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Home My WebLink About198-030 Imag~,._. reject Well History File Cover l'..~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. ]_ ~ c~-~ (~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVER~ VINCENT SHERYL MARIA WINDY Project Proofing BY: BEVERL~~-'~INCENT SHERYL MARIA WINDY _ Scanning Preparation OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERL~INCENT SHERYL MARIA WINDY DATE: IS/ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~') ~, PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: __~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (Sc~NING IS COMPLETE AT THIS POI~ UNLESS SPECI~ A~ENTION 18 REQUIRED ON ~ I~I~DU~ PAGE DUE TO QUALI~, G~YSCALE OR COLOR IMAGES) ReScanned (individual p,_~ge [,~,~ec,"a/aft~.~.tir~j ~¢cannmg c~mipl~.~ed) NO NO RESCANNEDB'Y: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd RECEIVED . STATE OF ALASKA . APR 1 1 200ALASKA OIL AND GAS CONSERVATION CO.SSION Alaska Oil & Gas CoHY.~~QnwLETION OR RECOMPLETION REPORT AND LOG A h Revised 04/10/07' Correct TD Data nc Drage 1a. Well Status: DOil DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other - D Stratigraphic D Service 2. Operator Name: 5. Date Comp., suSP.,_o(Ab~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/4/2007 198-030 306-362 3. Address: ~ 13. API Number 6. Date Spudded r,-,..- -., P.O. Box 196612, Anchorage, Alaska 99519-6612 04/03/1998 50-029-21349-01-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached 14. Well Name and Number: Surface: 04/11/1998 PBU N-22A 706' FSL, 531' FWL, SEC. 08, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2380' FNL, 3971' FWL, SEC. 17, T11N, R13E, UM 80.3' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2096' FNL, 5004' FWL, SEC. 17, T11N, R13E, UM 11741 + 8966 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 634407 y- 5966610 Zone- ASP4 11803 + 8959 Ft ADL 028283 TPI: x- 637912 y- 5963587 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 638939 y- 5963890 Zone- ASP4 N/A MD DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: BHCS lOlL I CNL IGR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE ... AMoUNT SIZE Wr. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE ~ c"....~~~ PUl.LEO 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2693' Surface 2693' 17-1/2" 3720 cu ft Permafrost 'E' & PF 9-518" 47# L-80 Surface 10019' Surface 8492' 12-1/4" 1890 cu ft 'G', 230 cu ft 'G', 674 cu ft 'G' 7" 26# L-80 9748' 10050' 8294' 8514' 8-1/2" 389 cu ft Class 'G' 2-7/8" 6.16# L-80 9862' 11803' 8377' 8959' 3-3/4" 104 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUSING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2",17#, L-80 x 7595' - 9712' 9712' MD TVD MD TVD 4-1/2", 12.6#, L-80 9712' - 9909' 9857' 25. ACIO,- CEMENT :;T~ ...... SCANNED APR 2 6 Z007 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED - 8797' P&A wI 23 Bbls Class 'G' 7595' Cut tubing at 9306', Pulled From 7595' 1814' Cut & Pull 9-5/8" Casing, Cmt wI 674 cu ft 'G' 7240' Set EZSV wI Whipstock on Top 26. PRODUCTION TEST Date First Productíon:~'~'- . -to. _. _....,.... Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BsL CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED Oll-BSl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE'" 27. CORE DATA Brief ~escriptio~ of ~ithology, por~sity, f~actures, apparent dips and presence of oil, gas or water (attach separate s ~ry). N Submit core chips; If none, state none. RBDMS 8Fl APR 2 (; 2007 /-j¡:'97 \ one B~:lL, Form 10-407 Revised 12/20030 R , G, N,4 [ONTINUED ON REVERSE SIDE ~w c., · 28. GEOLOGIC MARK 29. ORMATION TESTS NAME MD TVD Include and brie ummarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10033' 8502' None Shublik 10084' 8538' Sadlerochit 10220' 8625' Zone 3 1 0490' 8776' Zone 2C 1 0630' 8857' 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ ' Title Technical Assistant Date [)L{ /, 0 0 PBU N-22A Well Number 198-030 306-362 Permit No. I A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 John Rose, 564-5271 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ RECE:iVE VJ~ STATE OF ALASKA J, :>,( MAR IA OIL AND GAS CONSERVATION COM.SION W' A~a Oil &"M~lto~~~~A~N OR RECOMPLETION REPORT AND LOG Revised 03/05/07' Correct Ab'ndonment Details A .. 1 a. Well Status: DOil DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development D Exploratory , DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or ~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/4/2007 ,./)1 198-030 .¡ 306-362 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 04/03/1998 50-029-21349-01-00 I 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 04/11/1998 PBU N-22A / 706' FSL, 531' FWL, SEC. 08, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2380' FNL, 3971' FWL, SEC. 17, T11N, R13E, UM 80.3'/ Prudhoe Bay Field I Prudhoe Bay Pool ,¡ Total Depth: 9. Plug Back Depth (MD+ TVD) 2094' FNL, 5008' FWL, SEC. 17, T11N, R13E, UM 11741 + 8966 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 634407 y- 5966610 Zone- ASP4 11807 + 8958 Ft ADL 028283 / TPI: x- 637912 y- 5963587 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 638942 y- 5963892 Zone- ASP4 N/A MD DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: BHCS lOlL I CNL IGR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AM9UNT SIZE Wr. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PUllED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2693' Surface 2693' 17-1/2" 3720 cu ft Permafrost 'E' & PF 9-5/8" 47# L-80 Surface 10019' Surface 8492' 12-1/4" 1890 cu ft 'G', 230 cu ft 'G', 674 cu ft 'G' 7" 26# L-80 9748' 10050' 8294' 8514' 8-1/2" 389 cu ft Class 'G' 2-7/8" 6.16# L-80 9862' 11803' 8377' 8959' 3-3/4" 104 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD . '" ........ ." Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET MD) None 5-1/2", 17#, L-80 x 7595' - 9712' 9712' MD TVD MD TVD 4-1/2", 12.6#, L-80 9712' - 9909' 9857' 25. ACID, FRAcTURE, CEMENT SaUEEZE,ETC; IGANNED MAR 1 3 2007 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED - 8797' P&A wI 23 Bbls Class 'G' 7595' Cut tubing at 9306', Pulled From 7595' 1814' Cut & Pull 9-5/8" Casing, Cmt wI 674 cu ft 'G' 7240' Set EZSV wI Whipstock on Top 26. PRODUCTION TEST Date First Production: . .' . ". "-.' Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". "', None ~ /-iJiJ;t A JRT~J ~'r. - Form 1~7 ReV;SeddRI' GIN A L CONTINUED ON REVERSE SIDE "~-~--' RSDMS 8ft MAR ,] 2 2007 G ( 28. GEOLOGIC MARKE 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10033' 8502' None Shublik 1 0084' 8538' Sadlerochit 10220' 8625' Zone 3 10490' 8776' Zone 2C 10630' 8857' 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram Signed Terrie Hubble Title Technical Assistant Date 03/00/0 31. I hereby certify that the fore PBU N-22A Well Number 198-030 306-362 Permit No. I A roval No. Prepared By NamelNumber: Drilling Engineer: Terrie Hubble, 564-4628 John Rose, 564-5271 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completiCln report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool iis a completion, ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one intervéll (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Digital Well file we;1 