9 ORIGINAL COMPLETION 12/21106 OOBlPAG CORRECT 9-518" CSG DEPTH WELL: 07-OSA 01112199 SIDETRACK (07 -OIA) PERMT No: ~982440 05115101 RJ'IVTP CORRECTIONS AA No: 50-029-20296-01 05131103 SRBI1lP a..OSElNB'\I PERFS, CBP SEC 33, T11 N, R14E, 2905.82' Fa. & 4275.96' FNL 07r2lJ/03 SRBI1lH AOO PERFS 09110103 ~P PERF ANGLECORRECTK>N BP Exploration (Alaska) "/'2.#, 12.347" PERFORATION SUMMARY REF LOG: MEM CNL ON 02/04/99 ANGLE AT TOP PERF: 59 @ 9760' Note: Refer to A-oduction 2" 2" Color Blueline Prints CD / 1 1 )d.LL<)~ 1 1 1 é). L/l?=r Schlumbel'gel' Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description H.17 A \ ~ ~' \ f);\ 10558569 MCNL K-03A 1 - éÁ) 10560252 SCMT D.S.07-32 ,<1?\ ~ð~ 10564482 SCMT D.S. 07-08A ~rr\'J -(9 10559786 SCMT Z-03") c¡ -\7) I 40001315 MWD GR (REPROCESSED) Z-03 40001315 MWD GR MD Z-03 40001315 MWD GR TVD D.S.15.28A S-03-\@ 1-1 10715362 MEM PPROF & IPROF Date 08112103 04125103 06110103 05128103 O'}120/97 C'.,:~' ,.. -O¡'/..:C':7 -J. 11121'~' --I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 RECEIVED , . ,'-.. ... d.- {'\!'\.. 1 ,- ~ 'I ,- j Iv i , '.. --'- l.~ Date Delivered: , ,.-.".. '"'1: ~ "".,~ """"I:: ('omtt1~ ,'<,;;:;L è~':...,L~Ui:l...l""'!I"";'; ,.!;,~~; ¡:,r:!",h,;~taae - ,.."¡ .... ~~~~"\~ 12/31103 NO. 3087 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 1 1 1 -- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~e:\ \ ~/~\. C ~~ ~iYì , . (' STATE OF ALASKA { ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 SuspendD Operation ShutdownD Perforate ŒI WaiverD OtherD Alter CasingD Repair WellD Plug PerforationsO Stimulate D Time ExtensionO Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 198-2440 Development I]] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20296-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 07-o8A 8. Property Designation: 10. Field/Pool(s): ADL-0028309 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10948 feet true vertical 9022.7 feet Plugs (measured) 9920 Effective Depth measured 9920 feet Junk (measured) None true vertical 8949.1 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 39 - 119 39.0 - 119.0 1530 520 Liner 37 3-1/2" 9.3# L-80 8961 - 8998 8243.7 - 8275.8 10160 10530 Liner 1941 3-3/16" 6.2# L-80 8998 - 10939 8275.8 - 9021.1 Production 2344 9-5/8" 47# 500-95 28 - 2372 28.0 - 2372.0 8150 5080 Production 82 9-5/8" 47# N-80 2372 - 2454 2372.0 - 2454.0 6870 4760 Production 44 9-5/8" 47# 500-95 2454 - 2498 2454.0 - 2498.0 8150 5080 Production 6164 9-5/8" 47# N-80 2498 - 8662 2498.0 - 7986.3 6870 4760 Production 948 9-5/8" 40# SOO-95 8662 - 9610 7986.3 - 8781.3 6820 3330 Surface 2674 13-3/8" 72# N-80 38 - 2712 38.0 - 2711.9 4930 2670 Perforation depth: R E eEl V E 0 Measured depth: 9760 - 9780, 9782 - 9802 . . True vertical depth: 8877.63 - 8994.48,8889.25 - 8995.48 JAN 0 8 2004 Tubing (size, grade, and measured depth): 5-1/2" 17# L-80 @ 27 - 8915 . ., 4-1/2" 12.6# L-80 @ 8915 - 9035 Alaska Oil & Gas Cons. CommiSSIOn Packers & SSSV (type & measured depth): 5-1/2" Baker SAB Packer @ 8903 Anchorage No SSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 610 18.1 212 0 580 Subsequent to operation: 2134 21.5 0 600 1060 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ) ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasD WAG D GINJD WINJD WDSPLD Daily Report of Well Operations. ! Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron NI A Printed Name Garry Catron . i ~ 1 5 2004 Title Production Technical Assistant Signature Phone 564-4657 Date 1/7/04 Form 1 0-404 Revised 12/2003 ( .Bf~ L JAM U ~ 1U\!~ ~ :( . 07-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/20103 MEM GR/CCU AOPERF MIRU OS CTU #9 RIH WI POS MEM GR/CCL Log up from 98701 to 9100. ctm. Flag pipe at 97501 ctm. POOH. Good data. 8 ft correction EOP at flag = 9731.31. RIH wI 20' - 2 1/4in HSO PJ2306 6SPF TCP gun. Shoot interval 97601-97801. POOH, all shots fired. RIH lifting w/N2. Lift in segments down to 98401 ctmd (below perfs). Recovered 216 bbls of fluid from wellbore (wellbore vol. = 215 bbls). Continue to lift getting only N2 returns. Shut well in and injected N2. Shut down N2. Surged well to system. Monitor flow to tank. Maintained 700 psi WHP 2 bpm fluid flowback in returns. Took returns to flowline (flowed at 430 psi). After 1.5 hrs put well in test. Well flowing at 3550 bopd, 3.7mm gas and climbing, 1200 GOR, 75 deg F., at 70 deg choke setting. Shut in well. FLUIDS PUMPED BBLS 30 1 % KCL 2500 Gals Nitrogen 6 50/50 Methanal/H2O 2536 TOTAL Page 1 ( ( TREE = GRA Y GEN 2 I I WB..LHEAD = GRA Y 0 7 0 SA SAFETY NOTES: ACTUA. TOR = AXELSON - KB. ELEV = 64' BE ELEV = KOP= 4165' Max Angle = 96 @ 10444' Datum MD = 9736' Datum TVD = 8800' SS tit 2151' 5-1/2" CArv'CO BAL-O SSSV NP, 10 = 4.581" 13-3/8" CSG, 72#, N-80, 10 = 12.347" 2712' Minimum ID =2.80" @ 8998' 8718' 5-1f2" BAKERSLlDlNGSLV, 10=4.313" TOP OF 3-3/16" LNR I I 8804' 5-1f2" BAKER LANDING NIP, 10 = 4.223" 8853' 5-1f2" BAKERSBRASSY, 10= 4.875" 8903' 9-5/8" x 5-112" BAKER SAB PKR, 10 = 4.223" TOP OF 4-1/2" TBG 8915' 8915' 5-1/2" TBG, 17#, L-80, .0232 bpf, D = 4.95" 8915' 8961' 3-314" x 3" BAKER DEPLOY SLV, 10 = 3.000" TOPOF3-1/2"LNRI 8965' 8975' 4-1/2"BAKERNIP,ID=3.759" (BB-IIND 3-1/2" LNR) 3-1/2"LNR,9.3#,L-80,.0087bpf,ID=2.992" 8998' 8998' -i 3-1f2"X3-3/16"XO,D=2.992"j TOPOF 3-3116" LNR 1-1 8998' TOPOF CErvENT 1-1 9024' 4-1/2"TBG,12.6#,L-80,.0152bPf,ID=3.958" I 9036' 9035' 4-1f2"SHEAROUTSLB,ID=4.125" (BEHND 3-3/16" LNR), I 9-518' ŒG, 47#, N-80, ID = 8.681' H 10082' I I I MILLOUT WINOOW - 9610' - 9620' PERFORATION SUMMA RY 9920' CIBP SEr 05/31/03 REF LOG: M8V1 CNL ON 02104/99 ANGLEATTOP ÆRF: 59 @ 9760' FaTD- BAKER LA NOING f\.bte: Refer to A"oduetion DB for historieal perf data OOLLAR, 10 = 2.992" SIZE SPF INTERv' AL Opn/Sqz DA. TE 2-1/4" 6 9760 - 9779 0 07f20/03 10937 BAKER FLOA T SI-OE 2-1/4" 6 9782 - 9802 0 05/31/03 2" 4 10299 - 10576 C 02/05/99 2" 4 10768 - 10907 C 02105/99 10948' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.80" 10937' DATE REV BY COMMENTS DATE REV BY OOMMENTS PRUDI-OEBAY UNIT 01/09/79 ORIGINAL COMPLETION WELL: 07-08A 01/12/99 SIŒTRACK(07-08A) PERMT f\.b: 1982440 05/15/01 RN/TP CORREC1l0NS API f\.b: 50-029-20296-01 05/31/03 SRB/1LP CLOSElN8N PERFS, CIBP SEC 33, T11 N, R14E, 2905.82' ÆL & 4275.96' FN.. 07/20/03 SRB/1LH ADD ÆRFS 09/10/03 CMO/1LP PERFANGLECORREC1l0N BP Exploration (Alaska) WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To~ State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska}, Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM COLOR Open Hole I I 1 Res. Eval. CH I I 1 07-08A 7-20-03 Mech. CH I~-~ ~1 Caliper Survey ProActive Diagnostic Services, Inc., PO Box 1369 Stafford Tx 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog, com Wcbsit¢: www.mcmorylog, com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanon~] Suspendr--~ Operation Shutdown[--~ Perforate[] VadanceE] Annuar Disposal[-'~ After Casing[~ RepairWell[~ Plug Perforations~] Stimulate~] Time Extension E] Other[] Change Approved Program~-'~ Pull Tubing~--~ Perforate New Pool~--'~ Re-enter Suspended Well~] ClBP & ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement · Exploratoryr'~ 198-244 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 StratigraphicF-~ Servicer"~ 50-029-20296-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 07-08A 8. Property Designation: 10. Field/Pool(s): ADL 028309 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10948 feet true vertical 9023 feet Plugs (measured) Set CIBP @ 9920' (05/31/2003) Effective Depth measured 9920 feet Junk (measured) Tagged TD @ 10810' (05/16/2003) true vertical 8949 feet Casing Length Size MD TVD Burst Collapse Conductor 119' 20" 152' 152' 40K 520 Surface 2679' 13-3/8" 2712' 2712' 80K 2670 Intermediate 2577' 9-5/8" 9610' 8781' 80K 4760 Sidetrack Liner 33' 3-1/2" 8965'-8998' 8247'-8276' 80K 10530 Sidetrack Liner 1939' 3-3/16" 8998'-10937' 8276'-9021' 80K ( --- ) Perforation depth: Measured depth: Open Perfs 9782'-9802' .., Open Perfs below CIBP 10299'-10576', 10768'-10907'. True vertical depth: Open Perfs 8889'-8899' Open Perfs below CIBP 9023'-9020', 9016'-9018'. Tubing: (size, grade, and measured depth) 5-1/2" lZ# U 0TBG x4-1/ " 4-1/2" 12.6# L-80 TBG @ 9036'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BKR SAB PKR @ 8903'.JUN ! (; 2003 5-1/2" CAMCO BAL-O SSSV Nipple @ 21[l~'..ka_.__ 0i~ & 12. Stimulation or cement squeeze summary: A~ch0ra~e Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Exploratoryr"l Development~ Service[--~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oil· CasE] WAGE] G~NJE] WINJE] WDSPLE] Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeWayne R. Schnorr Title Techical Assistant Signature ~"~~ ~J~ ~ r.,t i/,-~ j kj°~/~n1. 907/564-5174 Date June 04, 2003 '- ' "- I IKiI~ Form 10-404 Revised 2/2003 07-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/16/2003 PACKERS/BRIDGE PLUGS/POGLMS: FILL CLEAN OUT 05/21/2003 PACKERS/BRIDGE PLUGS/POGLMS' DRIFT/TAG 05/23/2003 ANN-COMM (AC-EVAL AND REPAIR)' AC-FLUID LEVEL 05/28/2003 PACKERS/BRIDGE PLUGS/POGLMS' CEMENT BOND LOG--SCMT/USIT 05/31/2003 PACKERS/BRIDGE PLUGS/POGLMS' CAST IRON BRIDGE PLUG; PERFORATING EVENT SUMMARY 05/16/03 MIRU CTU # 5. RIH W/2.1" JS NOZZLE. CIRC HOLE @ MIN RATE FROM SURFACE. TAG TD @ 10810' (2350' BELOW ESTIMATED TOP OF CACO3). CHASE 5 BBL FLO-PRO SWEEP FROM 9900' TO SURFACE @ 80%. LOSING RETURNS 3:1 AT 3000'. FREEZE PROTECT TO 2500' W/50/50 METH. RDMO 05/21/03 *** WELL SI UPON ARRIVAL*** D & T TO DEV (PRE CIBP/ADPERF) W/2.5 D- GUN & S-BLR TO 9624' WLM. STOPPED DUE TO DEV OR DLS 196' SHORT OF TARGET DEPTH (9820' MD) ***LEFT WELL SI*** 05/23/03 T/I/O = 10/20/5. MONITOR WHP's AND TBFG FL (PREP FOR E-LINE). TBG FL NEAR SURFACE. 05/28/O3 RAN SCMT. CORRELATED TO SWS MCNL 2/4/99. TOOL RUN TO 10120 BEFORE STOPPING DUE TO DEVIATION. LOGGED INTERVAL 8966-10120 FT. ESTIMATE TOC @ 9012' MD (FIELD PICK). LINER TOP @ 8966. TD NOT TAGGED. ***WELL LEFT SI*** 05/31/03 NO GO ON LINER TOP FOR DEPTH CONTROL/SET CIBP/ADPERF--MIRU DS CTU #9/RIH W/3.5" NOZZLE. TAG LINER TOP @ 8989' CTMD - 23' = 8966' CORRECTED. EOP = 8963.5'. POOH. RIH WITH BAKER HYD SETTING TOOL AND 3-3/16" CIBP. CORRECT TO CENTER OF CIBP AT FLAG (8975.4'). SET CIBP @ 9920'. POOH. RIH W/20' - SWS 2-1/4" PJ HSD 2306 HMX @ 6 SPF / 60 DEGREE PHASING. TAG CIBP AND CORRECT DEPTH TO BOTTOM SHOT. PUH TO BOTTOM SHOT DEPTH @ 9802'. POOH. ALL SHOTS FIRED. RBIH WITH 2-1/4" JSN. FP WELL FROM 2250' WITH 50/50 METHANOL WHILE POOH. RD DS CTU #9. WELL TO REMAIN SI UNTIL TEST SEPARATOR IS AVAILABLE. <<< JOB COMPLETE >>> FLUIDS PUMPED BBLS 149 METHANOL WATER 101 50/50 METHANOL WATER 56 2% KCL WATER 425 1% EXTRA SLICK KCL WATER 731 TOTAL Page 1 07-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 05/31/2003 THE FOLLOWING INTERVAL WAS PERFORATED WITH 2-1/4" HSD HMX POWER JET 2306 @ 6 SPF, 60 DEGREE PHASING, AND RANDOM ORIENTATION. 9782'-9802' Page 2 bp RECEIVED AUG 1 5 7.001 Alaska Oil & Gas Cons. Commission Anchorage August 15, 2001 Mr. Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7 th Avenue, Suite 100 Anchorage, Alaska 99501 - 3539 Re: Recommendations Stemming From February 19, 2001 Incident at DS7-8a Dear Tom: This memo is in response to an email I received from Tom Maunder last week regarding the subject incident. In a follow-up conversation, Tom indicated that a review of the recommendations stemming from the incident investigation would be helpful in resolving some outstanding questions the Commission has. The DS7-8a incident investigation team made some recommendations in the areas of erosion / velocity management, use of coiled tubing velocity strings, assessment of local emergency well kill procedure for rapid deployment, and the GPB emergency response process / plan. Details of the pertinent recommendations follow: Recommendation - Modify existing procedures and methods to enhance effectiveness of erosion management programs including well startup and well flow / sand monitoring. Ensure direct communication between CIC and Operations. Final goal will be to have a common GPB velocity / erosion measurement and management program. MOC process should incorporate velocity / erosion issues in surface piping modifications. Consider impingement, solids, restrictions, etc. o Recommendation Status - A draft of the velocity / erosion measurement and management procedure has now been submitted to the GPB Operations Managers for review prior to implementation. · Recommendation - Review recommendations from recent erosion incidents in GPB. Identify applicable outstanding recommendations and implement necessary remedial measures. o Recommendation Status- Procedure mentioned above is ensuring all pertinent erosion / corrosion related recommendations are being addressed on a fieldwide level. · Recommendation - Use downhole completion coiled tubing string as originally designed. No annular flow for continuous operations. Well completion designs and wellwork plans should consider erosion and corrosion with appropriate procedures put in place to ensure this analysis takes place. Recommendation Status - Regarding this recommendation, the wells with coiled tubing velocity strings (DS7-Sa and DS 18-04a) have had these strings removed. The Sundrys reflecting the completion of this work are attachments 1 and 2 respectively. There are no other wells at a Greater Pmdhoe Bay field completed in a manner similar to DS7-8a's completion prior to the subject incident.. If you have further questions on this subject, please feel free to contact me, 564-4580 or via email (seymouli @bp.com). GPB Town Operations Manager Cc: R. Jacobsen (BPXA Legal Counsel) S. Rossberg RECEIVED AUG 1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X (AL String Removal) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1213' FNL, 166' FEL, Sec. 33, T11N, R14E, UM At top of productive interval 4063' FNL, 3782' FEL, Sec. 27, T11N, R14E, UM At effective depth At total depth 4276' FNL, 2906' FEL, Sec. 27, T11N, R14E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic_ Service__ (asp's 676036, 5949706) (asp's 677637, 5952174) (asp's 678517, 5951984) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 07-08A 9. Permit number / approval number 198-244 10. APl number 50-029-20296-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10948 feet Plugs (measured) 9023 feet Effective depth: measured $925 feet Junk (measured) true vertical 8213 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 119' 20" 271 sx AS 119' 119' Surface 2648' 13-3/8" 3700 Sx AS ~ 2712' 2712' Production 9546' 9-5/8" 1200 Sx Class G 961 0' 8781' Liner 1987' 3-3/16" 20.5 bbls 15.8 ppg LARC 10948' 9023' RECEIVED Perforation depth: measured 10299'- 10576'; 10768'- 10907'. J~U[~ .~ 5 ~001 Alaska 0il & Gas Cons. Commission true vertical 9023' - 9020'; 9016' - 9017'. Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 Tbg @ 8915' MD; 4-1/2", 12.6#, L-80 Tbg @ 9036' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8903' MD. 5-1/2" CAMCO BAL-O SSSV @ 2151' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation(2/14~2001) Subsequent to operation OiI-Bbl 577 (shut in) Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 15781 311 Casing Pressure Tubing Pressure - 401 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._.X 16. Status of well classification as: Oil _X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title: DS 7 Surveillance Engineer Bob Gerik Date July 5. 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07-08A DESCRIPTION OF WORK COMPLETED AL COILIED TUBING STRING REMOVAL Date Event Summary 2/19/2001' 2/20/2001' 2/21/2001' 2/26/2001' 4/04/2001: 4/13/2001: 4/14/2001' 4/15/2001' 4/16/2001: 5/19/2001' Well 07-08A was sidetracked in early 1999 and completed as a Zone 1 horizontal well without gas lift. It initially came on line at 1500 BOPD and 2500 GOR, but within 2 weeks it began slugging and died. In August of 1999, a 6800' long string of milled out 2-3/8" coiled tubing was run in the well to allow gas lifting until formation gas increased enough for the well to flow on its own. A 5000# FMC 5 x7 coil tubing head spool piece was installed in the tree just below the master valve. The AL coil string was hung off this tubing head using a 5" FMC tubing hanger (5-1/8" OD). A Weatherford PT nipple (1.50" minimum ID) and WLEG were run on the lower end of the coil string to allow a 1-1/2" pump through plug (1.553" OD) to be used during installation and removal. The coil string was hanging free from the hanger. The gate valve connected to the 2" side port on the tbg head spool piece eroded and leaked. The well was killed, the valve removed, and the side port blinded. FP'd flowline & 2-3/8" CT String w/150 bbls of 60/40 Methanol Water. Well on vacuum. MIRU. Pumped 117 bbls of 60/40 Methanol Water down the IIA. Pumped 17 bbls of 60/40 Methanol Water down the tubing, then swapped to 15 bbls of Diesel, followed by S/D. Valve crew installed a 2nd IIA valve. PT'd valve to 5000 psi. RU DS pump to IIA valve. PT'd equip. Pumped 250 bbls of Inhibited KCI Water, followed by 18 bbls of Visc KCI Brine, followed by 38 bbls of 35 ppb CaCO3 pill, followed by 10 bbls of Visc KCI Brine, followed by 70 bbls KCI water. 'Pumped 44 bbls of Diesel, followed by 22 bbls 2% KCI water, then swapped to 13.5 bbls of 60/40 Methanol Water, followed by S/D. RD. RIH &drifted to 6810' SLM. RIH & set a 1-1/2" PE Plug in PT Nipple @ 6810'. Ran 4-1/2" LIB to tubing hanger. PPPOT-CT to 1000 psi- passed. PPPOT-T to 5000 psi- passed. MIRU CTU & Work Platform. PT BOPE. Held safety meeting. Loaded well w/60/40 Methanol Water. RIH w/HYD GS & latched velocity string. Unseated tubing hanger. PU, cut, & spliced the 2- 3/8" CT. POOH w/velocity string. FP'd well. RD. Ran PDS Caliper log f/8925' SLM to surface. This well is presently shut in & future wellwork options are being evaluated. 07-08A is currently uncompetitive due to high GOR & is being considered as a ST candidate. RECEIVED AUG 1 5 2001 Page 1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPI:::RATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1065' FNL, 189' FEL, Sec. 24, T11N, R14E, UM At top of productive interval 3184' FNL, 1416' FEL, Sec. 24, T11N, R14E, UM At effective depth At total depth 3021' FNL, 4876' FEL, Sec. 24, T11N, R14E, UM 5. Type of Well: Development _X Exploratory_ Stratigraphic__ Service_ (asp's 691572, 5960796) (asp's 690401, 5958649) (asp's 686937, 5958724) 6. Datum elevation (DF or KB feet) RKB 56 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-04A 9. Permit number / approval number 198-028 10. APl number 50-029-20875-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11233 feet 8878 feet Plugs (measured) Effective depth: measured 11148 feet true vertical 8869 feet Casing Length Size Conductor 80' 20" Surface 2573' 13-3/8" Production 9673' 9-5/8" Liner 654' 7" Liner 1928' 2-7/8" Junk (measured) Cemented 1850# Poleset 2640 Sx Fondu / 400 Sx PFC 500 Sx Class G & 300 Sx PFC 288 Sx Class G 13 bbls 15.8 ppg Neat Class G Perforation depth: measured 10485' - 10795'; 10885' -11150'. true vertical 8798'- 8851'; 8852' - 8869'. Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80 Tbg @ 9477' MD. Measured Depth 80' 2629' 9729' 10077' 11227' True Vertical Depth 80' 2641' 8349' 8694' 8878' RECEIVED AUG 1 5 Z001 Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) 4-1/2" Baker PBR Packer @ 9351' MD; 9-5/8" x 4-1/2" Baker SAB Packer @ 9368' MD. 4-1/2 CAMCO BAL-O-SSSV @ 2204' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure (see attached) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl (Shut in since March 12000) (Shut in) Cas ng Pressure Tubing Pressure 15. Attachments I 16. Status of well classification as: I Copies of Logs and Surveys run __ Daily Report of Well Operations _X Oil __X Gas _ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Al Schmoyer Al Schmoyer Title: DS 18 Surveillance Engineer Date 4/25/2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 18-04A DESCRIPTION OF WORK COMPLETED AL COIL TUBING STRING REMOVAL RECEI\' ..... ,.., AUG !' Alaska Oil & Gs:. Cons. Commission Anchorage Date Event Summary 4102/2001: 410312001: 4~08~2001: 410912001: 411012001: 411112001: 4112/2001: Well 18-04A was sidetracked in May of 1998 and completed as a Zone I horizontal well without gas lift. The well did not flow. A Hydraulic Fracture Treatment was performed in September of 1998 after which it would flow only with nitrogen. An 8400' long string of 2-3/8" coiled tubing was run in the well in August 1999 to allow gas lifting until FM gas increased enough for the well to flow on its own. A 5000# FMC 5 x7 coil tubing head spool piece was first installed in the tree just below the master valve. The AL coil string was hung off this tubing head using a 5" FMC tubing hanger. The tubing hanger has a 4-1/2" G fishing neck on the top looking up. A Weatherford PT nipple & WLEG were run on the lower end of the coil string to allow a 1-1/4" pump though plug to be used during installation & removal. The coil string is hanging free from the hanger and is not attached at the BTM (8430'). Unfortunately the well was unstable, repeatedly plugged off with paraffin, and produced only intermittently on gas lift. It has been shut in since March 2000. A CT ST is planned for late 2001. The 8400' AL coil string removal is described below: Performed Hot Oil Treatment (to clear paraffin plug in the 2-3/8"x 4-112" annulus for future extraction of the 2-3/8"AL Coil string) as follows: MIRU CTU. Tested BOPE. RIH w/1-1/2" CT & pumped a total of 706 bbls of 170° F Crude, 45 bbIs Hot Diesel, 11 bbls Diesel / Xylene, 5 bbls Neat Methanol. Successful removed paraffin plug f/the 2-3/8" x 4-1/2" annulus. POOH w/CT. RD. RIH w/slickline & set a Weatherford 1-1/2" PE Plug in PT Nipple @ 8436'. MIRU service CTU & Work Platform. Commenced BOPE test. Completed BOPE test. PU Baker BHA & Lubdcator. Killed well w/1% KCL Water. Spotted 24 bbl FIo Pro Pill. Checked well for flow - flowed back Diesel. Attempted several times to sting into tubing hanger fishing neck - all attempts were unsuccessful. Opened well & monitored it for flow. Pumped water down IA. RU slickline. RIH w/LIB & spangs to top of CT fishing neck in tubing hanger. POOH w/information on damaged G fishing neck. Ran 5" overshot w/tattle tail pins on inside. Appears that overshot swallowed 7" - 8" over the top of the fishing neck. RD SLU. FP'd well. Ran special swaging tool on top of bent AL coil stdng GS fishing neck until clear for a back press valve to be set. Set Cameron 2" BPV. ND BQP's. Removed damaged fishing neck. MU 2-3~8" pup joints w/TIW Valve in tubing hanger. NU & PT'd BOP's. MU CTC to top pup joint. PUH to place hanger @ floor. RD pup joints, MU to hanger, & pull AL coil string into lubricator. Hot tap, cut velocity string, & MU spoolable connector. POOH. Coil parted above injector. Laid pipe to back deck. Stdpped off injector & re-stabbed pipe. Dressed pipe for another attempt. Page 1 18-04A DESCRIPTION OF WORK COMPLETED AL COIL TUBING STRING REMOVAL Date Event Summary 4113/2001' MU to AL coil string. Stripped over w/injector & POOH. Spooled 2-3/8" AL coil string onto reel. Closed master. FP'd to 3600'. Left well shut in. Well is currently shut in. In the future, this well will be CT sidetracked. RECE" AUG 1 5 2001 Alaska Oil & Gas Cons. Commission Anchorage Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Per/orate _ Pull tubing _ Alter casing _ Repair well _ Other _X (AL String Removal) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1213' FNL, 166' FEL, Sec. 33, T11N, R14E, UM At top of productive interval 4063' FNL, 3782' FEL, Sec. 27, T11N, R14E, UM At effective depth At total depth 4276' FNL, 2906' FEL, Sec. 27, T11 N, R14E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic__ Service__ (asp's 676036, 5949706) (asp's 677637, 5952174) (asp's 678517, 5951984) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 07-08A 9. Permit number / approval number 198-244 10. APl number 50-029-20296-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 119' Surface 2648' Production 9546' Liner 1987' 10948 feet 9023 feet 8925 feet 8213 feet Size Cemented 20" 271 Sx AS 1 3-3/8" 3700 sx AS II 9-5/8" 12oo Sx Class G 3-3/16" 2o.5 bbls 15.8 ppg LARC Plugs (measured) Junk (measured) Measured Depth 119' 2712' 9610' 10948' True Vertical Depth 119' 2712' 8781' 9023' Perforation depth: measured 10299'- 10576'; 10768'- 10907'. true vertical 9023' - 9020'; 9016' - 9017'. Tubing (size, grade, and measured depth) 5.1/2", 17#, L-80 Tbg @ 8915' MD; 4-1/2", 12.6#, L-80 Tbg @ 9036' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8903' MD. 5-1/2" CAMCO BAL-O SSSV @ 2151' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation(2~14~2001) Subsequent to operation OiI-Bbl 577 (shut in) Representative Daily Avera.qe Production or Iniection Data Gas-Md Water-Bbl 1578~ 311 Casing Pressure Tubing Pressure - 401 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~ ~ Title: DS 7 Surveillance Engineer Bob Gerik Date July 5, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07-08A DESCRIPTION OF WORK COMPLETED AL COILIED TUBING STRING REMOVAL Date Event Summary 2/19/2001: 2/20/2001: 2/21/2001: 2/26/2001: 4/04/2001: 4/13/2001: 4/14/2001: 4/15/2001: 4/16/2001: 5/19/2001: Well 07-08A was sidetracked in early 1999 and completed as a Zone 1 horizontal well without gas lift. It initially came on line at 1500 BOPD and 2500 GOR, but within 2 weeks it began slugging and died. In August of 1999, a 6800' long string of milled out 2-3/8" coiled tubing was run in the well to allow gas lifting until formation gas increased enough for the well to flow on its own. A 5000# FMC 5 x7 coil tubing head spool piece was installed in the tree just below the master valve. The AL coil string was hung off this tubing head using a 5" FMC tubing hanger (5-1/8" OD). A Weatherford PT nipple (1.50" minimum ID) and WLEG were run on the lower end of the coil string to allow a 1-1/2" pump through plug (1.553" OD) to be used during installation and removal. The coil string was hanging free from the hanger. The gate valve connected to the 2" side port on the tbg head spool piece eroded and leaked. The well was killed, the valve removed, and the side port blinded. FP'd flowline & 2-3/8" CT String w/150 bbls of 60/40 Methanol Water. Well on vacuum. MIRU. Pumped 117 bbls of 60/40 Methanol Water down the IIA. Pumped 17 bbls of 60/40 Methanol Water down the tubing, then swapped to 15 bbls of Diesel, followed by S/D. Valve crew installed a 2nd IIA valve. PT'd valve to 5000 psi. RU DS pump to IIA valve. PT'd equip. Pumped 250 bbls of Inhibited KCI Water, followed by 18 bbls of Visc KCI Brine, followed by 38 bbls of 35 ppb CaCO3 pill, followed by 10 bbls of Visc KCI Brine, followed by 70 bbls KCI water. Pumped 44 bbls of Diesel, followed by 22 bbls 2% KCI water, then swapped to 13.5 bbls of 60/40 Methanol Water, followed by S/D. RD. RIH & drifted to 6810' SLM. RIH & set a 1-1/2" PE Plug in PT Nipple @ 6810'. Ran 4-1/2" LIB to tubing hanger. PPPOT-CT to 1000 psi- passed. PPPOT-T to 5000 psi- passed. MIRU CTU & Work Platform. PT BOPE. Held safety meeting. Loaded well w/60/40 Methanol Water. RIH w/HYD GS & latched velocity string. Unseated tubing hanger. PU, cut, & spliced the 2- 3/8" CT. POOH w/velocity string. FP'd well. RD. Ran PDS Caliper log f/8925' SLM to surface. This well is presently shut in & future wellwork options are being evaluated. 07-08A is currently uncompetitive due to high GOR & is being considered as a ST candidate. Page 1 TF~E= GRAY GEN 2 ~ SAFETY NOTES WELLHEAD= GRAY 07 08A A Cq'UATOR= AxELsoN "' . KB. ELEV = 64' BF. ELEV = KOP = 4165' Max Angle= 96 (~ !0444'l Datum MD = 9736'I , I ~'~" cs~. ,~, N-~,o, ,,:,: 12.347" H 2712' ~ k ID :4.581" Minimum ID=,,2.80"@8998' ~---J ~?~' I--[ 5-1/2" BAKER SLIDING SLV, ID=4.313"I TOP OF 3-3/16 LNR J J I I--t s804' I--t 5'1/2""A"E"'AN~N~N'""D--4'223" I ~ ~ ~-I 8853' I"--J 5-1,2" BAKER SBR ASSY, D :4.875"I ~---~ 8903' J'--j 9-5/8"X5-1/2"BAKERSABPKR, ID=4.223"I J 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.95" j ----t 8961' I--I 3.75" X 3" BAKER DEPLOY SLV, ID:3.000" J IT°P°F3-1/2''LNRI--t8965' f j '---t 8975' I"'-~ 4-1,2" BAKER NPPLE (BEHIND 3-1/2" LNR), / ID: 3.759 J 3-1i2"LNR, 9.3#,L-BO,.OOBTbpf, ID=2.992" J--J 8998' -'1 '-- --I ~s' I-t 3-1'2"X 3-3/16"XO, ID: 2.992"I JTOPOF 3-3/16"LNR J----[ 8998' ' / ITOPOFC:EMENT I--t 9024' ~ , 9035' 4 1/2 SHEAROUT SUB (BEHIND 3-3/16 LNR) ;: 1--1 '" "' I I __ . J 9-5/8" cse, 47#, N-80, ID = 8.681" J~l 10082' -- ~ <~' ;~ I ..... ' __~--'-- __ ~ ~X,. '~'~ MILLOUT WINDOW- 9610'- 9620' J PERFORATION SUMMA RY RB= LOG: MEM CNL on 02/04/99 ANGLEATTOPPERF: 87@ 10299' x) ~ ,. % __ Note: Refer to Production DBforhislorical perf data ~ ~ ~ ~ ~-~-"'-~-E~AKERLAN~--~ SIZE SPF INTERVAL Opn/Sqz DATE X I 2" 4 10299-10576 0 02/05/99 2" 4 10768-10907 0 i 02/05/99 ~ ~: ~ k %"~.~'~ . ., .... ~ ~ lO~37 I1BAKERF'OATS"OE 1~3/16" LN~, 6.2#, L-B0,.0076b¢, ,D= 2.~0" H ~0~' i DATE . REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/09/79 ORIGNAL COMPLETION WRL: 07-08A 12/07/00 SIS-MD CONVERTED TO CANVAS PERMITNo: 98-244 02/15/01 SIS-MD FINAL APINo: 50-029-20296-01 01/12/99 SIDETRACK SEC 33 T11N R14E2905.82 FEL 4275.96 FNL 05/15/01 RNfrP CORRECTIONS ! BP Exploration (Alaska) SIZE SPF INTERV A L Op n/Sqz DATE 2" 4 10299-10576 O 02~05~99 2" 4 10768-10907 O 02/05/99 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/09/79 ORIG NA L COMPLETION 12/07/00 SIS-MD CONVERTED TO CANVAS 02/15/01 SIS-MD FINAL 01/12/99 SIDETRACK 05/15/01 RNfrP CORRECTIONS Table 1.0 Drill Site 7 Incident Timeline Date Event Critical Factor 1/99 Coil tubing sidetrack was completed 2/17/99 N2- FCO 3/8/99 Drain valve erosion @ DS-7 manifold 3/28/99 N2-FCO 3/99 Choke replaced on 7-8- erosion 6/99 Prepared program to install coiled tubing in the well; X expected to be used 6-9 months and removed 8/99 FMC C.T.H.S was installed X 9/7/99 Flow changed from tubing to annular flow X 10/99 Hot oil wash for rate 11/99 Slickline drift/tag for rate 2/00 Well line inspection showed damage 9/15/00 Tubing displacement. Corrosion treatment 9/16/00 Erosion in downcomer (8" where 2" came in at 90 deg) 10/16/00 Surface Piping was designed with annular flow considered 10/16/00 Brought on line with new 3" flow line, no AL 1/26/01 Inspection of choke showed 0.05" loss but enough metal left for strength. 