Events for SurfaceWell - N-' Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> N -> N-22 Date Range: 08/Dec/2006 to 27/Jan/2007 Data Source(s): DIMS, AWGRS Events Source Well AWGRS N-22A AWGRS N-22A AWGRS N-22A AWGRS N-22A 8WG.RS N-22A AWGRS N-22A AWGRS N-22A AJNGRS N-22A AWGRS N-22A AWGRS N-22A AWG_RS N-22A 8WGRS N-22A AWGRS N-22A AWGRS N-22A Date 01/27/2007 01/24/2007 01/24/2007 01/23/2007 01/23/2007 01/22/2007 01/21/2007 01/18/2007 01/17/2007 01/17/2007 01/16/2007 01/11/2007 01/10/2007 01/09/2007 . Page 1 of 3 Description set bpv/ pre rig T/I/O= Vac/O/O. Temp= 51. LD5 drillout prep (pre-rig ST). No change in pressures overnight. Assist cameron with LDS drillout. Last two LD5 were drilled out. Job complete. Final WHP's= Vac/O/O. T/I/O=VAC/O/O. LD5 drill out (Pre-rig). Casing head: 13 3/8" x 13 5/8" 5m w/ 1) 3 1/16" 5m McEvoy OA valve. Tubing head: 135/8" 5m x 13 5/8" 5m w/ 2) 3 1/16" 5m McEvoy IA valves. Tubing head adapter: 13 5/8" 5m x 6" 5m 5 seal. Tree: McEvoy 6" w/ Otis actuator. Opened bleeder screw on IC hanger to check for test void pressure build-up over night (0 psi). Rigged up Wachs drill and drilled out the 2 remaining stuck LDS . Replaced with (2) new LD5. PT IC hanger: Stung into test void, pressured up on void and pumped 2 gal of fluid, could only achieve 700 psi. Pressure dropped to 0 psi quickly after shutting off pump, no external leaks, did not energize YB seal. T/I/O= Vac/O+/O+. Temp= 51. ALP= 0+ psi and is blinded @ casing valve. LDS drillout prep (pre-rig ST). Assist cameron with LD5 drillout, drilled lout of 3 continue tomorrow. Final WHP's= Vac/O/O. T/I/O=VAC/O/O. LDS drill out (Pre-rig). Casing head: 13 3/8" x 13 5/8" 5m wI 1) 3 1/16" 5m McEvoy OA valve. Tubing head: 13 5/8" 5m x 13 5/8" 5m w/ 2) 3 1/16" 5m McEvoy IA valves. Tubing head adapter: 13 5/8" 5m x 6" 5m 5 seal. Tree: McEvoy 6" w/ Otis actuator. Bled penetrating fluid from Ie hanger test void (1000 psi). Attempted to free (2) stuck lOS, attempt failed. Rigged up Wachs drill and drilled out 1 LDS. Unable to remove all of inner thread, installed blank LDS. Will continue job on 1-23-07. T/I/O= Vac!Vac!Vac. Temp= 51. ALP=O+ psi and blinded at casing valve. LDS drillout prep (pre-rig ST). Initial TBG & IA FL's near surface. Purge N2 down IA up the TBG with 3 bbls of fluid returned. U-tube TBG & lA, TBG & IA FL's @ 36'. Bled pressure's back to 0 psi. Put N2 down the OA, OA FL @ 30', bled OAP back to 0 psi. Cleaned and preped casing hanger for LD5 drillout and laid out fire blanket's in cellar. Flowline pressure @ 0 psi. ***NOTE*** grease crew serviced wing and lateral valve. Final WHP'S= 0/0/0 T/IA/OA= 0/0/0 Well head repair, installed heater on IC casing hanger to warm well head up for 4 hours. Pumped fluid into YB injection port to free up old packing. When 1" port was removed found green packing in port. Pressure up on injection port till was getting back fresh packing. Rigged up on test port on IC hanger and injected penetrating oil into test void to 3,000 psi. and monitored test pressure for 30 minutes. After test bled test void to 2,000 psi. and left on void. To try and free up [3] seized LDS with the flats broken off. Will try to back out on Tuesday 1-22-07. If unable to break free, we are set up to drill out using Wachs rep. and new Wachs drill. Prep for drill out. Gather parts and equipment. T/I/O=Vac!Vac!Vac. Temp=SI. TBG, IA & OA FL's (Prep for LD5 drillout). TBG , IA & OA on Vac unable to get FL's. T/I/O = 300/200/0 [LRS 42 unable to complete job (Circ-out)] CMIT TxIA to 3500 psi (PASSED on 4th attempt) MIT OA to 2000 psi (PASSED) Freeze Protect T x lA, Pumped 170 bbls of 80* diesel into tubing and U- Tube over to IA. Freeze Protect Flow Line with 2 bbls of neat methanol 50 bbls of crude 3 bbls of neat methanol 40 bbls of crude 45 bbls of diesel. CMIT TxlA with 8.9 bbls of diesel lost 40/40 psi in the 1st 15 min and 20/20 psi in the 2nd 15 min for a total loss of 60/60 psi in the 30 min test. MIT OA with 2 bbls of diesel lost 40 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 60 psi in the 30 min test. Bled All WHP's to 0 psi. Final WHP's = 0/0/0 *** Job continued from 01/16/07 WSR *** Circ out well (RWO prep) - Pumped 562 bbls (976 total) 110* 2% KCL down TBG taking returns up IA to flowline. Pumped 8 bbls diesel down TBG. Pulled off job per mechanical problems. LRS 62 to finish job. FWP's = 150/140/500 T/I/O = 120/50/0 - Circ Out (Pre-RWO) - Pumped 5 bbls meth followed by 414 bbls 120* 2% KCL down TBG taking returns up IA to flowline. *** Job continued on 01/17/07 WSR *** *** NOTE: Lock down screws leaking by, flagged and notified Pad Operator *** Well head repair: Work on freeing up stuck LDS on casing spool, {9} flagged from earlier well work. Was able to free up {6} of nine bad LDS. {3} was unable to get to operate, LDS broke off at flats. Called engineer, drilling wants to drill pre rig. Are now working on procedures to drill. ***STILL IN PROGRE5S**** ***WELL5HUT-IN ON ARRIVAL*** 5.5" TUBING CUT AT 9306 FT WITH 4.15" POWERCUTTER. DEVIATION AT CUT 44 DEGREES. TAGGED AT 9354 FT ELM. ***JOB COMPLETE. *** ***CONTINUED FROM 1/8/07*** MIT TEST INITIAL PEASURE T/I/O, 2070/2165/0 1ST 15 http://digitalwellfile.bpweb. bp.com/W ellEvents/Home/Default.aspx 3/5/2007 Digital Wellfile AWGRS N-22A AWGRS N-22A AWGRS N-22A AWGRS N-22A 01/09/2007 01/08/2007 01/05/2007 01/04/2007 AWGBS N-22A 01/04/2007 AWGRS N-22A 01/04/2007 AWGRS N-22A 01/03/2007 AWGRS N-22A 01/01/2007 AWGRS N-22A 12/31/2006 AWGRS N-22A 12/26/2006 AWGRS N-22A 12/25/2006 AW_GRS N-22A 12/24/2006 AWGRS N-22A 12/23/2006 AVVGRS N-22A AWGRS N-22A AWGRS N-22A AWGRS N-22A AWGRS N-22A AWGRS N-22A 12/23/2006 12/22/2006 12/21/2006 12/20/2006 12/19/2006 12/10/2006 . Page 2 of3 MIN T/I/O, 2050/2135/0 2ND 15 MIN T/I/O, 2045/211 PASSED TEST ***WELL LEFT S/I OPERATER NOTIFIED*** Well head repair: Installed heater on well head for LDS work. Air compressor on order. ***WELL S/I ON ARRIVAL *** DRIFTED W 4.5" CENT, S-BAILER SD @ 9120' SLM ( NO CEMENT ON S- BAILER WAS EMPTY) DRIFTED W 2' X 1 7/8" STEM, 2.65" CENT, S-BAILER SD @ 9630' SLM STICKY BOTTOM, S-BAILER CONTAINED FINE BROWN SAND PUMPING DIESEL FOR PT ***CONTINUED ON 1/9/07*** CTU #9 w/ 1.75" coiled tubing. Cement plug pre sidetrack. ***Continued from 1/4/07 WSR*** Tag up at surface. Trap 540 psi WHP. RDMO. Notify Pad Operator of well status. ***Job Complete*** Note: WCTOC ~8797' CTU #9 w/ 1.75" coiled tubing. Cement plug pre sidetrack. RIH with 2.5" BDJSN. Dry tag at 9829' ctmd. Lay in 23 bbls 15.8 ppg "G" cement at 1: 1 with 100% returns. POOH. Freeze protect coil with 60/40 meth. FP well to 2500' with 60/40 meth. ***Continued on 1/5/07 WSR*** T/I/O = 0/20/0. Temp= S1. AL Line= Blinded @ Spool. TBG FL @ Surface. IA FL @ Surface. TBG & IA FL's. PULL BPV AFTER TUBING HEAD X TUBING HEAD ADAPTER STUD BOLT ADJUSTMENT T/I/O=BPV/O/O, Pre-Rig PPPOT-T(PASS), PPPOT-IC (FAIL). PPPOT-T. External Alemite fittings are installed. Sting into test void to check pressure (300 psi), bled pressure from void (gas). Pumped fluid through void until clean returns were achieved. Pressured void to 5000 psi for 30 min, lost 100 psi in first 15 min, lost 20 psi in second 15 min (PASS). Cycled LOS on TBG spool, all LDS moved freely. PPPOT-IC. External Alemite fittings installed. Sting into test void to check pressure (0 guage). Pumped fluid through void untill clean returns were achieved. Attemp to pressured void to 3000 psi, could only pressured to 600 psi, stoped pump and pressure decreased to 0 psi. Tightened LDS on casing head upper flange, only got 5 pins to move. Repressured void and could only achieve 600 psi, returning to 0 psi when pump was stoped (FAIL). 