1232 on 2/19/01 Choked 7-8 back du o r'sing/~emperature X 2/19/01 DS OPERATOR DISCOVER~ 7-8 OIL/GAS LEAK AT LEAK APPROXIMATELY 1915 DISCOVERED 2/19/01 Shut SSV X 1942 on 2/19/01 Fire Dept on pad, IMT established at PBOC 1948 on 2/19/01 Operator depressures 7-8 by shutting SSV and depressuring 7-8 to manifold building 1948 on 2/19/01 Depressured to LP then to 0 psig 1955 on 2/19/01 Preparing for 7-8 entry 2020 on 2/19/01 Thought SSV did not close because leak persisted 2100 on 2/19/00 ADEC notified by IMT 2107 on 2/19/01 Decision made to enter wellhouse 2/19/01 Dowell contacted to "Kill" well 2/19/01 After 90 bbls, pressure went to 2500 psig. Indicating SSV was closed. Flow line volume 92 barrels. 2127 on 2/19/01 Entered wellhouse to close manual valve, saw leak and left 2200 on 2/19/01 IGV and test separator closed 2200 on 2/19/01 Wells Team activated in Anchorage to support Incident Response 2/19/01 After dry rehersal;, tried to open SSV. Second attempt succeeded 2/19/01 Setting up to flow water back to wellbore Date Event Critical Factor 2/19/01 Opened SSV via pick up hydraulic unit 0015 on 2/20/01 Started pumping 0200 on 2/19/01 Hooked up to hydraulic panel, well to test sep and depressured to 1300 # and S/I . .0343 on 2/20/01 Pumping 5 bbls @ 19504/ .._0432 on 2/20/01 Leak identified as FMC valve upstream of SSV 0500 on 2/20/01 Patched isolation valve with clamp 0500 on 2/20/01 Pump rate reduced X 2/20/01 Depressured and readjusted patch 2/20/01 Routed vent hoses to spicer tank 2/20/01 Depressured CT to well next door 1600 on 2/20/01 Pumped kill pill and then brine. Killed well 2/20/01 Monitored for "no flow" test to verify well killed, 1-1/2 hours "'2345 on 2/20/01 Removed valve and installed blind flange on coiled tubing hanger spool and completed well control 1000 on 2/21/01 Investigation Initiated 04/04- 04/16/01 Remove coiled tubing velocity string, set DH plug 07-08A Coiled Tubing AL String Surface Details Com Swab 1' High Pressure Hose From Gas Lift Source SSV FMC Coiled Tubing Hanger See attached drawings for coiled tubing head and hanger details 5x7 FMC Coiled Tubing Head With 2" Side Outlet 6,800' of Used ~ Ooil 4 1/2" Production Tubing 9 5/8' Casing Wire Downcomer The FMC 5x7 Coiled Tubing Head Spool Replaces the Existing Master Valve Production Down Flowline 2" Coiled Tubing Head Side Production Outlet Run hardline from 2" side outlet to Cosasco fiffing Coiled Tubinq Head Details 2 3/8" EUE Pin x 4 1/2' GS FMC Coiled Tubing Hanger 2 3/8" EUE Box Both Ends 1 3/4" Coil Connector with 2 3/8' EUE Pin Top 6,800' of Used-l.,a~' Coiled Tubing Figure 1.2.2 Well Head Diagram Wellhead Equipment Division Tree Drawing Date: 8/28/99 Rig:_. CTU #4 Well Number: D~;7-08 Tree Bore: 5 1/8' 7 '1/16' 5M FLG. 13 5f8' 5M FLG. 2.41' .' GRAY 1,15' GPBU Drill Site 7 Well 8 Gas/Oil Leak LCIR No. 2001-LCIR-23994 N 100% by RT Leak area i ii · iiii illl ii ii[i i ii 111 BP Explora[io Corrosion Group Drillsite 7 Downeomer ,q ~'n-I' ~'m h r~'t" qualitative Inspection Resul[s Ranki,ng Key = W~II ~s < ~ and C~ ~ 105~ of the S~em O~lgn Pretests, ~ ~ Lose Well 8 Damage. Summary Pa .9, NNN hv' TMM BP -Explora[~ o Corrosion Group' · Drilisite 7 Well . DOWlicomer · February. 20, 2001 by: TMM N 100% by RT Leak area 3.9 I i I I i --i llalll i P Explora[i on Corrosion Grou~ Drillsite 7 Downcomer . ...... qualitative Inspection Results Ranking geD[. , ~gn ~ ~ We~ Lee, ~ ~.~:o~ < ~, o~ C~ ~ 100~ ~d < t05~ ~ = 'N~II ~S · BO~ or ~P~ < S~tem. Od~lgn Pr~u~e. I I I [ I I Well 8 Damage. Summary 9NNN h~7' TM~4 BP Explora[ion Corrosion _Group' Drillsite 7 Well '8 DowIlCOlIl. er February 2.0, 2001. by: TMM L~ SENT BY:B P Envir0nmen~al ; 7- 8- 1 ; 113'02 ; B P Entvir0nmen~al, 907 864 5000;#11/15 ?-03eP, 01A~1 Non-Emergency Spill Report Notittcnttou ~...-- ~t_~ O~ { 26~0: WOA ~37~ page I~ ~e spill comla~ to ~,l~e?.'T~,,,:Y,.ei _.. r,, Is spill ~bout to tr~v~.t off s ~~ or ma~?~ Re,rd ~o~m~e~, ~b~ spill i~~~ b~w: . P~se n~-~'alt ~f~don b~ ~ ~ce;~ f~ ~cy ~~g, pl~ss provide co~le~ Company (~UBPX ~T!rdP~)t. ~?~ .. ~ ..... . ............... - ...... 5npe~lsor's Name: _~~~ ~~~'~._ : ................. . .... - ...' Loeatlonl~aciltW (iuclu~ molule ~s.): ~ ~ ,~ .. ' L Voi.~ Total (~t.ns):. ,.~ ~ _~- ~_~.,.... '"i~~ AAI - Fax to XlF22g & 8167 BPX- Fax to x4174 and [AAI ~as belu~) (BPX ~ O Prndho~A Pmdao~OA Pt. Mac I & 2 81128 816~ Ntmk~* 4174 ~, Desdhorse ~ ~ · Drill~t* Offpad (pond, river, icc, snoW, icc road): .... , ..... _ . ....... ... _ .... ._. _ Ir'ilo Seconda.,'y conTaJl~an! (drip p~, 9~m Spill Su~aee Area (u~ate.): ~. . Sonree (t~ w~l, pipc~, ,e~clc nos.?): DisposaU~us~~e Ioea~o~: . . .... If n~ ~nse. call F~C Complete Ih~ ~ and fix to ~ or BPX bmsed on I~oatia~ of spdl,. ~d ree~rO ~m~..Ju b~x~s bdo~ 4467 *All Niakuk and Drilling spills on lhe I~OA - Fax form to BPX m X41 74, x4467 ~d xo I~C ~tx$2ls SENT BY:B P Environmen:al Ptt~tat: ogFz.V3000 Page-' 1 7- 8- 1 ; 18:00 ; B P Entvlronmon:al~ BP l~ploration, Inc. Easteru Operating Area Prudhog Bay/GPMA, Phonc: (~07) 659.82'/0 Final Agenoy Report LOCATION OF DISCItARGE: D$7 ADDITIONAL LOCATION INFO. Ddllsite 7 W'dl 8 907 564 5000;# 2/15 TIME OBSERVED: REPORT'ED TO: RiiSPON$IBLR GROUP: TYPE AND AMOUNT: CAU$I~ OP DJ.~CI-1ARGEt 7:~;00 AM 0911 rd2000 BII2, DAWLJBY ADEC: 9t 16/00 Verbal ADNE: g/l 6/00 verbl~l NSB: 9/16/013 ¥~bal Otlmr: AOOCC 9/!~ Verbal BP ~w~PLORATION EQUIPMENT DIFPlCULTY ArtificJnl m~ lift: lln~ rupture. Apparent corrosion it, fJ0wlin¢ from well caused pto tiole l~k;-spmyt~g instd~ oF welll~use and a p~rtioo of ~c pid. ENVIRONMENTAL DAMAGE,' None, thc .spill w~$ cnutained on thc grav~l pad. CL~ANL~ ACTIONS: CL~UP VERIFICATION; AMOUNT OP SPILL I~COYERitD: PKI~VENTIVE ACTION: clump b~ was us~ ~ d~ up tho pad. Thc ~i~ w~l~ Oft~ wzllhoua~ w~e pro~U~WaSh~ m~d wJ~d down. The cont~inat~ gavel around the wetlhao,~e was ~g0v~d wltk a sup~u~kct. VlaU~ Replace & repair line DiSPOSAL/RECYCLE LOCA'I'ION: Otl~r The material w,~ dtapc~xt ofa~ pacl 3 m~d G~/I. 90:Z£ I~-t0-1 hi' SENT BY:B P Environmental · .'D ; 7- 8- 1 ; 12:50 ; B P Entvlronmen~al~ 007 564 5000;# 1/15 PAl AND PAl CONTRACTOR SPILL REPORT I~.. ALp. IN.E ~.B_ELUQA 1:3 EXPLORATIC)N ~ANCHORA~IE ....,',,, ::... ,... .j~-~ONE., .. · , ~- . ..... ._:. ' ..'..., .... ' , , .~:;': · ~ 65~;~41 ..... r'tOTHER · '.'~ .C_ , ,, ',-~ ' Opemtione TIME · '. : Crude YES __ VO LU ME --.----_ YES __ VOLUME ------. VOLUME, off Pad? Iht= i Building? Int= Lined lleeondo~/Centalnrnenl~_ YES =: Coiled TUbing/Unit/Wh"eline ~quip ~ Fiang~ Compre~r Vent~M~ule Ven~ ~ Ftys D~m~Oo,tainemtDump~ers ~ Pumps P~ting~al~Gonnactbns 0 sumps gl Constm;tlon/Pmje~ ~1 Drift ,,~lTg Mainlenance ,~ Fluid Transfer/TranspOrt 1;I iJmdu~tionlFadlily M~nt Cps Q Road Pad Malnt Drilling Hydmte~ting Rued Travel W~reline Worl< Othe rAJnlmlown ~ P~oced~r~ ~ Management System O Training ~ Human Engineering Q Quali~ Control ~ immedl~m Supe~lllon Q Heavy Equip/Mobile Equip/Vehl;taa Q 'Ter~ks l;;I Communlcaaona Q Nat. Phenomeno~ab~ge _ : ~ .... ~ ~ UnknoWn ~._~Flowllne~H~llnaa Q Tmnsfer.~.oses _ ~ E~igment Dl~loulty . ,- ~ .... :B~A~LED'~PbAN~TION OF ........... ROO~.~BE" .. ,,, ' '-- ,. ,"__ -,.: .... - -- ~' "" .......... ,; ..... ;--_L:' "" Erosion of pipe due ~ high pressu~ ~ificlal lift ~mam. PA~troups~Envlrenments]~ORMS\SpflI.GI;s Rc=~aottlng Forme'~plll forma-info~,~plll Report Form elf. Jan gg (Revised I~ EXPLORATION INC. Loss Control Investigation Report Report Printed: 0612812001 PERSONAL INJURY INCIDENT i"-Nature of Incident' 1 Spill, Process i-Nature of Damage Corrosion/Erosion RESPONSIBLE ASSET f~sset -----[ Field PB PBU-EOA SG~--t-6m Involved .................... -~E-q-uTpment Involved as Lift at Well Pads Wellhead Company Material Name Department Sub Department Operations Production (Field) ...... i-Gal/Lbs ~80 i Est CSs-t--------~ INCIDENT LOCATION Asset --- Field GPB PBU-EOA Location Drill Site 07 ROOT CAUSE ANALYSIS Causal Factor Basic Cause Equipment Difficulty Unexpected Failure Contributing Cause Unexpected Failure Root Cause Desciption Erosion of pipe due to high pressure artificial lift stream Root-Cause Unexpected Failure LClR DETAILS -ECIR Number Occurence Dat~ lime Reference 2000-LCIR-16016 09/16/2000 06:00:00 9/17~00 Event Description ~ Well 7-8 had completed a tubing displacement- corrosion treatment downhole the day before the incident (9/15). Investigation is in process to determine the nature of the leak and subsequent spill. Update 9/18/00- Wellhouse was steamcleaned to allow inspection of the wellhead. Visual examination revealed a pencil-sized hole eroded in the flowline, inside the wellhouse, directly opposite of the Cosaco flange (corrosion probe). The corrosion coupon had been removed to install annular production string. ACTION ITEM Action Item ~t Priorit~ .... Responsible party r-Work Order 43256 2 Medium GPB, Flow Station 3 Supervisor Description Initiate incident investigation to determine nature of wellhead spill. To be completed by 9/18. Update 9/18/00- Investigation revealed an eroded hole in the flowline directly opposite of the annular production string. High velocity erosion occurred. Target Date 09/18/00 Risk Rank El, 09/18/00 Comments Incident root cause determined. ACTION ITEM Action Item ~ Priority 43272 2 Medium -Description Responsible Party t Work Order GPB, Flow Station 3 Supervisor Freeze protect flowline Target Date Date Completed 09/18/00 09/18/00 ---Comments Freeze protect completed on 7-8 flowline. ACTION ITEM -Action Item ~ Priority 43273 1 High Description Safeout well. Kill well. Responsible Party Work Order GPB, Flow Station 3 Supervisor Target Date Date Completed --- 09/18/00 09/18/00 Comments Pumped brine down 7-8 and blinds have been installed on flowline. Page 1 ~ ~XPLORATION INC. ' ~ ~ Loss Control Investigation Report ~o , . Report Printed: 06/28/2001 ACTION ITEM Work Order Action Item # ! Priority .... i Responsible Party 43274 I 3 Low I GPB, Flow Station 3 Supervisor Description Repair/replace S riser. Target Date ----'CD-Eib-Completed -~ 10/01/00 ! 09/23/00 Comments Return to service action is not HSE related and should not be in the LCIR data base. While this action is not completed at this time, I am closing the action at the same time as I approve the LCIR as it does not belong in the LCIR system. Matt Werner, GPB Operations Manager ACTION ITEM -Action Item # Priority 43275 2 Medium lResponsible Party GPB, Flow Station 3 Supervisor vV~rk Order Description Review incident with Wells and Operations Group to determine whether this method of annular flow can be safely re-established. Target Date Date Completed 10/01/00 10/15/00 -Comments The annular flow on this well was reviewed by the trouble well engineer, wells group supervisor, and operations. The actual velocity of the fluids and gas are lower in this configuration then the conventional tubing flow. The actual failure of the surface piping was due to a flawed surface , piping design. The new surface piping has been engineered with annular flow considerations. Ford, Erin September 17, 2000 Originator Date Werner, Matt September 23, 2000 Approver D-a-t-6 Page 2 Well Test/Black Oil Plot WELL: 07-08A/PRUDHOE Dates from 09/18/1999 to 07/02/2001 25 0 ~OOOO0 300000 200000 40000 3OOOO 20OOO 4OO0 3000 2000 soo i 400 300 2004 r r- --l---- tI --I- I ! M J S O 50 40 30 20 F M ~ A J A N ================================================================== (- -1 1- --~ .... I ..... 1 ..... I ..... -1 ..... 1' ..... I' .... _--I -1 ..... I ..... I ..... l-- .... --/ ..... E -: :::::::::::::::::::::::::::::::::::::::::::: :~ K .... .3ZZZZZ~Z .... ': .... :,'- ....Z~ ..... l- -(- l- 4- .... I ..... 4 ..... I-- .... %-1 .....-I- .....I ..... -~ I- -I ..... I ..... 4 ..... l-- .... --I ..... ,~ I ~---' ..... ~ ..... ~---:~'- .... ~ ..... ' ..... I ,~ ~ ..... ' ..... ~ ................ I ~ I ! '1 I I I I I I I I F I ~f-"--' .....~ .....~ ....~ .....: .....' ..... ~, F ~ ..... ' ..... ~ .....~ .....' ..... i ! i i i i i i I i i i I I i I / \ I I i i I I I i i I i I I I- ~ /- '- -- __-----~__-- --I__-- '- __--__-- % 1 -- : : -- --I~__-' '-: : __--I-- -' -- __-- -' ~: : ~ ~ :l~ ~ % ~ ~ ~ l- --__ -- __-- -- 2-- -- ~ -' --I---- -- -- -- ---- -1---- -- -- -- --~'-- -----I--''---: r ::::::::::::::::::::::::::::::::::::::::: r -1 ..... ,- __.: ..... , _~--___ ,~ i ~,/ .... ',~-' ..... ~, ..... ,' ..... ~, .......... , ~'~, ~ I ,~:~ - -',~-o~ ............. , , ,' ..... F ~, ~r---:,,, ~. ..... ~, ..... ,' ..... ~, ..... ~, .... ~ r,, .... ~, ~,~ ~ ,,,, - -,,8-~ ~¥~- - -~ ~z~ b-', ..... ~ · , ~ , , , , ~, J -.- , , , , r-~ ~: :~_::::::::::::::::::::::::::::::::::::,.~:::_-, :::-c :: :¢7..~_':_~--__-_..~_ ~:~t r.~ - -, ..... :: .... :c .... :,- .... I- l- .....I-\ ....--t -I- -~ L ~ - [~~ t- -- ~ - ~~ ~ I [ %, i i i i i i r r .... ,-~- --~ ,- r -,' - a r I\ I I I I I -- m--'], i ~ i i il F M A M J - ----------'-----I ..... C: .... :I ..... I::- _-i_- :-r-Z---t: .... J I- .... -f ..... t- ..... I ..... '+ ..... I-- .... I- .... '1 ..... f" ..... ! ..... 1' ..... ..... ~ .... ~. ..... .. ..... : ..... ~ ..... i i' I ) 'I I I I I I I I I I i i i '1 '1 'l ..... t ...... I m -- I I -**-,~ .....,-'---**'I ........... , -* , , , , I I I' I i' ..... -~ .....I ..... "'f .....I ...... I ..... I I I I I I I I ' ' ' ' .4' ' =' -f -1 -i 1- i- -t -i ..... -1 fi- - - - -4 ..... 4 ..... I ..... ~ ..... ~ -I ................. ~--- I ! i / i ! i i i - -i ....... I ..... 7 ..... I ..... -] - - f .... -~ .....r ..... ~ ..... i- l I I I I I I I I I , ----I--_-----::I----- Z ...... -r --I---------:::)-- .... I- ......... :3 ..... I ..... 3 .... -I- ....... · -r ..... i I ZZZZDZZZZZ I i i i i i i i I I I I i J F M A M J i I I I I I I I 100 90 80' 70 60 50 40 30 20 10 1999 J 2000 2001 WT/BO I [__.___lGross Fluid 09:39:41 I July 02 2001 ) CPE Vl.4.121 ['-e---lOll Rate WELL [---¢~ -{G.O.R. e IMan. Pressure ~ IChoke ~as Rate 07-08A I ' Lift * IMan. Temp. Def/Meas. I ' IBiack Oil LI~/ U~/ bp April 5, 2001 "' ONLY ' · Comm ~ ~A~I~UKA'I'IUIq I~. UUJ BP ~xplorafion (Alaska) ]nc. 900 Ens! Bemson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work, , This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for April 2 - 9, 2001: ~ WeU Work Planned' 02-19 ADD PERFORATION 02-21 ADD PERFORATION . 05-17B ADD PERFORATION ' '", !~~:~' CT REMOVE 2-3/8" GL COIL ~,,, 11-22A ADD PERFORATION 15-43 SET CIBP W/CT 16-05Ai CT REPERFORATION / ACID STIMULATION 18-04A CT REMOVE 2-3/8" GL COIL 18-13A CT SET CIBP FOR GSO 18-18A SET CIBP W/CT Starting next week, I will be including WOA, Milne Pt, & Endicott wellwork. If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc@bp.com. Sincerely, Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells March 10, 2001 Mr. Walt Sandel Environmental Specialist State of Alaska · Department of Environmental Conservation 610 University Avenue Fairbanks, AK 99709-3643 Subject: 07-08 Well Event Response Timeline RE£EIVED MAR 2 1 2001 Alaska 011 & Gas Cons, A~,ctmr~ Dear Mr. Sandel: In accordance with your request of March 8, 2001 we are providing a short synopsis of the well work associated with the recent DS 07-08 event. We hope this clears up any remaining confusion in this area. Please feel free to contact us if further detail is needed. 2-19-01: Incident occurred at well 07-08A, gas and oil venting from well shelter. 2-20-01: With company-approved procedures, the response crews rigged up pumping equipment at DS-7 manifold building to kill well 7-08A. 00:00 hours to 12:17 hours- Pumped 1332 bbls of 2% KCl-wtr. down 7-08A via flow line through the 2 3/8" coil tubing (CT) velocity string (X Production Tbg. IIA) to perforations at rates of- 0.5 - 8 barrels per minute (bpm). Beginning wellhead pressure (WHP), 2200 psi. ending 0 PSI. 2-20-01 1400 hrs - 19:20 hours- Pumped the salt kill pill from the manifold building down 7- 08A flow line to the 2 3/8" velocity string (X Production Tbg. HA) to perforations, 3 - 6 - I bpm, 0 -400 PSI WHP (perforations locked up as planned) then WHP was bled to zero PSI. The washed out casing valve was removed from the tree and replaced with a blind flange with tap installed. Well secured. The salt kill pill was pumped in the stages listed below beginning with: 26 bbls methanol 135 bbls 9.8 ppg brine 26 bbls Hi Vis 9.8 ppg brine lead 77 bbls 10.5 ppg Salt pill w/XC 30 bbls Hi Vis 9..8 ppg brine tail 254 bbls 9.8 ppg. lbrine , , , 2-21-01, 0100 hrs - 0200 hrs- Pumped 150 bbls methanol-water from the manifold building down 7-08A flow line through 2 3/8" velocity string to freeze protect CT. 0300 hrs - 03:20 hrs - Pumped from 7-08A wellhead down the 2 3/8" CT X Production Tbg annulus with 88 bbls. methanol-water to freeze protect lEA. Wellhead pressures CT/T/IA/OA =vac. 2-26-01, 10:00 hrs - 19:00 hrs -ACS removes well shelter, scaffolding is built, tree is serviced, add additional valves to IIA and injection test is completed. (CT left freeze protected to 2500' with diesel) 2-27-01, 19:00 hrs - 02:30- Pumped a CaCO3 pill from the wellhead down the CT X Production Tbg. Locked up perforations to 1300 PSI differential pressure as planned. (Shut-In at Well with 600 psi on CT and CT X Production Tbg) Top of CaCO3 pill is at 8454' md. Top of perforations@ 10299' md. All peris covered by approximately 2,000 feet. The pill stages were pumped as follows beginning with: 250 bbls 2% KCL-water 18 bbls 8.5 ppg KCL-water Hi Vis 38 bbls 9.0 ppg, 35 ppb CaCO3 pill l0 bbls 8.5 ppg KCL-water Hi Vis 70 bbls 8.5 ppg Inhibited 20/0 KCL-water 44 bbls diesel 22 bbls 8.5 ppg inhibited 2% KCL-water 12 bbls methanol 2-28-01 All wellhead pressures on Coil Tubing/Tubing/Inner Annulus/Outer Annulus bled to zero PSI and are monitored daily. To date all are still at 0 PSI. Future Plans: Procedures are being formulated to extract the velocity string which will return this well to its original wellhead configuration and is consistent with others in the field. Surface equipment (wellhead, s-riser, elbows, and choke system in manifold building) from well to manifold building will be. inspected. All of the inspections will be completed and documented prior to removing the CT string and returning well to production. Please feel free to contact John Smart/Gary McBride, ADW/BPB Wells Operations Supereisors, Office phone (907) 659-5872 ff you need further information. ~_.Sincerely, Jack M. Fritts/Ruth Germany-Bice GPB Operations Manager Cc; Richard L. Powell, PRB 19 GPB Environmental, PRB 7 Len Seymour, MB 5-2 Smart/McBride, PRB 20 AOGCC P. 00:[ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Blair Wondzell, P. I. Supervisor DATE: FROM: Chuck Scheve, SUBJECT: Petroleum Inspector February 20, 2001 Floe line leak PBU DS 7-08A. M.~0:nday__,_F.,ebnJarv '19, 2001_: At 2020 1 received notification of a flow line leak on well 0SA. I proceeded to the incident command center at PBOC as access to location was restricted to the emergency response team. The Drill Site Operator found the leak while making his rounds and believed it was a leak in the flow line but could not verify the location dueto large amounts of gas in the well house. The first response was to reduce the pressure on the flow line in the manifold building. This was accomplished and it was believed that the well had shut in with the surface safety valve. An attempt was made to enter the well house but was unsuccessful as gas was still escaping and visibility was 0. A pump truck was then rigged up on the flow line at the manifold building and an attempt was made to pump seawater into the well. The flow line pressured up 2650 psi and held indicating the SSV had closed and the leak was somewhere on the wellhead. After several practice runs on an adjacent well the entry team managed to get a hyd hose hooked up to the panel and pump open the surface safety valve. Seawater was pumped at 8bbls per rain down the 2 318 coil tubing by 5 % tubing annulus with: This greatly reduced the flow of gas and increased the visibility in the Wellhouse, Upon entry into the Wellhouse the leak was found to be in the body of the master valve. The forward plan is tO pump a sized salt pill and 9.8 ppg brine to kill the well. When it is certain the well is dead the washed out valve will be replaced. Side notes: This well has a coil tubing completion and was being produced up the 2 3/8 by 5 % annulus. It is my understanding that there is no way to isolate the washed out valve with a tubing plug or back pressure valve. This well had a washout in the flow line in the well house on 9-1-00 at which time the line rerouted. Wellbore Schematic Tree Diagram RECEIVED F.%q. 2 o 2.001 Alaska 0il & Bas Cons. ~ Anchorage Calculations Chal Subject ~--O~A File JBy Sheet number QUALITY LITHO PRINTING, ANCHORAGE, AK (907)563-4743 159-5881 Wellhead Equipment Division Tree Drawing Date: 8/28/99 Rig: CTU #4 Well Number:. DS 7-08 Tree Bore: 5 118" 7 1116" 5M FLG. 13 5/8" 5M FLG. 135/8" 5M FLG. 20" 2M FLG. 2.~2' 2.51~' O. 2.41' 2.17' GRAY 1.15' ARCO ALASKA, INC. HGR CONN TUBING PRODUCTION SURFACE LINER CONN NIP SLV NIP SBR PKR TUBING XO SLV NIP LINER 8997' MIN ID = 2.750 XO SOS LINER 9610' cTD WindOw Ped Perf COLLAR SHOE A 07-08A APl: 500292029601 SSSV Type: Annular Fluid: DSL/10.6 CaCI2 Reference Log: MEM CNL Last Tag: 10921 Last Tag Date: 2/4/99 Well Type: PROD Depth Annotations Depth Comment 8997 8997' MIN ID = 2.750 9610 9610' CTD Window Prudhoe Bay 07-08A Orig Compltn: 1/12/99 Last W/O: 1/12/99 Ref Log Date: 2/4/99 RKB: 64 ft TD: 10948 ftKB Max Hole 96 deg @ 10444 Angle: Angle @ TS: deg @ Angle @ TD: 80 deg @ 10948 Rev Reason: CT Last Update: 11/5199 Other Depth 0 1 2151 6816 6817 (plugs, equip., etc.) - JEWELRY TVD Type Description ID 0 HGR FMC Tbg Hgr w/4-1/2" G Fishneck deployment sub 0.000 1 CONN 2-3/8 EZ Wetherford Coil Connector 2.375 2151 SSSVNIP 5-1/2" CAMCO BAL-O SSSV Nipple 4.582 6384 CONN 2-3/8' EZ Coil Connector 2.375 6385 NIP Weatherford 1.5" PT Land NIP w/1.5" PH pump thru plug set in profile/ 0.000 WLEG 8034 SLV 5-1/2" BAKER SLIDING SLEEVE 0.000 8108 NIP 5-1/2" BAKER LANDING NIPPLE 4.223 8150 SBR 5-1/2" BAKER SBR ASSY 4.223 .- 8194 PKR 9-5/8" X 5-1/2" BAKER SAB PACKER 4.223 8204 XO 5-1/2" x 4-1/2" CROSSOVER 0.000 8244 SLV 3.75" x 3" BAKER DEPLOYMENT SLEEVE 3.000 8256 NIP BAKER NIPPLE 3.759 8276 XO 3-1/2" x 3-3/16" Crossover 2.992 8308 SOS 4-1/2" SHEAR OUT SUB 0.000 9017 COLLAR BAKER LANDING COLLAR 2.992 BAKER FLOAT SHOE 2.992 8718 8804 8853 8903 8915 8961 8975 8998 9035 10903 10937 9021 SHOE Casing Strings - All Size Weight 9.625 47.00 13.375 72.00 2.375 0.00 3.500 9.30 L-80 3.188 6.20 L-80 Tubing Strings - All Size Weight Grade 5.500 17.00 L-80 4.500 12.60 L-80 Perforations Interval TVD 10299-10576 9023-9020 10768-10907 9016-9018 Grade Top Btm Feet Description N-80 0 9610 9610 PRODUCTION N-80 0 2712 2712 SURFACE 0 6817 6817 LINER 8965 8998 33 LINER 8998 10937 1939 LINER Top Btm Feet Description 0 8915 8915 TUBING 8915 9036 121 TUBING Zone Status Feet3PF Date Type 277 4 2/5/99 IPERF 139 4 2/5/99 IPERF Comment L TPg~ 02-19-01 1956 DRILL SITE 7 WELL 8 OIL TOTGAS FORM WATER GLG GLP ACT PRO] CHOKE SIZE STBD MSCFD GOR BWPD(%) MSCFD PSIG GLR FTP FTP 83H(L )MV136 944 28201 29864 327(26) 0U 500 22183 267+ 280 CHK: 02-19-01 1955 IGV: OPEN SINCE 02-19-01 1948 DIFF 13 REASON FOR CHOKE PRIORITY OR CFR: ENG/EOC NOTES: CHOKE TO 500 FTP FOR GOR 11-16-00 MBS COMMON # LINE .... MIXTURE VELOCITY .... FS TR --LINE-- CL PRES CURRENT 8 HOUR AVG LIMIT WC INC INC INC DL B C D WL PGIG (FPS) (FPS) (FPS) (%) FGOR TGOR NWC STEP SEQ 3 B * *C * 12 270 82.16 83.27 1S 29865 29865 117 N RECOMMENDED RATE DATA UPDATED BY: KDW ALLOCATION FACTORS NET CFR = 0( ) LAST UPDATE: 05-02-95 0847 OIL: 1.0129 (MONTH) OIL ROR = 630(70) LAST UPDATE: 01-08-01 1841 GAS: 1.1079 -47 REC GLG : 0 PROD STATUS: MY PRODUCE H20: 1.0611 WELL TEST REPORT THE WELL IS CURRENTLY SCHEDULED FOR TESTING AVG AVG AVG AVG TOTAL LIFT FORM TOTAL 1-FAF ORIF DATE CHK SEP FTP SEP GL OIL WTR GAS GAS % GOR GOR TEST SYLL DIA POS TMP TEST PRS PRES STBD BPD MSCFD MSCFD WC SCF/B SCF/B TIME TPLG 02-14 71 91 401 261 50 577 311 15781 0U 35 27350 27350 2.7 NRNG 6.75 01-26 70 87 445 283 20 599 209 15946 0U 26 26620 26620 3.3 NRNG 6.75 01-19 70 88 472 274 650 596 197 16273 0U 25 27303 27303 6.2 NRYG 6.75 01-13 50 67 1068 285 200 507 79 11867 0U 13 23406 23406 0.9 NDNU 3.75 01-11 70 89 522 282 200 661 215 15669 OU 25 23705 23705 3.0 NRNG 6.75 01-03 83 89 352 278 300 606 229 16092 OU 27 26555 26555 3.0 ERNG 6.75 12-20 83 89 347 285 950 640 250 14119 OU 28 22062 22062 5.4 NRNG 3.75 12-15 83 91 323 260 150 678 287 1~286 OU 30 19596 19596 3.0 ERNG 3.75 DATE NOTES 01-13 TESTED AT 50 DEGREE CHOKE. 11-19 SWAPPED PRODUCTION BACK UP COIL TUBING X TUBING ANNULI. 11-17 SWAPPED TO PRODUCE UP COIL. 11-16 TESTING ~ A REDUCED CHOKE. 11-15 RETESTED W/3.75 PLATE FOR TEST VERIFICATION. 10-23 MECH REPAIRED ACTUATOR ON C DVT. 10-18. TESTED WITHOUT A/L 10-17 TESTING WITHOUT A/L 10-16 BOL WITH NEW FLOWLINE, A/L IS NOT ON, 10-15 PRETESTED WELL SYSTEMS AND BROUGHT ON LINE $$ NAME t~N~LO6 / METER R~TE TRENDING - 7 DFIY PLOT DESCRIPTIDN I ---ADJUSTABLE--- CURRENT ---PLDT RANGE--- VALUE MINIMUM MAXIMUM B. BB' .0.00 14 14 I16 06 I1 ? ~ 119 14 I~ 1 06 14: DP: P3 HOURS 0~- 14-81 SHIFT KEYS SET MIN AND MAX TO -1 TO TURN ON "PRETTYI' SCALING 1 - TIME FORI, IARD 8 - DISPLAY TREND FOR METER,LENGTH,DDTE,TIME ENTERED ON LINE 1 P - TIME BAI]KI~IARD 9 - DISPLAY TREND FOR PVID,LENGTH,DDTE,TIME ENTERED ON LINE I 9O 8O 7O 6O 5O 4O 3O 2O 10 0 0:00 Well 7-8 Choke 2-19-01 4:48 9'36 14:24 19:12 0:00 4'48 Time Annular Communication History Well 07-08 Problem: CT AL string installed 8-27-99 Status: CTST 1/99 CT AL string installed 8-27-99 > 11/23/98: MITOA Failed; PPPOT IA x OA PO Passed @ 5000 psi (pre CTD) > 12/19/98: MITIA Passed @ 3000 psi (pre CTD) > 01/12/99: CTD moved cfi well > 08/01/99: WL set TTP > 08/27/99: CT gaslift string installed > 09/01/00: Hole in S-Riser where jumper ties in. Well SI. Planned Action: None Date Comment 1/9/2000 9/12/1999 8/27/1999 7/27/1999 3/21/1999 1/12/1999 12/27/1998 12/1.9/1998 12/16/1998 11/23/1998 8/29/1998 7/15/1998 7/14/1998 7/3/1998 3/31/1998 5/15/1993 Water sample on.. 1/9/00 is formation water. CT/T/I/O = 1200/1200/0/0 CT FL @ 4370', Tbg FL @ 4370' well was shut in. CT gaslift string installed. T/I/O =600/0/0. DSM killed well with 3 bbl Meth, 300 bbl KCL, 60 bbl crude. Final 0/0/0. T/I/O = 250/40/0 TBG FL @ 1250' for FE. CTD moved off well. CTD (CDR1) moved on well. T/I/O = vac/130/0 MITIA to 3000 psi PASSED (for Pre CTD); Initial IA FL @ 100' (4.4 BBLS). Bled IA from 130 psi to 0+ psi in 30 mins, all gas. MITIA lost 30 psi in 15 mins, 10 psi in the second 15 mins and a total of 40 psi in 30 rains. Pumped 8 bbls of diesel down the IA. Final WHP's = VAC/0/0 P & A perfs; est TOC @ 9036' (pre CTD) T/I/O = SI/175/0+ MITOA FAILED; IA FL @ 60'(2.6 bbls), OA FL @ 50' (3 bbls). Started pumping down the OA. OA would not pressure up above 2000 psi. LLR @ 10.4 GPM @ 1850 psi. Total test time 30 mins. Total test volume 311 gallons. Pumped 15 bbls of diesel total down the OA. OA pressure dropped off on it's own. IA x OA PKO's PASSED; Test port @ 0+ psi. Flushed through, got good reruns. Monitored Pack off during MITOA/LLRT with no increase in pressure. Tbg x IA PPPOT to 5000 psi PASSED; Test port @ 500 psi bled to 0 psi. Could not flush through. Pressured up test port several times to get test to pass. Test lost 180 psi in 15 mins, 120 psi in second 15 mins, 300 psi total. Final WHP's = Sl/150/1280. T/I/O =?/440/320 IA FL @ near surface. WL MITIA @ 3000 psi Passed. Lost 190 psi in 30 minutes. T/I/O = 80/20/0 TBG FL at 1590'. IA FL at surface. Post N2 lift. WL did FCO to 9960', with N2 lift- Well .qot flowing, need FL's shot MITIA Passed @ 1000 psi (pre Frac) by WL DSM complete MIT-IA to 2100 psi (Passed) MIT-IA lost 25 psi in first 15 min and 50 psi in second 15 rain for a total of 75 psi in 30 min. T/I/O=1550/300/340, well flowing. Production Screening MIT on the 9-5/8" Passed to 2500 psi. The dP/dT= -20 psi/30 min. Final press, after bleed down was:T/I/O=1550/300/340. 2/22/2001 Page 1 of 1 Well 07-08 07-08 07- 08A 07- 08A 07- 08A 07- 08A 07- 08A 07- 08A 07- 08A 07- 08A 07- 08A 07- 08A 07-08 07- 08A 07- 08A 07- 08A 07-08 07- 08A 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07 -08 07-08 07-08 07-08 07-08 07-08 Well Events for SurfaceWell 07-08 from 01/01/1950 to 02/19/2001 Date Description of Work 11/22/1999 DRIFT/TAG (RATE): DRIFT FOR RATE TO 10076' SLM 10/28/1999 HOT OIL TBG WASH: HOT OIL IIA (RATE) 09/02/1999 MISC-NRWO: PULLED 1-1/2 .... PE" PUMP OPEN PLUG (POST-CT AL STRING) 08/27/1999 MISC-NRWO: RUN 2-3/8" CT GAS-LIFT STRING 08/05/1999 MISC-NRWO: PULL PLUG FROM SSSV NIPPLE (PRE CT AL STRING) 07/31/1999 MISC-NRWO: SET AT SSSV NIPPLE 07/28/1999 MISC-NRWO: DSM KILLED WELL 07/23/1999 MISC-NRWO: PREP FOR COILED TUBING HANGOFF 07/11/1999 MISC-NRWO: FULL BORE DRIFT TO LINER TOP 03/29/1999 FCO-N2:N2 LIFT FCO 03/28/1999 FCO-N2: FCO (PRE-N2 LIFT) 03/07/1999 FCO-N2: DRIFT FOR OBSTRUCTION (NO FLOW) 02/17/1999 N2 LIFT 02/05/1999 CT IPERF (POST CTD) 02/04/1999 CT MEMORY CNL (PRE IPERF) 01/29/1999 01/13/1999 01/12/1999 01/1 i/1999 01/10/1999 01/09/1999 01/08/1999 01/07/1999 01/06/1999 01/05/1999 01/04/1999 01/03/1999 01/02/1999 01/01/1999 12/31/1998 12/30/1998 12/29/1998 12/28/1998 MILL CMT (POST CTD) CT ,DRILLING DIESEL CHARGES (1/13 - 1/31/99) CTD HANDOVER CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES CT DRILLING CHARGES Source AWGRS PBU AWGRS PBU AWGRS i:, -i5 .......... AWGRS PBU AWGRS AWGRS PBU AWGRS PBU AWGRS PBU AWGRS PBU AWGRS PBU ..A...~_.G..R...S... PBU AWGRS PBU WIMS WIMS WIMS WlMS WlMS WIMS WIMS WlMS WlMS WlMS WIMS WlMS WlMS WIMS WlMS WlMS WlMS ,..w...!.M.,.S. WIMS WIMS 07- 0SA 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 07-08 12/27/1998 12/27/1998 12/26/1998 12/19/1998 12/17/1998 12/16/1998 12/15/1998 11/27/1998 11/26/1998 11/23/1998 10/09/1998 09/14/1998 09/10/1998 09/08/1998 09/05/1998 09/04/1998 09/03/1998 09/03/1998 09/01/1998 08/30/1998 08/29/1998 08/29/1998 08/29/1998 08/27/1998 07/31/1998 07/17/1998 07/16/1998 07/14/1998 07/14/1998 07/13/1998 07/03/1998 07/03/1998 05/31/1998 05/25/1998 05/22/1998 05/16/1998 05/11/1998 05/09/1998 04/10/1998 04/10/1998 04/10/1998 03/31/1998 03/31/1998 01/31/1998 12/10/1997 10/28/1997 10/27/1997 08/19/1997 CTD CHARGES CT DRILLING CHARGES CT DRILLING CHARGES WPA DRIFT & TAG POST P & A P & A (PRE-CTD) P & A (PRE CTD) PPROF DRIFT/TAG FOR P.PROF WPA PULL FRC SLV, 9905' ELM TAG W/3.45" 28' FILL FRC SND SMPL (POST FRAC) FCO TO TD 10,002 N2 LIFT TO FLOW (POST FRAC) DATA FRAC / RE FRAC, 35.5 K PUMPED, 29.6K IN PERFS, ATP 2930 PSI RAN FRAC SLEEVE (PRE FRAC) PERF - 202 INTERVAL ( 9900' - 9920' ) DRIFT-TAG W/3.5 DMY GUN TO 10024' (PRE PREF/PRE FRAC) REVERSE FCO (PRE-ADPERF-FRAC) 10010' TAG @ 9891' ELM W/2.5" SBLR, NO SAMPLE; NEED 9920' (PRE PERF/FRAC) UR/FCO TO 9996' CTM FCO TO 10001' (PRE-FRAC) TAG LEDGE @ 9867' ELM W/2.65" x 11' STEM, NO SAMPLE (PRE FRAC) WPA TAG @ 9734' ELM W/3.5" DC, FRAC SAND IN S. BLR (PRE FRAC) FCO 9599' - 9950' CTM, N2-LIFT TO FLOW (POST-FRAC) DRIFT & TAG @ 9603' EL W/3.19 CENT. 126' FILL.(POST FCO) PULLED FRAC SLEEVE (POST FRAC FCO) WPA FCO TO 9,960' N2 TO FLOW (POST FRAC) ZONE 1 FRAC (PUMPED 24K SAND, 9K THRU PERFS SD W/6.8#@ PERFS) WPA MITIA TO 3000 PSI-OK, TAG TD @ 9976' ELM, 43' RH., RAN FRAC SLV- 3.25 "I.D. CT N2 LIFT TO FLOW (POST SQZ) UR 9865-9891, FCO 9891-9995, SWAP WELL TO CRUDE, NO FLOW DRIFT-TAG 3.60" CENT. TO 9875' ELM (POST SQZ) GSO SQZ, 15 BBP, 3500 PSI SQZ. TAG SAND TOP @ 9886' (PrE SQZ) SAND PLUGBACK TO 9885', PRE-CEMENT GSO SQUEEZE GYRO SURVEY D&T W/2.70 TO 9899 (GYRO) 07-08 98-04-10 GYRO.xls PULLED SSSV; DRIFT-TAGGED@ 9907' (26' FILL) MIT IA 2000#(PASS) (POS~I SQZ) WPA MISCELLANEOUS CHARGES 07-08 12-10-97 RSSSV.xls 07-08 PERF 10-28-97.xls 07-08 10-27-97 D-T.xls 07-08 08-19-97 PPROF.xls WIMS WIMS WlMS WlMS WIMS WlMS WIMS WlMS WlMS WIMS _WJ_M__S_. WlMS WlMS WlMS WlMS WlMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS WIMS ...W..I.M_S.. WIMS Excel WIMS WIMS WIMS Excel Excel Excel Excel 07-08 07-08 07-08 05/07/1997 07-08 05-07-97 DRIFI'.xls 12/08/1995 07-08 12-08-95 TAG.xls 08/08/1995 07-08 08-08-95 SHIFT.xls Excel Excel Excel 02/21/2001 08-44 FAX 907 564 5~ Feb-20-O1 1~:05 From-ARL'O PRUDHOE IC$ · $5g-I~024 T-127 P.02/03 ~002 DS %08 Post Well Kill Rink Ass~qment For Replacement of CT by Tubing Annulus Valve (Wtng Valve) Risk. Well begins to flow when damaged valve is removed. Consequence. s- Loss of Well Control and Environmental Impact Mitigating Factor- Have Bleed line Rigged to Bleed Tank. Bleed CT by Tubing Annulus a~ nece.~ary. Monitor for Flow for 30 minutes before taking any further actions. Riak. Exposure Time During Valve Cttange Out Consequences- Loss of Well Control and Environmental Impact Mitigating Factor- Install Tapped Blind versus 3" Gate Valve (Lighter in weighr and easier to install) · · Revised: 2/20/01 1:01 PM Well 07-08 Kill & Secure Procedure 1) Secure clamp on FMC CT hanger casing valve (ie "TxCT annulus valve") to stop leak. 2) Continue to pump 1% KCL water @ 1 - 2 bpm. 3) Shut down momentarily and check TxCT annulus pressure. Continue pumping 1% kcl water. 4) Check drain header manifold inside manifold building for leakage into kill line in DS 7 manifold. Secure any wells that might be leaking. 5) Get kill fluids to DS 7. Pre Kill Measures 1) Insure DSM valve crew standing by (on location, but at safe distance) w/VR plug and replacement CT hanger valve. 2) Open master valve, SSV then swab valve. Ensure primary wing valve is closed. 3) Bleed gas from coil tubing thru tree cap to flowline. Well Kill Procedure 1) Dowell pump will remain pumping on drain header in manifold w/1% KCI down TxCT annulus, 1-2 bpm @ 50 psi. 2) Pump the following fluid schedule. Note flowline capacity 94 bbls. a, m, Close Pump Pump Close Pump Close primary ~,~valve, open TxCT annulus valve, 20 bbls ~7.~a-t-Ynethanol @ 3 BPM, 75 bbls 9.8 brine @ 3 BPM, TxCT annulus valve, open primary wing valve, 60 bbls 9.8 ppg brine @ 3 BPM, primary wing valve, open TxCT annulus valve, Pump 10 bbls 9.8 brine @ 3 BPM. Pump 2.5. bbls Vis 9.8 brine @ 3 BPM, Pump~'~bbls Salt Pill @ 3 BPM, Pump 25 bbls Vis 9.8 brine @ 3 BPM, Pump 250 bbls 9.8 brine @ ~nax rate, up to 250 psi. >> Salt pill should be at top of perfs when 230 bbls brine is pumped. << Slow pump rate, pack salt pill into perfs by pressuring up 250 psi over current pump pressure. Hold pressure for 10 minutes to pack salt into perfs. Bleed pressure to 0 psi, monitor for 30 minutes If pressure remains negligible, pull and replace TxCT annulus valve. Fluid Inventory 580 bbls 9.8 ppg NaCI brine 50 bbls viscosified 9.8 ppg NaCI (100 cp) 20 bbls Salt pill 270 bbls 60/40 Me©H/H20 300 bbls 1% KCI 20 bbls Neat MeOH STATE OF ALASKA S{I ALASKA OIL AND GAS CONSERVATION COMMIS ~,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdowe _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Nter casing _ Repair well _ Other_X 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1213' FNL, 166' FEL, Sec 33, T11N, R14E, UM. At top of productive interval: 4063' FNL, 3782' FEL, Sec 27, T11N, R14E, UM. At effective depth: 5. Type of Well: Development _X Exploratory _ Stratagrapic _ Service _ At total depth: 4275' FNL, 2909' FEL, Sec 27, T11N, R14E, UM. 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Conductor 119' Surface 2648' Production 9609' Liner 1977' CT Gas Lift String 6800' 10948 feet 9023 feet 10914 feet 9018 feet Size 20" 13-3/8" 9-5/8" 3-3/16" 2-3/8" Plugs (measured) Junk (measured) Cemented 271 Sx Arcticset 3700 Sx Arcticset II 1200 Sx Class G 20.5 Bbls LARC Not Cemented 6. Datum of elavation (DF or KB feet): 64' RKB 7. Unitor Property: Prudhoe Bay Unit 8. Well number: 7-08A 9. Permit number/approval number. t98-244 10. APl number: 50-029-20296-01 11. Field/Pool: Prudhoe Bay Oil Pool Measured depth 119' 2712' 9610' 10945' 6800' Trueve.icaldepth 119' 2712' 8781' 9022' 6371' Perforation Depth measured 10299- 10576'; 10768- 10907' true vertical 9023 - 9020'; 9016 - 9017' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 8915' MD; 4-1/2", 12.6#, L-80, Tbg Tail @ 9036' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 8903' MD; Camco BaI-O SSSV Nipple at 2151' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see attached ORIGINAL 14. Prior to well operation Subsequent to operation Representitive DailyAverage Production orlnjection Data OiI-Bbl Gas-M~ Wate>Bbl 46 346 0 172 130 8 Casing Pressure . Tubing Pressure 278 246 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Engineering Supervisor Form 10-404 Rev 06/15/88 Date IZ./ 'l SUBMIT IN DUPLIC 7-08A DESCRIPTION OF WORK COMPLETED COIL TUBING GAS LIFT STRING INSTALLATION Installed a temporary CT Gas Lift String to kick off well, and to allow this Iow GOR well to sustain flow as follows: 7/28/99- 7/29/99: Removed wellhouse, flowline, & tree, then loaded the wellbore w/1% KCL Water & Crude to kill well. 8/27/99 - 8/28/99: MIRU CTU w/spool of 2-3/8" Coil Tubing. PT equipment & BOP, then MU 2-3/8" Coil Connector, Weatherford 'PT' seating Nipple w/PE pump thru plug installed. Stabbed assembly on well & PT to 4000 psi. RIH w/6817' of milled out 2-3/8" x 0.190" CT to 6850' MD, then PU to 6800' MD. Set slips/pipe rams and manually locked CT in place. Cut coil off at surface. MU CTC, Crossover to 2-3/8", installed 2-3/8" tubing hanger, & landed 2-3/8" tubing. PT hanger packing to 5000 psi, OK. RD. 912/99: RIH to latch & POOH w/PE pump through plug from CT. RD. 10/28/99: Pumped Hot Oil Treatment down IA & tubing for rate. Placed the well on production w/gas lift & obtained a valid welltest. Well will be produced w/AL until GOR levels become sufficient enough to allow for removal of the CT AL string. RECEIVED 1999 Alaska Oil & Gas C, ons. Commissio. And o e 198-244-0 PRUDHOE BAY UNIT 07-08A 50- 029-20296-01 BP EXPLORATION (ALASKA) INC Roll #1: Start: Stop Roll #2: Start Stop MD _1_.Q.9__4_8- TVD _0_9_0~_~ Completion Date~5/99 Completed Status: I._;0_!L_, Current: T Name Interval Sent Received D 8890 f~'"" SCHLUM MCNL CH 3/4/99 3/11/99 D 9227 ~4'~ SPERRY GR OH 6/22/99 6/29/99 L MCNL 't-~INXL 8330-10918 CH 2 3/4/99 3/11/99 L NGP-MD I~NAL 9246-10948 OH 6/24/99 6/29/99 L NGP-TVD F~NAL 0-8955 OH 6/24/99 6/29/99 R SRVY RPT ~/SrPERRY 9500-10948 OH 1/27/99 1/28/99 T/C/D Thursday, February 01,2001 Page I of 1 I-I F~ I Ill JM r=- SE FI~JI I-- E S To: State of Alaska June 22, 1999 Alaska Oil and Gas Consevvation Corem Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - D.S. 7-08A, AK-MW-90056 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmi~ letter to the attention of. Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20296-01. RECElUED JUN 29 1999 Alaska 0il & Gas Cons. Commission 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company sideriteS-sun 0 !:t I I-I--I N G S E I:l~J I C I:: S State of Alaska Alaska Oil and Gas Conservation Comm Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 Juue 24, 1999 RE: MWD Formation Evaluation Logs: 7-08A, AK-MW-90056 The technical data listed below is being submitted herewith. Pl~se address any problems or concerns to the attention of~ Jun Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 7-08A: 2" x 5" MD Cramma Ray Logs: 50-029-20296-01 2" x 5" TVD Gamma Ray Logs: 50-029-20296-01 RECEIVED ,,.,Jiq ~9 q999 Alaska Oil & Gas Cons. Commission Anchorage 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silvemdo Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 3/4/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12395 Companl Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 7-08A 1~ 99093 MCNL ~ ~ ~ o~ 0 990204 ] ] ] D.S. 14-04A 99068 MCNL~r~<~ ~ ~ 990102 ] ] ~ D.S. 15-11A ~.~ /.' 99092 MCNL ~O~O 990206 I I 1 ~2-~ 99091 GR/CCL (~ ~ i 9s~2o2 1 D.S. 13-02B MEMORY G~CCMJEWELEY 990227 1 1 D.S. 13-02B MEMORY G~CC~DL 990228 1 1 . ~'~.~ , , , . DATE: " SIG 'Alaska' ...... ''~'"'. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-65~J~C~ you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS;51ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas D Suspended D Abandoned D Service ,2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 98-244 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-20296-01 4. Location of well at surlace 9. Unit or Lease Name 1213' FNL, 166' FEL, SEC. 33, T11 N, R14E, UM ' ~: "~',' .~:.;";:::~';:'~""t i~.kO~.l~'...'~,~ Prudhoe Bay Unit ~ ........ '-.~::;.u~;,~ ~,~.~.~";'.;1 '~ 10. Well Number At Top Producing Interval i''' ~'''''~:_/~/~F ~ ~ II At Total Depth ,,,~ :'-"~.! ~:;':,~. I 11 Field and Pool 4275' FNL, 2909' FEL, SEC. 27, Tll N, R14E, UM .i '~ i. ~~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Leas~ D-e~ig-/i~.t'lS~"an'h'~ Serial No. RKB 64 leetI ADL 028309 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January 1, 1999 January 9, 1999 February 5, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10948' MD /9023' TVD 10914' MD /9018' TVD YES ~] No r"]I 2151, MD. feet MD 1900' (approx) 22. Type Electric or Other Logs Run MEM CNL/GR/CCL, MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'Iq'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94# H-40 Surface 119' 30" 271 Sx Arctlcset 13-3/8" 72# N-80 Surface 2712' 17-1/2" 37oo Sx Arctlcset II 9-5/8" 47# N-80/S00-95 Surface 9610' 12-1/4" 1200 Sx Class G 3-3/16" 6.2# L-80 8968' 10945.5' 4-1/8" 20.5 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE : DEPTH SET (MD) PACKER SET (MD) 10768' - 10907' MD; 9016' - 9017' TVD; @ 4 SPF 5-1/2" 8815' 8903' 10299' - 10576' MD; 9023' - 9020' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 17, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 2/20/1999 4.0 Test Period >I 2692 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. 263 psi 24-Hour Rate > 1478 3979 0 28. CORE DATA * This 10-407 is submitted as directed per the 10-401 form approved December 8, 1998 (Permit #98- )Er ~ ~ V~ ~. D, Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~J~,~'~0~bmit In duplicate 29. '"' 30. GEOLOGIC MARKERS I FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sag River Sand 9149' 8405' Top of Shublik 9187' 8437' Top of Sadlerochit 9278' 8513' Zone 1B 10014' 8990' 31. LIST OF ATTACHMENTS Summary of 07-08A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is tree and correct to the best of my knowledge. Signed ~4~~ Title AAI Coil Tubin,q Drillin,q Supervisor Date ! Bruce E. Smith, P.E. INSTRUCTIONS Prepared by Paul Rauf 263.4990. General.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 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 ,, i 07-08A 'fi"' DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 12/2611998: MI CTU. 12/27/1998: RU CTU. Started test of BOPE. 12/28/1998: 12/29/1998: 1 2/30/1998: 12/3111998: 1/01/1999: Completed BOPE test. RIH & milled R nipple @ 8975' MD. Milled to 9050' MD. Spotted Biozan pill & POOH. RIH & drilled pilot hole through Cement to 9390' MD. Drilled Cement to 9542' MD & POOH circulating bottoms up. .RIH & tagged BTM @ 9538' MD. Milled pilot & ramp to 9610' MD. Spotted Biozan pill & PUH to 2000'. Performed rig maintenance. POOH. RIH w/BHA to BTM & commenced milling window through the 9-5/8" casing. Milled to 9613'. 1/02/1999: Time milled window to 9619' & POOH. RIH & dressed window interval 9610' - 9619'. 1/03/1999: 1/04/1999: Backreamed window interval. POOH w/mill. RIH w/bi-centered bit & tagged 9617'. Encountered BOW lip, unable to proceed. POOH. RIH & time drilled f/9617' to 9618'. Time milled to 9620'. PUH & PT wellbore to 1500 psi - bled down 300 psi in 5 min. POOH. PT'd BOPE. RIH & milled window f/9616' - 9619'. 1/05/1999: 1/06/1999: Milled through window to 9620'. Drilled to 9626' & backreamed window interval. POOH to C/O BHA. RIH w/bi-centered bit & tagged BTM @ 9627'. Performed LOT to EMW of 9.6 ppg. Drilled to 9828'. Drilled to 10050' & POOH. RIH & drilled to 10150' & POOH. 1/07/1999: RIH & drilled ahead to 10510'. Stuck BHA @ 10500'. 1/0811999: 1/09/1999: Pumped Crude to free CT. Drilled to 10830' MD. Drilled to 10920' & POOH. RIH & drilled toTD @ 10948'. POOH w/BHA. 1/10/1999: RIH to BTM & POOH due to MWD failure. RIH w/BHA & discovered CT crack @ 9564' to 9504'. POOH. RIH w/nozzle to 1000' & circulated 2% KCL Water. 1/11/1999: RIH w/1978' 3-3/16" liner. Landed liner @ 10945'. TOL=8968'. Released f/liner. 1/1 2/1999: 2/02/1999: 2/03/1999: Cemented liner in place w/20.5 bbls of 15.8 ppg LARC. Contaminated Cement w/Biozan & jetted contaminated Cement f/wellbore. POOH w/CT. FP'd well. RDMOL. MIRU CTU & PT'd BOPE. Standby due to weather delays. RU CTU. RIH w/2.75 mill & tagged TOE Milled to 10909' MD. RD. Sidetrack Summary Page I i 07-08A i' DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 2/04/1999: 2/05/1999: RU CTU. PT'd BOPE. RIH w/SWS CNL-GR-CCL tools & logged f/BTM to 8300' MD. Layed FIo Pro in liner. POOH while FP'ing well. Numerous delays due to Iow ambients. RIH w/Perf guns to PBTD @ 10914' & shot 416' of Initial Perforations @: 10768' - 10907' MD (Zone lB) Ref Log: CNL 2/4/1999. 10299' - 10576' MD (Zone lB) Used 2-1/8" carriers & shot all Perfs @ 4 SPF, overbalanced, 0° phasing, & random orientation. POOH w/guns. ASF. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page 2 spe -suri 0 I:! I I_1_ I I~! G SEI:I~ICG S 27-Jan-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 7-08A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,500.00' MD 9,598.00' MD 10,948.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 07, Slot 7-08A 7-08A Job No. AKMW90056, Surveyed: 5 January, 1999 SURVEY REPORT 22 January, 1999 ORIGINAL Your Ref: API-500292029601 KBE-64.0 MWD SURVEY INSTRUMENT Surface Coordinates: 5949705.70 N, 676038.80 E (70° 16' 05.5052" N, 148° 34' 34.9607" W) DRILLING SERVICGS; Survey Ref: svy5483 Sperry-Sun Drilling Services Survey Report for 7-08A Your Ref: API-500292029601 Job No. AKMWgO056, Surveyed: 5 January, 1999 Prudhoe Bay Unit Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9500.00 37.120 73.210 8630.60 8694.60 9598.00 38.480 72.300 8708.03 8772.03 9645.77 45.880 69.800 8743.41 8807.41 9674.00 49.130 67.900 8762.48 8826.48 9703.18 52.260 65.900 8780.96 8844.96 9741.84 56.020 63.320 8803.61 8867.61 9770.69 58.010 67.050 8819.32 8883.32 9797.26 60.600 69.370 8832.88 8896.88 9830.94 64.460 70.560 8848.41 8912.41 9866.06 65.830 76.890 8863.19 8927.19 9899.08 66.360 80.940 8876.57 8940.57 9927.41 65.570 84.280 8888.12 8952.12 9962.31 64.070 90.960 8902.98 8966.98 10000.22 62.310 98.860 8920.10 8984.10 10032.01 66.000 98.860 8933.95 8997.95 10064.23 70.840 99.390 8945.80 9009.80 10093.34 76.020 92.010 8954.11 9018.11 10125.86 82.900 87.880 8960.06 9024.06 10150.37 87.630 84.980 8962.08 9026.08 10174.49 91.230 84.450 8962.32 9026.32 10209.19 94.570 90.430 8960.56 9024.56 10250.83 91.670 95.520 8958.30 9022.30 10278.26 87.890 96.230 8958.40 9022.40 10308.39 87.100 94.120 8959.72 9023.72 10342.39 88.330 90.600 8961.07 9025.07 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Alaska State Plane Zone 4 PBU_EOA DS O7 Dogleg Rate (°/100fi) 2329.17 N 1268.03 E 5952063.89 N 677252.01 E 2346.98 N 1325.39 E 5952083.04 N 677308.94 E 1.500 2357.44 N 1355.68 E 5952094.20 N 677338.98 E 15.882 2364.95 N 1375.09 E 5952102.17 N 677358.21 E 12.536 2373.82 N 1395.85 E 5952111.51N 677378.75 E - 11.965 2387.26 N 1424.14 E 5952125.62 N 677406.72 E 11.127 2397.41 N 1446.10 E 5952136.27 N 677428.44 E 12.851 2405.88 N 1467.32 E 5952145.24 N 677449.45 E 12.303 2416.11 N 1495.39 E 5952156.12 N 677477.27 E 11.882 2425.03 N 1525.96 E 5952165.75 N 677507.63 E 16.811 2430.83 N 1555.57 E 5952172.24 N 677537.10 E 11.327 2434.16 N 1581.23 E 5952176.17 N 677562.67 E 11.122 2435.48 N 1612.76 E 5952178.23 N 677594.16 E 17.844 2432.61 N 1646.43 E 5952176.14 N 677627.89 E 19.165 2428.20 N 1674.69 E 5952172.40 N 677656.25 E 11.607 2423.45 N 1704.27 E 5952168.34 N 677685.93 E 15.099 2420.70 N 1732.00 E 5952166.25 N 677713.72 E 30.109 2420.75 N 1763.95 E 5952167.04 N 677745.65 E 24.561 2422.27 N 1788.32 E 5952169.13 N 677769.98 E 22.614 2424.49 N 1812.33 E 5952171.91N 677793.93 E 15.086 2426.04 N 1846.93 E 5952174.27 N 677828.49 E 19.718 2423.88 N 1888.43 E 5952173.08 N 677870.03 E 14.052 2421.07 N 1915.71 E 5952170.91 N 677897.37 E 14.021 2418.36 N 1945.69 E 5952168.90 N 677927.40 E 7.471 2416.96 N 1979.63 E 5952168.30 N 677961.36 E 10.959 Vertical Section (ft) Comment 631.43 682.35 708.97 725.81 743.62 767.54 786.19 804.53 829.06 856.34 883.50 907.45 937.60 970.89 999.34 1029.15 lO56.67 1087.54 111o.71 1133.36 1166.42 1207.10 1234.20 1263.87 1297.04 Tie on Point Window Point Continued... 22 January, 1999 - 10:44 ,2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 7-08A Your Ref: API-500292029601 Job No. AKMW90056, Surveyed: 5 January, 1999 Prudhoe Bay Unit r,, Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10372.22 89.300 88.490 8961,69 9025.69 2417.20 N 2009.45 E 5952169.23 N 677991.17 E 10407.20 92.810 89.900 8961.05 9025.05 2417.69 N 2044.41 E 5952170.54 N 678026.11 E 10444.16 96.060 94.820 8958.19 9022.19 2416.18 N 2081.21 E 5952169.89 N 678062.94 E 10482.46 94.920 100.100 8954.52 9018.52 2411.23 N 2119.00 E 5952165.82 N 678100.83 E 10504.96 90.880 101.680 8953.38 9017.38 2406.98 N 2141.06 E 5952162.09 N 678122.99 E 10537,80 87.190 101.680 8953.94 9017.94 2400.33 N 2173.21 E 5952156.20 N 678155.28 E 10566.48 86.480 99.570 8955.52 9019.52 2395.06 N 2201.36 E 5952151.58 N 678183.54 E 10608.55 92.570 102.730 8955.87 9019.87 2386.92 N 2242.61 E 5952144.42 N 678224.97 E 10637.84 90.970 107.130 8954.96 9018.96 2379.38 N 2270.88 E 5952137.54 N 678253.42 E 10668.00 91.580 109.940 8954.29 9018.29 2369.80 N 2299.47 E 5952128.63 N 678282.22 E 10697.97 91.230 114.680 8953.56 9017.56 2358.43 N 2327.18 E 5952117.91 N 678310.19 E 10733.31 90.620 117.850 8952.99 9016.99 2342.79 N 2358.86 E 5952103.02 N 678342.23 E 10768.08 92.020 121.720 8952.18 9016.18 2325.53 N 2389.03 E 5952086.47 N 678372.79 E 10795.44 92.640 124.530 8951.07 9015.07 2310.59 N 2411.92 E 5952072.07 N 678396.02 E 10829.15 91.140 128.400 8949.96 9013.96 2290.57 N 2439.01 E 5952052.69 N 678423.57 E 10858.94 89.030 129.400 8949.92 9013.92 2271.87 N 2462.19 E 5952034.53 N 678447.19 E 10885.82 86.220 127.500 8951.03 9015.03 2255.17 N 2483.22 E 5952018.33 N 678468.60 E 10948.00 79.740 123.040 8958.63 9022.63 2219.55 N 2533.56 E 5951983.89 N 678519.76 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.846° (05-Jan-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 104.790° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10948.00ft., The Bottom Hole Displacement is 3368.28ft., in the Direction of 48.780° (True). Alaska State Plane Zone 4 PBU_EOA DS 07 Dogleg Rate (°/100fi) Vertical Section (ft) Comment 7.784 10.813 15.919 14.041 19.276 11.236 7.752 16.307 15.977 9.532 15.854 9.133 11.833 lO.509 12.306 7.838 12.615 12.619 1325.82 1359.50 1395.46 1433.26 1455.68 1488.46 1517.02 1558.98 1588.24 1618.33 1648.02 1682.65 1716.22 1742.16 1773.47 1800.66 1825.25 1883.01 Projected Survey Continued... 22 January, 1999 - 10:44 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 7-08A Your Ref: API-500292029601 Job No. AKMW90056, Surveyed: 5 January, 1999 Prudhoe Bay Unit , . Alaska State Plane Zone 4 PBU_EOA DS O7 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9500.00 8694.60 2329.17 N 1268.03 E 9598.00 8772.03 2346.98 N 1325.39 E 10948.00 9022.63 2219.55 N 2533.56 E Comment Tie on Point Window Point Projected Survey 22 January, 1999 - 10:44 - 4 - DrillQuest TONY KNOWLE$, GOVEF{IVOF~ ~L&S~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 8, 1998 Erin Oba ARCO Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoc Bay Unit 07-08A ARCO Alaska, Inc. Permit No: 98-244 Sur Loc: 1215'S & 166%V of NE er, Sec. 33, T11N, R14E, UM Btmhole Loc. 4586'FNL, 2584'FEL, Sec. 27, T1 IN, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Commissio~ ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game, Habitat Section xv/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PfiRMIT TO DRILl_ 20 AAC 25.005 la. Type of work: Ddll t Reddll tX I lb. Type of well. Exploratory t Stratigraphic Test Re-entry t Deepen tI Service t Development Gas m Single Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64 feet 3. Address 6. Property Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28309 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251 1215'S & 166'W of NE cr, SEC. 33, T11 N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1069' N & 1062' E of SW cr, SEC. 27, T11 N, R14E, UM 07-08A #U-630610 At total depth 9. Approximate spud date Amount 4586' FNL, 2584' FEL, Sec 27, T11N, R14E, UM December 7, 1998 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) feetI No Close Approach feet 11375' MD / 8996' 'I'VD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 9610' MD Maximum hole angle 91 ° Maximum surface 2500 psig At total depth ('rVD) 3321 psig @ 8800' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-1/8" 3-3/16" 6.2 L-80 TC II 2425' 8950' 8234' 11375' 8996' 18 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 10105 feet Plugs (measured) PBTD tagged @ 9905' MD (9/14/98) true vertical 9174 feet Effective Depth: measured 9905 feet Junk (measured) true vertical 9013 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 119' 20" 271Sx Arcticset g~)%~G~~~ 119' 119' Surface 2648' 13-3/8" 3700 Sx ArcticSet II 2712' 2712' Production 10018' 9-5/8" 1200 Sx Class G 10082' 9146' RECEI'VED Perforation depth: measured 9886'- 9921'; 9926'- 9933'.2 1998 true vertical 8998' - 9026'; 9030' - 9035'. Alaska 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee tX Property Plat t BOP Sketch _X Diverter Sketch Drilling fluid program t Time vs depth plot t Refraction analysis _ Seabed report 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Stephen Ward @ 256.1305. Signed ~,~ ~ , ~ Title Arco Engineering Supervisor Date r E#n Oba Prepared by Paul Rauf 263-4990. Commission Use Only Permit Number I APl number I Approjva~..at JSee cover letter ~,~:~'-- ~__., ~'.~-~ 50- (:::~-2.. ~-.-~..(:3.2- (:~*--~C3~/ ---e~-?l~ Ifor other requirements Conditions of approval Samples required t Yes~o Mud log required m Yes.'No Hydrogen sulfide measures .~"¥es t No Directional survey required ,,~'Yes t No Required working pressure for BOPE t 2M; t 3M; t 5M; t 10M; t 15M (~ 350~psi for CTU Other: Original Signeci, By by orderof L~av'd W- JohJ~s,o~l Commissioner Approved by the commission Date '--- Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 7-08A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 3-3/16" cemented liner. Perforate and produce. Intended Procedure: · Cement squeeze and plugback the existing completion to -~ 9030' md. · Mill window in 9-5/8" casing at -9610' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. · Directionally drill 4.125" x 1300' horizontal well to access Lower Romeo reserves. Build angle to -91 o at TD. · Run and cement 3-3/16" liner to TD. · Perforate selected intervals. · Place well on prodUction. NOTE: Drill cuttings will be disposed of at CC2A and drilling mud will be disposed at Pad 3. November 19, 1998 DS 7-08A Proposed CT Sidetrack Horizontal 5-1/2" Tubing 5-1/2" DB Nipple 8804' 4.223" ID Packer 8903'-- 2151' 8718' 5-1/2" BaI-O SSSV Nipple ID = 4.562" 5-1/2" XA Sliding Sleeve ID - 4.562" 4-1/2" Top of 2-7~8" Liner in 4-112" Tbg. tail. Initial Perfs~ 1000' I . ..: ::~. · :::.i' :.:':?.:~:'!;i::.:..:.:!::!i:!.i~. :,ii':':'.~::':~:..,i::~. Window cut in 9-5/8" at TD ~ ....:.... [:::::i:::~':!:!~':i:'!!!! i ~:!!:i;i;;:;ii':!::~!!ii!!iiiiiii::'..:i:.:~J Current perforations 9-5/8" C,~,,~j ~:::::?:::::::::::::::::::::::%:::::::::::::::::::?:::::::::::::::::::::::::::::::::::::?:::~` . . shoe @10082' ==================================??================ ......... ' ....cemen[ squeezea ARCO Alaska, Inc. StCuc"lufe : D.S. 7 Slot : Field ' ?~ud~a~e B,a¥ I.~cc~11on ' ~l~dh Slope, Ala~kai East -> 1~'00 1.'~0 1~00 1~0 1600 1 ~ 1000 19~ 2000 2'1(~ 2~'00 2-~0~ 2~400 2500 ~00 2.n~O ~800 2gOO .5000 .~100 ' %72. & Ef, Cl oF ~L~ICl - flg~,60 Tvc~ IgOgD~ H, ~flb~40d E ~ r-nee.ha I i I J I i I i I i I i I ! I i I , I i I i I i I i I ! I , I i I i I i I , I i I , Verficol Section (qeeJ) -:> 2/'0O 2600 2500 .,~_.... 2qOO 2300 I 2~00 --m- 2100 ~ 2000 I90O I BOQ 1 tO0 Azl'~u~h lO~.OO wi'~ rel:erence O.(~O lq, 0.00 ( I~r~rn 7--48 7-08Aplan.xls Page1 Measured Depth 9600.00 9625.00 9650.00 9675.00 9700.00 9720.00 9725.00 9750.00 9775.00 9800.00 9825.00 9849.09 9850.00 9875.00 9900.00 9925.00 9950.00 9975.00 10000.00 10025.00 10050.00 10075.00 10089.26 10100.00 10118.64 10125.00 10150.00 10175.00 10200.00 10216.00 10225.00 10250.00 10275.00 10300.00 10325.00 10350.00 10375.00 10400.00 10425.00 10450.00 10475.00 10500.00 10525.00 10550.00 10575.00 10600.00 10625.00 10650.00 10675.00 10700.00 10725.00 10750.00 Inclin Degrees 38.52 38.62 38.73 38.83 38.94 39.02 39.67 42.99 46.35 49.76 53.21 56.55 56.68 60.15 63.63 67.10 70.59 74.07 77.55 81.04 84.52 88.01 90.00 90.36 91.00 91.00 91.02 91.03 91.04 91.05 91.05 91.06 91.07 91.08 91.09 91.10 91.11 91.12 91.13 91.14 91.15 91.15 91.16 91.17 91.18 91.18 91.19 91.19 91.20 91.20 91.21 91.21 Azimuth Degrees 72.30 72.18 72.06 71.94 71.83 71.73 72.31 74.98 77.33 79.43 81.33 83.00 83.03 83.71 84.35 84.95 85.52 86.06 86.59 87.10 87.61 88.11 88.39 88.61 89.00 89.25 90.25 91.25 92.25 92.89 93.25 94.25 95.25 96.25 97.25 98.25 99.25 100.25 101.25 102.25 103.25 104.25 105.25 106.25 107.25 108.25 109.25 110.25 111.25 112.25 113.25 114.25 True Vert True Coordinates Depth X Y 8709.70 2347.25N 1326.51E 8729.24 2352.01N 1341.35E 8748.76 2356.80N 1356.22E 8768.25 2361.64N 1371.11E 8787.71 2366.52N 1386.03E 8803.26 2370.45N 1397.98E 8807.13 2371.43N 1401.00E 8825.90 2376.07N 1416.84E 8843.68 2380.26N 1433.90E 8860.38 2384.00N 1452.11E 8875.95 2387.26N 1471.39E 8889.81 2389.94N 1490.91E 8890.31 2390.03N 1491.66E 8903.40 2392.49N 1512.81E 8915.18 2394.78N 1534.74E 8925.60 2396.90N 1557.36E 8934.62 2398.84N 1580.59E 8942.21 2400.59N 1604.34E 8948.34 2402.14N 1628.53E 8952.98 2403.49N 1653.05E 8956.12 2404.63N 1677.82E 8957.75 2405.56N 1702.75E 8958.00 2406.00N 1717.00E 8957.97 2406.28N 1727,74E 8957.74 2406.67N 1746.37E 8957.63 2406.77N 1752.73E 8957.19 2406.87N 1777.72E 8956.75 2406.54N 1802.72E 8956.30 2405.78N 1827,70E 8956.00 2405.06N 1843.68E 8955.84 2404.58N 1852.67E 8955,38 2402.94N 1877.61E 8954.91 2400.87N 1902.52E 8954.44 2398.37N 1927.39E 8953,97 2395.43N 1952.21E 8953.49 2392.06N 1976.98E 8953.01 2388.25N 2001.68E 8952.52 2384.02N 2026.32E 8952.03 2379.36N 2050.87E 8951.53 2374.27N 2075.34E 8951.03 2368.75N 2099.72E 8950.53 2362.81N 2124.00E 8950.03 2356,45N 2148.17E 8949.52 2349.66N 2172.23E 8949.01 2342.46N 2196.16E 8948.49 2334.84N 2219.97E 8947.97 2326.81N 2243.63E 8947.46 2318.36N 2267.16E 8946.93 2309.51N 2290.53E 8946.41 2300.25N 2313.75E 8945.88 2290.59N 2336.80E 8945.36 2280.52N 2359,67E Dogleg Deg/100ft 0.00 0.51 0.51 0.51 0.51 0.51 15.00 15.00 15.00 15.00 15.00 15.00 14.09 14.09 14.09 14.09 14.09 14.09 14.09 14.09 14.09 14.09 14.09 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 Vert ASP Coordinates Sect X Y 628.13 677306.92 5952083.21 641.09 677321.65 5952088.31 654.06 677336.40 5952093.45 667.04 677351.17 5952098.63 680.04 677365.97 5952103.86 690.44 677377.82 5952108.07 693.07 677380.81 5952109.12 707.02 677396.54 5952114.13 722.26 677413.50 5952118.72 738.74 677431.62 5952122.88 756.37 677450.82 5952126.59 774.40 677470.26 5952129.73 775.09 677471.01 5952129.84 794.75 677492.10 5952132.79 815.20 677513.97 5952135.59 836.36 677536.53 5952138.24 858.15 677559.71 5952140.72 880.50 677583.41 5952143.02 903.32 677607.55 5952145.14 926.52 677632.03 5952147.07 950.02 677656.77 5952148.79 973.72 677681.67 5952150.30 987.30 677695.90 5952151.07 997.55 677706.63 5952151.61 1015.35 677725.24 5952152.43 1021.44 677731.60 5952152.68 1045.43 677756.59 5952153.37 1069.55 677781.58 5952153.62 1093.78 677806.57 5952153.44 1109.34 677822.56 5952153.10 1118.11 677831.56 5952152.83 1142.53 677856.53 5952151.78 1167.05 677881.48 5952150.29 1191.65 677906.40 5952148.37 1216.32 677931.28 5952146.01 1241.05 677956.12 5952143.22 1265.85 677980.90 5952140.00 1290.69 678005.63 5952136,34 1315.58 678030.28 5952132.26 1340.51 678054.87 5952127.74 1365.46 678079.37 5952122.80 1390.44 678103.77 5952117.43 1415.43 678128.09 5952111.63 1440.42 678152.29 5952105.41 1465.42 678176.39 5952098.77 1490.40 678200.36 5952091.71 1515.36 678224.21 5952084.24 1540.30 678247.93 5952076.35 1565.21 678271.50 5952068.04 1590.08 678294.92 5952059.33 1614.90 678318.19 5952050.21 1639.67 678341.30 5952040.68 Ref. Point Measured Depth 1 O775.OO 10800.00 10825.00 10850.00 10875.00 10900.00 10925.00 10950.00 10975.00 11000.00 11025.00 11050.00 11075.00 11100.00 11125.00 11150.00 11175.00 11200.00 11225.00 11250.00 11275.00 11300.00 11325.00 11350.00 11375.00 11375.88 Inclin Degrees 91.22 91.22 91.22 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.23 91.22 91.22 91.22 91.21 91.21 91.20 91.20 91.19 91.19 Azimuth Degrees 115.25 116.25 117.25 118.25 119.25 120.25 121.24 122.24 123.24 124.24 125.24 126.24 127.24 128.24 129.24 130.24 131.24 132.24 133.24 134.24 135.24 136.24 137,24 138,24 139.24 139.28 7-08Aplan.xls True Vert True Coordinates Depth X Y 8944.83 2270.06N 2382.37E 8944.29 2259,20N 2404.89E 8943.76 2247.95N 2427.21E 8943.23 2236.32N 2449.33E 8942.69 2224.30N 2471.24E 8942.16 2211.90N 2492.94E 8941.62 2199.12N 2514.42E 8941.08 2185.97N 2535.68E 8940,55 2172.45N 2556.70E 8940.01 2158.57N 2577.48E 8939.47 2144.32N 2598,02E 8938,93 2129.72N 2618.31E 8938.39 2114.77N 2638.33E 8937.86 2099.47N 2658.10E 8937.32 2083.83N 2677.59E 8936.78 2067.85N 2696.81E 8936.25 2051.54N 2715.75E 8935.71 2034.89N 2734.40E 8935.18 2017.93N 2752,75E 8934.65 2000.65N 2770.81E 8934.12 1983.06N 2788.56E 8933.59 1965.16N 2806.01E 8933.06 1946.95N 2823.13E 8932.54 1928.46N 2839.94E 8932.02 1909.67N 2856.43E 8932.00 1909.00N 2857.00E Dogleg Deg/100ft 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4,00 Page 2 Ved ASP Coordin~es Sect X Y 1664.37 678364.23 5952030.75 1689.01 678386.99 5952020.43 1713.56 678409.57 5952009.70 1738.03 678431.95 5951998.59 1762.41 678454.14 5951987.09 1786.69 678476.12 5951975.20 1810.86 678497.90 5951962.93 1834.91 678519.45 5951950.28 1858.85 678540.78 5951937.26 1882.65 678561.88 5951923.86 1906.32 678582.75 5951910.11 1929.85 678603.37 5951895.99 1953.22 678623.74 5951881.51 1976.44 678643.86 5951866.68 1999.49 678663.71 5951851.49 2022.37 678683.30 5951835.97 2045.06 678702.61 5951820.11 2067.58 678721.64 5951803.91 2089.90 678740.39 5951787.38 2112.02 678758.84 5951770.53 2133.93 678777.00 5951753.36 2155.64 678794.86 5951735.87 2177.12 678812.41 5951718.07 2198.37 678829.64 5951699.98 2219.40 678846.56 5951681.58 2220.13 678847.15 5951680.93 Ref. Point Total Length' 1655.88 C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ -- 7" Riser Methanol Injection ~ I tis 7" WLA Quick I' '1 onnect ~ Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Ram Type Dual Gate BOPE Hydraulic over Electric 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure 2" Pump-In Cutters or Combination Cutter/Blinds Slip / Pipe rams ManuaIValves Drilling spool 7-1/16", 5M by 7-1/16", 5M Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus RI 6 Alaska LAYOUT WSSSV Tubing-NPC Casing Casing SLS -- NIP -- SBR -- PKR -- XO-- Tubing-NPC -- NIP -- SOSUB-- Perf Perf Perf Perf 07-08 07-08 APl: 1500292029600 I Well Type: ] PROD H2S:I Spud: 112/17/78 SSSV Type:I Orig Compltn:11/9/79 Annular Fluid:I Diesel/10.6 CaCI2 Reference Log: I BHCS Last W/O:11/6/79 Ref Log Date: 1/1/79 I Last Tag: Last Tag Date: Rev Reason: RPERF Last Update: 4/16/98 Elevations RKB: 64 ft KOP: I 0.00 ftKB PBTD: 110105.00 ftKB TD: 10105.00 ftKB Max Hole Angle: 39 deg @ 9650 Ang e ~ TS: 34 deg (~ 9278 t Angle @ TD: 136 deg ~ 10105 t Cas Flng KB 64 ft Tub Head Grd KB-Grd Other (plugs, equip, etc.) - All DepthllD IType 2151 4.562 WSSSV 871810.000 ISLS 880414.223 IN~P 8853 0.000 I SBR 8903 0.000 PKR 8915 0.000 XO 8975 3.759 NIP 9035 0.000 I SOSUB 9036 0.000 TTL General Notes oft Off Oft 64 ft Description 5-1/2" Camco BAL-O SSSV Nipple 5-1/2" Baker Sliding Sleeve 5-1/2" Baker Landing Nipple 5-1/2" Baker SBR Assembly 9-5/8" x 5-1/2" Baker SAB Packer Crossover 5-1/2" x 4-1/2" 4-1/2" Baker Nipple 4-1/2" Baker Shearout Sub 4-1/2" Tubing Tail Date Note 'rTL ELM (~ 9038: ELM Tubing Tail (Logged 01/08/79) Daterun: 1979-01-09 18975 Min ID = 3.759" (4-1/2" Baker Nipple) Casing String - SURFACE Item Top Btm (in) (ftKa) (ftKB) 13.375 in Casing 0.00 2712.00 Casing String - PRODUCTION Wt72.00 Grd N-80 Item Top Btm (in) (ftKB) (ftKB) 9.625 in Casing 0.00 10082.00 Wt47.00 Grd N-80 Tubing String - TUBING Item (in) 5.500 in Tubing-NPC 4.500 in Tubing-NPC Perforations Interval 9729-9745 9745-9752 9752-9756 9756-9760 Top I BoEom (ffKB) I (ffKB) 0.00 8915.00 8915.00 9036.00 9760-9764 9764-9765 9798-9843 9853-9863 9876-9921 9926-9933 stimulations & Treatments Len 8915 (ft) 121 17.00 12.60 Grd L-80 L-80 RPERF RPERF RPERF RPERF RPERF Comment RPERF RPERF Interval Date 9729- 9933 1/8/90 sQzType Comment STATE OF ALASKA ~'- ,._ASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend _ Operational shutdown _ Re-enter suspended well_ 1. Type of request: Alter casing _ Repair well _ Plugging _X Time extension _ Change approved program _ Pull tubing _ Vadance _ Stimulate _ Perforate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1215' S & 166' W of NE cr, SEC. 33, TllN, R14E, UM At top of productive interval 1069' N & 1062' E of SW cr, SEC. 27, TllN, R14E, UM At effective depth At total depth 1214' N & 1541' E of SWcr, SEC. 27, TllN, R14E, UM 5. Type of Well: DeveLopment Exploratory _ Stratigraphic _ Service __ 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 07-08 9. Permit number/approval number 78-16 10. APl number 50-029-20296 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10105 feet Plugs (measured) 9174 feet PBTD tagged @ 9905' MD (9/14/98) Effective depth: measured true vertical 9905 feet Junk (measured) 9013 feet Casing Length Conductor 119' Surface 2648' Production 10018' Perforation depth: true vertical 89~, Size Cemented Measured Depth ~ True vertical Depth 20" 271 Sx Arcticset 119' \ \ ~..119' 13-3/8" 3700 Sx",~rcticSet II . 2712' ~ 2712' 9-5/8" 1200 Sx Class G 10082' 9146' measured 9886'- 9921'; 9926'- 9933~ 2. 1998 Alaska 0il & Gas Cons. Commission Tubing (size, grade, and measured depth) 5-1 Packers and SSSV (type and measured depth 13. Attachments Description summary of 14. Estimated date for commencing operation ":'"~ -- I 15. Status of well classification as: November 30, 1998 I 16. If proposal was verbally approved . Oil __X Gas __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 6 Anchorage '.", lr~?C'"'~@ 8811' MD; 4-':1/2" 0 NPCT @ 9036' MD. ,~:'E/8" x 5-~' Baker SAB t~i ~ 8.90__3'2; ~5-1,2" Camco BAL-0 SSSV ~ 2151' MD. prop~~~per~program BOP sketch __X Suspended__ Questions? Call Stephen Ward @ 250-1305. Edn Oba Title Arco Engineering Supervisor FOR COMMISSION USE ONLY Date ~'/- I ~'- Prepared by Paul Rauf 263-4990 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10-... Approved by order of the Commission Commissioner Approval no. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. ~' (. Check ,' EFT/~: AAI PAYABLES Date: 11/19~ Page o~00100Q8~.. 0 0 6 8 6 P.O. Box 102776 va:, Entity: v~ao~ ~: Anchorage, AK 99510 o~o~ ~ooo~o~o~ DATE, ' INVOICE'NU:MBER VOUC.,,Hm, ~cam .GROSS 11/18/98 ~111898S~01 ClllP 119 S~ 100.00 100.00 FILING FEE FOR PE~IT TO )RILL SIDETraCK WELL 07-08A · .' ",:' "~:'.~..."~:~, :.'~'.'~::;7~., .. , · . ·.. · .... .; . . '.., ...... :,.~.;:' . ~.~ .~:':,~'~,~%;~ :, · .. ..... ~;.~j..::'.' .."..:~ .~'.' ....: ~...~".~..'.'....2.;'.....:........;..,:. .... .... [. 2 ............... ,,,., .': '....: ::..~:..........~i......~...:::.:....:..:....'~ ~ · .. ., .. . .... .... ..............'.': :....:.... ~.~. ~' .'~..~ .... . .........~..::....:....:.............::..;:' ..:.. :'],.:' .~ ?.~ , · ' ' ': ":" ':" 7. : '" ............. ·: ..... '" Y? '. r,.q ~':i.'" ' : ' ,' "'...." ,i.',' .' ' ' ~ ~ .. .. ',~ >I.'~"',~,~ j: .~ ' . .....~ ......... .:.: ...... . ;:' ~.' ' ':'.""¢: .'.::~4:,..:,> · ',. ;. ..'..' ..... . , .,..~ ~ . ~...'."~..~ .~.~ , . '. ..... ,...,,.,..~, ..~ ,.o,.~.,~. . . ... , ... , .,... ~,;' ~. '2~,.'?~ ~.,:, %:';, ::.. ,,,,,., .,.. . ~.. :'?.:.)~ ~:.~.~',~,~,~.'.,... . :"::',~ · . ,. ~, . , ,..,.:,~ ~, ~. ,,~, .? ~..'~ . . ... . : ..~, · ~,~ ~ ~,...;;":, ", ~ .~ ~:: ~.~,~. ,., .~,. ...... .... , ' ' ,'.'[L~.~.~..k,,[:':~::' ..." ' ~ . 100.00 ~00,00 Y g g: FRT 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 MATLSg07/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 5VCS 907/265-6080 P.O. BOX 103240, Anchorage, AK 99510-3240 DIAL 907/263-4422 Detach check before depositing ,.. : ,' .' ', . ....... :.:,,...':.. ....i"i :::'."::' "::' "': "!~;~'~ble ['hr~u' · ...... ..... ":':' :' ..... ~ . . , ......... :' .: : ! .:., ' .... ! :: ' l~.ep~ic ~ahl~ St~e~byvtff~. I(.~lM~ck~ ' :" ' i ' F;O~.::~B0.X:...:10277§"..:;' '::: :'.:'..~.'!i'/'.~'il ...:' ~:i '.'..::7' ":': :" ,~: '~.:'.":: ? ::.' . i 'i:: !:':. ...:!: ::' ":..: '~::.: :.. :.':' ! ":::;.:;:...: '~:' :' :'..: '.~:':"::..::.: '. i :~. '..::~' ::~..:;' ':.~ :.... ':':' ~ . ~ ...... :~:.: ,'...; .... ~: '. An~h0i;~:;.'AK.::.i;g951:~.'..:.:.."::'.::::.';"~i::'"::i:......:::..:.:. :.: ,!:' ?:::;:..:::.. : " :.?:..i, .::" ' ..:.':'. ":i .:: ........ '~:'"'""" :: .... .i'!'" :.:':.,:'.:::.'.:' ;:';'" ::'.. ':~: :":': ' '::'::"'~':".' '::':,'?,: ;? ;?? :;:?::.::: ?'?::i?:.> i - 6~,,.m~m~.~.r~ i~6~s".:~...~o c~.~;S · .... ~ .......... pay (*'Amount Not To ~ed $~,000.00'*) To the order o~ ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMISSION 30011 PORCUPINE DRIVE ANCHORAGE ~ 99501 Date 11-19-98 ,'PYBt~N. AN?I-FRAUO PROTECTION · PATENTS 4 210 34r,: 4.227,720: 4,310,'1B0; fi,l~?,?OS ~,~b,l'S~,,, ***********.*** 100.00' Amount Void after 90 days /~ ~WO.:$ignatures mqUl:md -- ~d for amounts:over ,'OOOOiOO&f&,' ':OfiSqOhS&8~: 0 q qO000,' · WELL PERMI'~ CHECKLIST COMPANY _..~.,"_c... ,,-, : _ WELL NAME PROGRAM: exp ['3 der7 redrll~'serv [] wellbore sag II ann. disposal para req ' ~ FIELD & POOL ADMINISTRATION 1 11. AP_PR DA'fE, 12. INIT CLASS ~?,~_ t. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4 Well located in a defined pool .................. 5. Well Iocaled proper distance front drilling unit boundary 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unil ........... 8. I! deviated, is we,bore plat included ............... 9. Operator only affected pady ................... 0. Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17. CM I' vol adequale to tie-in long string to surf csg ........ 18. CM[ will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B 8, permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a '10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do tt~ey meet regulation ................ 26. BOPE press rating appropriate; test to ~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE GEOL AREA ~.~ ,~ "Y-'N G~N ON/OFF SHORE 4:~_: N N Is presence of H2S gas probable ................. N Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... Y ~ Seismic analysis of shallow gas zones. ' . . . Seabed condition survey (if off-shore) ............. '.':i'ii'.~:~:_:i:.-._ii ii..'..' .... iii..... "..' ....'.' .' '. ': '..' Co.ntact.nam. e/phon,e.for weekly progress reports ....... . lexp~ora~ory on~yJ " With proper cementing records, this plan (A) will contain waste in a suitable receiving zo.o~; ....... (B) will not conta.~.~jgate freshwater; or caus. C'drilling waste.. , to ~!,rfac ,e¢~ . ~ (C) will nOl impair mechanical integril.~f the well ~ for disposal', (r)) will nol damag~ produci~tion or impair recovery from a pool; and (E) will no! circurnvent 20 AA.C 25.252 or 20 AAC 25.412, Y N Y N .G__E__O.~:_O_G..Y_: ENGINEERING: RPC .............. BEWl;~'~,-~'¢_J,,~' UIC_~n__n.~_r COMMISSION: ~ RNC._ '~ . , ~ Comments/Instructions' M chel~lisl lu?v 05/2919t~1 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. I Sperry-Sun Drilling Services LIS Scan Utility Thu Jun 17 08:47:48 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header .Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: D.S. 7-08A 500292029601 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-JUN-99 MWD RUN 3 MWD RUN 5 AK-MW-90056 AK-MW-90056 D.LABRECQUE D.LABRECQUE MARK JOHNSON MARK JOHNSON MWD RUN 11 AK-MW-90056 D.LABRECQUE MARK JOHNSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 12 AK-MW-90056 W. JACKSON MARK JOHNSON MWD RUN 13 AK-MW-90056 W. JACKSON MARK JOHNSON liN 14E MWD RUN 14 AK-MW-90056 W. JACKSON ANDY KIRK FNL: 1215 FSL: FEL: 166 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 64.00 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 9610.0 PRODUCTION STRING 3.750 10948.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL MWD RUNS ARE DIRECTIONAL WITH NATUARL GAMMA PROBE (NGP) UTILIZING A SCINTILATION DETECTOR.. 3. MWD RUNS 1,2,6-10,AND 15-16 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. DIGITAL DATA IS SHIFTED TO THE PDC LOG (CNL OF 2/4/99). KBE = 64 FT. 5. MWD RUN 3,5 and 11-14, REPRESENTS WELL DS 07-08A, API# 50-029-20296-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10948'MD, 8958'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA P~AY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9500.0 10920.0 ROP 9534.5 10952.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 9500.0 9500.0 9506.0 9506.0 9507.0 9508.0 9514.0 9515.0 9583.5 9583.5 9623.0 9622.5 9637.5 9637.5 9645.5 9645.0 9647.5 9647.0 9650.5 9650.0 9653.0 9652.5 9675.5 9674.0 9677.0 9675.5 9679.5 9678.5 9689.5 9689.0 9702.0 9701.0 9707.5 9706.5 9711.5 9710.5 9716.5 9715.0 9717.5 9716.0 9722.5 9721.0 9731.0 9730.0 9734.5 9733.0 9739.5 9737.0 9745.5 9744.5 9748.0 9747.0 9754.0 9752.5 9784.5 9782.5 9805.0 9803.0 9808.5 9807.0 9810.0 9808.5 9813.5 9812.5 9817.0 9815.0 9831.5 9829.0 9833.5 9830.5 9835.0 9832.5 9842.5 9838.5 9848.0 9845.5 9854.0 9852.0 9857.0 9855.0 9860.5 9858.5 9863.5 9860.5 9865.5 9862.5 9876.5 9874.0 9878.0 9875.5 9901.0 9898.5 9904.5 9901.5 9908.5 9905.5 9910.0 9907.0 9918.5 9916.0 9923.0 9920.5 9925.0 9922.0 9926.5 9923.5 9933.0 9930.0 9939.0 9942.5 9944.0 9947.5 9955.5 9960.5 9962.5 9968.0 9974.0 9991.5 9993.0 9995.5 9997.0 10000.5 10008.0 10009.5 10010.5 10030.0 10034.0 10036.0 10040.5 10054.5 10056.0 10058.0 10069.5 10076.5 10083.5 10089.5 10094.0 10095.5 10097.0 10099.5 10111.0 10118.0 10123.0 10129.0 10132.0 10149.5 10155.5 10159.5 10164.0 10172.0 10174.5 10175.5 10180.5 10380.0 10381.5 10382.5 10387.5 10421.0 10422.5 10447.5 10489.5 10495.0 10497.5 10502.0 10504.5 9936.0 9939.5 9941.0 9944.5 9952.5 9957.5 9959.5 9964.5 9970.5 9988.0 9990.5 9992.5 9994.0 9998.0 10004.5 10005.5 10006.5 10027.5 10031.5 10033.5 10038.0 10052.0 10053.5 10054.5 10066.0 10075.0 10082.0 10087.0 10092.5 10094.0 10095.5 10098.0 10110.5 10116.0 10121.0 10127.0 10129.5 10148.0 10153.0 10155.5 10161.5 10169.0 10172.0 10173.5 10177.5 10377.5 10379.0 10380.5 10385.5 10419.0 10420.5 10446.0 10486.5 10490.5 10494.0 10499.0 10503.0 10520.0 10524.5 10525.5 10532.0 10535.5 10539.5 10546.5 10548.0 10554.0 10560.5 10570.5 10583.0 10589.5 10604.5 10612.0 10620.0 10623.0 10625.0 10632.5 10634.0 10639.5 10659.5 10673.5 10698.5 10700.5 10703.0 10706.0 10709.5 10726.5 10728.5 10759.5 10768.5 10779.0 10788.0 10799.5 10815.5 10823.5 10829.5 10839.5 10856.0 10858.0 10920.0 10952.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: 10517.0 10521.0 10522.0 10528.5 10533.0 10537.0 10543.0 10545.5 10552.0 10558.0 10567.0 10580.0 10585.0 10600.5 10608.5 10616.5 10620.0 10621.5 10629.0 10630.5 10636.0 10656.5 10670.0 10695.0 10697.0 10699.0 10702.0 10706.5 10722.0 10724.5 10755.5 10765.0 10775.5 10784.5 10795.5 10813.0 10821.0 10827.0 10835.5 10852.0 10854.0 10916.0 10948.0 BIT RUN NO 3 5 11 12 13 14 MERGED MAIN PASS. $ MERGE TOP 9246.0 9610.0 9618.0 10050.0 10150.0 10932.0 MERGE BASE 9610.0 9618.0 10050.0 10150.0 10932.0 10948.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9500 10952 10226 2905 9500 ROP 9.36 3301.88 67.2972 2836 9534.5 GR 17.42 210.96 48.1039 2841 9500 Last Reading 10952 10952 10920 First Reading For Entire File .......... 9500 Last Reading For Entire File ............ 10952 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9500.0 ROP 9535.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9581.5 9609.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 31-DEC-98 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 9610.0 9246.0 9610.0 .0 TOOL NUMBER PCG 61 3.750 3.8 BIO SEA WATER .00 .0 .0 0 .0 .000 .000 .000 .000 70.0 .3 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9500 9609.5 9554.75 220 9500 GR 17.42 51.89 25.2248 164 9500 ROP 12.05 73.86 26.376 150 9535 Last Reading 9609.5 9581.5 9609.5 First Reading For Entire File .......... 9500 Last Reading For Entire File ........... 9609.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9586.5 ROP 9610.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9590.0 9617.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record 02-JAN-99 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 9620.0 9620.0 9620.0 .0 .0 TOOL NUMBER PCG 61 3.750 3.8 BIO SEA WATER .00 .0 .0 0 .0 .000 .000 .000 .000 70.0 .3 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9586.5 9617.5 9602 63 9586.5 GR 22.94 24.73 23.4931 8 9586.5 ROP 265.87 365.1 334.989 16 9610 Last Reading 9617.5 9590 9617.5 First Reading For Entire File .......... 9586.5 Last Reading For Entire File ........... 9617.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9594.0 ROP 9618.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10017.0 10050.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE ,(MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS Data Format Specification Record Data Record Type .................. 0 05-JAN-99 MSC 1.32 PCG 7.53 MEMORY 10050.0 9629.0 10050.0 38.5 66.4 TOOL NUMBER PCG 41 3.750 3.8 FLO-PRO 8.80 45.0 8.8 10.0 .000 .000 .000 .000 .3 PCD 3.01e 129.0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 API 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Readin9 DEPT 9594 10050 9822 913 9594 GR 17.87 189.92 41.37 847 9594 ROP 12.21 539.68 72.2493 865 9618 Last Readin9 10050 10017 10050 First Readin9 For Entire File .......... 9594 Last Readin9 For Entire File ........... 10050 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 R3%W MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10025.5 ROP 10050.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10125.0 10149.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 06-JAN-99 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 10150.0 10050.0 10150.0 66.0 82.9 TOOL NUMBER NGP SPC 165 3.750 3.8 FLO - PRO 8.80 .0 9.0 6.7 .000 .000 .000 .000 141.7 .3 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 API 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10025.5 10149.5 10087.5 249 10025.5 GR 39.45 141.96 64.1134 200 10025.5 ROP 20.87 104 50.2266 199 10050.5 Last Reading 10149.5 10125 10149.5 First Reading For Entire File .......... 10025.5 Last Reading For Entire File ........... 10149.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10125.5 ROP 10151.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10900.5 10932.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PM: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 08-JAN-99 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 10932.0 10150.0 10932.0 87.6 96.1 TOOL NUMBER NGP SPC 165 3.750 3.8 FLO-PRO 8.90 .0 9.5 5.2 .000 .000 .000 .000 154.3 .3 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 API 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam 'Reading DEPT 10125.5 10932 10528.8 1614 10125.5 GR 30.03 210.96 52.6718 1551 10125.5 ROP 9.36 670.19 47.3137 1562 10151.5 Last Reading 10932 10900.5 10932 First Reading For Entire File .......... 10125.5 Last Reading For Entire File ........... 10932 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10901.0 ROP 10919.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet STOP DEPTH 10916.0 10948.0 09-JAN-99 MSC 1.32 PCG 7.53 PCD 3.01e MEMORY 10948.0 10932.0 10948.0 .0 .0 TOOL NUMBER NGP SPC 41 3.750 3.8 FLO-PRO 8.90 .0 9.5 5.2 .000 .000 .000 .000 154.3 .3 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name' Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 API 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10901 10948 10924.5 95 10901 GR 43.45 91.05 63.7037 31 10901 ROP 26.68 19485.1 3255.36 58 10919.5 Last Reading 10948 10916 10948 First Reading For Entire File .......... 10901 Last Reading For Entire File ........... 10948 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 07-08A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292029601 REFERENCE NO : 99093 REC, VED /~aska OiJ & Gas Cons. Commission LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02i PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/ 2 ORIGIN : FLIC REEL NAME : 99093 CONTINUATION # : PREVIOUS REEL : COHerENT : ARCO ALASKA, PRUDHOE BAY, DS 07-08A, API #50-029-20296-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/ 2 ORIGIN : FLIC TAPE NAME : 99093 CONTINUATION # : 1 PREVIOUS TAPE : COFIMENT : ARCO ALASKA, PRUDHOE BAY, DS 07-08A, API #50-029-20296-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 07-08A API AUUMBER: 500292029601 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 2-MAR-99 JOB iVUMBER: 99093 LOGGING ENGINEER: J. SPENCER OPERATOR WITNESS: G.SARBER SURFACE LOCATION SECTION: 33 TOWNSHIP: lin RANGE: 14E FNL: 1215 FSL: FEL: 166 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 10082. 0 47. O0 2ArD STRING 3. 500 10937.0 9.30 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:0~ BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 1 -JAN-79 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9589.0 9581.0 9563.5 9555.0 9533.5 9518.0 9516.0 9498.5 9496.0 9480.0 9459.5 9442.0 9440.5 9416.5 9387.5 9333.5 9319.0 9299.0 9278.5 9273.0 9239.5 9225.5 9220.0 9190.0 9157.0 9152.5 9150.5 9040 0 8945 0 8745 5 8706 5 8706 0 8704 5 8703 5 8639 0 8607 0 8606 0 8588 5 8588 0 8569 5 8567.5 8567.0 8563.5 8538.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH MCNL .............. 88885.0 88885.0 9586.0 9586.0 9578.5 9578.5 9560.5 9560.5 9552.0 9552.0 9529.5 9529.5 9514.0 9494.0 9438.5 9384 0 9330 5 9315 0 9296 5 9276 5 9271 0 9238 0 9224 0 9218 0 9188 0 9156 0 9150 5 9149 0 9038 0 8942 5 8747 0 8707 0 8705.0 8639.0 8607.0 8588.5 8569.5 8567.0 8539.5 9514.0 9494.0 9478.0 9456.5 9438.5 9413.0 9384.0 9330.5 9315.0 9296.5 9276.5 9238.0 9224.0 9218.0 9188.0 9156.0 9150.5 9149.0 9038.0 8942.5 8747.0 8707.0 8705.0 8639.0 8607.0 8588.5 8569.5 8567.0 8539.5 PAGE: .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:0~ 8518 5 8514 0 8497 0 8485 5 8484 0 8469 5 8459 5 8447 5 8428 0 8407 5 8404 5 8402 0 8397 0 8385 5 8384 0 8359.0 8347.0 100.0 $ REMARKS: 8519.5 8519.5 8514.5 8514.5 8498.5 8498.5 8484.5 8484.5 8470.5 8470.5 8461.0 8461.0 8447.0 8447.0 8430.5 8409.0 8405.5 8405.5 8398.0 8398.0 8386.0 8386.0 8360.0 8360.0 8348.0 8348.0 101.0 101.0 CONTAINED HEREIN IS THE MCNL DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 07-08A ON 4-FEB-99. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE MAIN PASS GRCH TO THE BASELINE GAM~A RAY PROVIDED BY THE CLIENT (GR.BCS); AND THE MAIN PASS NRAT TO GR.BCS. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. *NOTE: THE BASE GAM~A RAY (GR.BCS) IS FROM THE PARENT WELL. NO DEPTH SHIFTS WERE APPLIED TO THE MCNL DATA BELOW THE KICK-OFF POINT OF 9610'. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~9~ARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10909.0 8334.0 MCNL 10918.0 8334.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH MCNL REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNL MAIN PASS. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ArOFIB SAMP ELEM CODE (HEX) CCL CNT V 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1257049 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10915.000 GRCH. CNT -999.250 NCNT. CNT 7047.807 iFRAT. CNT 15.199 CCL.CNT -999.250 GR.BCS -999.250 DEPT. 2712.500 GRCH. CNT -999.250 NCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GR.BCS 51.900 FCNT. CNT FCNT. CNT 387. 885 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8521.0 8336.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: MCNL 8530.0 8336.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ArUMBER: 1 BASELINE DEPTH 88888.0 8515.0 8509.0 8498 0 8497 5 8493 0 8484 0 8472 0 8470 0 8460 0 8456.0 8449.5 8445.5 8443.5 8420.5 8413.0 8404.5 8391.5 8385.5 8381.0 8378.5 8371.0 8357.0 8345.0 100.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH MCNL .............. 88887.5 88890.5 8514.5 8499.0 8493.0 8484.5 8470.5 8461.5 8456.0 8449.0 8443.5 8412.0 8405.5 8386.0 8379.5 8371.0 8358.0 8346.5 101.5 8511.5 8499.0 8493.5 8471.5 8447.0 8420.5 8391.5 8380.5 99.5 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNL REPEAT PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE REPEAT PASS GRCH TO THE MAIN PASS GRCH; AND THE REPEAT PASS NRAT TO THE MAIN PASS NRAT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. $ .LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: 7 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1257049 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 1257049 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1257049 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 1257049 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 1257049 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V 1257049 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. NRAT. CNT DEPT. NRAT. CNT 8532.500 GRCH. CNT -999.250 NCNT. CNT 2225.050 FCNT. CNT 14.622 CCL.CNT -999.250 8335.500 GRCH. CNT -999.250 NCNT. CNT 1950.165 FCNT. CNT 44.529 CCL.CNT -999.250 57.868 55.814 ** END OF DATA ** LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NU~BER: 1 DEPTH INCREMENT: 0.1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10927.33 8318.73 MCNL LOG HEADER DATA DATE LOGGED: 4-FEB-99 SOFTWARE VERSION: THERMAL TIME LOGGER ON BOTTOM: 1716 4-FEB-99 TD DRILLER (FT) : 10903.0 TD LOGGER (FT) : 10921.0 TOP LOG INTERVAL (FT): 8330.0 BOTTOM LOG INTERVAL (FT) : 10918.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER MGR 123 LTTN Al3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 10082.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1950 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 37000 TOOL STANDOFF (IN): REMARKS: FIELD PICK GOC = 10150 FT ND TOP OF LINER = 8967 FT MD TAGGED TD AT 10921 FT MD DEPTH OFFSET USED FOR BOTH MAIN AND REPEAT PASSES = +33 FT LOGGING INTERVALS SELECTED BY CLIENT: a.) 8700 FT DOWN TO TD b.) TD UP TO 8300 FT c. ) REPEAT FROM 8500 FT UP TO 8300 FT THIS FILE CONTAINS THE RAW MCNL DATA FOR THE MAIN PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1257049 O0 000 O0 0 3 1 1 4 68 0000000000 CVEL PS1 F/HR 1257049 O0 000 O0 0 3 1 1 4 68 0000000000 GR PS1 GAPI 1257049 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT PS1 CPS 1257049 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT PS1 CPS 1257049 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT PS1 1257049 O0 000 O0 0 3 ~1 1 4 68 0000000000 CCLD PS1 V 1257049 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10927.334 CVEL.PS1 0.000 GR.PS1 -999.250 NCNT. PS1 -999.250 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 -999.250 DEPT. 8318.734 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 -999.250 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 85.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MCNL 8533.95 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH 8317.95 4 -FEB-99 THERMAL 1716 4-FEB-99 10903.0 10921.0 8330.0 10918.0 1800.0 NO TOOL NUMBER MGR 123 LTTN Al3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PAGE: 12 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 10082.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 1950 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 37000 TOOL STANDOFF (IN): REMARKS: FIELD PICK GOC = 10150 FT~iD TOP OF LINER = 8967 FT~iD TAGGED TD AT 10921 FTMD DEPTH OFFSET USED FOR BOTH MAINANDREPEAT PASSES = +33 FT LOGGING INTERVALS SELECTED BY CLIENT: a.) 8700 FT DOWN TO TD b.) TD UP TO 8300 FT c.) REPEAT FROM 8500 FT UP TO 8300 FT THIS FILE CONTAINS THERAW MCNL DATA FOR THE REPEAT PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12:02 PA~E : 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 CVEL PS2 F/HR 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS2 GAPI 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT PS2 CPS 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT PS2 CPS 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT PS2 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 CCLD PS2 V 1257049 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8533.951 CVEL.PS2 0.000 GR.PS2 -999.250 NCNT. PS2 -999.250 FCNT. PS2 -999.250 NRAT. PS2 -999.250 CCLD.PS2 -999.250 DEPT. 8317.951 CVEL.PS2 -999.250 GR.PS2 -999.250 NCNT. PS2 -999.250 FCNT. PS2 -999.250 NRAT. PS2 -999.250 CCLD.PS2 85.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 2-MAR-1999 12: 02 PAGE 14 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 99/03/ 2 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/ 2 ORIGIN : FLIC TAPE NAME : 99093 CONTINUATION # : 1 PREVIOUS TAPE : COF~ENT : ARCO ALASKA, PRUDHOE BAY, DS 07-08A, API #50-029-20296-01 * * * * REEL TRAILER * * * * SERVICE NAME .. EDIT DATE : 99/03/ 2 ORIGIN : FLIC REEL NAME : 99093 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA, PRUDHOE BAY, DS 07-08A, API #50-029-20296-01