9 LDS tight, could not function properly. SET BPV FOR STUD ADJUSTMENT T/I/O= VAC/VAC/O. Temp= S1. Bleed WHP's to 0 psi, BPV (stud remediation pre-rig). A/L blinded at casing valve, ALP= 0 psi. T/I/O= 0/0/0 Temp= S/I Circ-Out w/ Crude (Pre CTU/ PREP for SDTRCK) Pumped 5 bbls neat, 870 bbls crude down the tubing, up the IA taking returns down the flowline. Freeze protected flowline w/ WOA FP procedure. FWHP's = 200/200/600 REPLACE SWAB VALVE AND TREE CAP ASSEMBLY P/TTO 4500 PSI WOA GREASE CREW *** CONT WSR FROM 12-23-06 *** ( pre CIBP/ pre sidetrack) TAG TOP OF SLUGGITS @ 9821'SLM W/3" BLIND BOX. 9' OF SLUGGITS DUMPED ON FILL IN 4-1/2" TBG. TOP OF LINER AT 9462'MD. *** LEFT WELL SHUT IN , TURNED OVER TO OPERATOR *** *** CONT WSR FROM 12-22-06 *** ( pre cibp / pre-sidetrack) DUMPED 100# OF SLUGGITS AT 9812'SLM W/3.50" DUMP BAILER. MADE TWO ATTEMPTS TO OPEN OTIS XA SS AT 9629'MD APPEARS SLV IS STILL NOT OPEN, NO PRESSURE CHANGES NOTED. NOTE: 42BO SHIFTING TOOL BECAME STUCK IN SLV ON 2ND ATTEMPT. *** CONT WSR ON 12-24-06 *** BOTH THE SWAB VALVE AND THE TREE CAP FLANGE NEED TO BE REPLACED. SWAB FAILS TO HOLD MORE THAN TWO RUNS AT BEST AND THE THREADS ON THE TREE CAP FLANGE ARE IN POOR SHAPE. T/I/O = 80/VAC/10. Temp = S/1. AL blinded at casing valve, ALP = 0 psi. TBG and IA FLs (pre-CTU). Slickline downhole upon arrival. TBG FL @ 480' (12 bbLs). IA FL @ 318' (18 bbLs). *** CONT WSR FROM 12-21-06 *** (pre CIBP / pre sidetrack) BAILED 1/2 GAL OF GRAVEL MIXED WITH PLASTIC. LOST SPANGS AND BAILER ( SWIVELED OFF) RAN KJ , 3.6" BELL GUIDE, 2.6" BELL GUIDE, 2" JUS TO 9694' SLM RAN KJ , 3.84" CENT. , 3.6" B.G , 2' JUS TO 9694' SLM RAN KJ ,4.50" CENT. , 2' x 1 7/8" STEM, 4.00" LIB TO 9683' SLM RAN KJ , 3.70" CENT. , 2 x 1 7/8" STEM, 3.50" LIB TO 9694' SLM RAN 2.6" B.GUIDE W/2" JUS PULLING TOOL, RECOVERED FISH FROM 9808'SLM CONTINUE BAILING ***CONT WSR ON 12-23-06 *** ***WELL SHUT IN ON ARRIVAL *** (pre-cibp / pre-sidetrack) RIH W/ 10' X 2.25" DRIVE DOWN BAILER, SIT DOWN @ 9827' SLM CURRENTLY POOH W/ BAILER *** CONT WSR ON 12-22-06 *** ***CONTINUED FROM 19-DEC-2006** TUBING PUNCHED OVER INTERVAL 9666-9668 FT IN 5-1/2" TUBING. 4 SHOTS PER FOOT, .22" HOLES (9 HOLES TOTAL) DEVIATION AT PUNCH 44 DEGREES. ***JOB COMPLETE*** RIG UP FOR TUBING PUNCH. **CONTINUED 20-DEC-2006** ***CONTINUED FROM 9-DEC-06*** LEAK DETECT RUN FROM SURFACE TO 9800 FT FROM IA TO TUBING. STATIC AND PUMPING PASSES LOGGED AT 100 FPM. PUMPED 75 DEG F CRUDE AT 0.45-0.35 BPM. INJECTIVITY OBSERVED ABOVE FILL AT 0.45 BPM @ 2950psi. REPEAT PASSES OVER ANOMALIES LOGGED AT 80 FPM. GLM AT 3941 FT PROVIDING PATH FOR http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 3/512007 Digital Wellfile . Page 3 of3 FLUID RETURNS TO PERFS FROM IA. WARM BACK PA. RUN AT 1 HR, 3 HRS AFTER OFF PUMPS. SUSPECTED PC LEAK AT "'4250'. RUN GYRO DATA GYRO FROM SURFACE TO 9800 FT ***JOB COMPLETE*** Continued from 12-09-06 T/I/O= 200/250/25 Assist E-Line LDL (Shut in) (Side track screening) Pumped 172.8 bls of 70* crude down IA. Bleed TxlA PSI down. Bleed back 16 bbls crude. Final Whp's=75/50/50 T/I/0=200/250/25 Assist E-Line w/ LDL. (Shut In)(Side Track Screening) Job in progress. ****** TBG AND IA NOT FULL NUT****** AWGRS N-22A 12/09/2006 RUN LEAK DETECTION LOG FROM SURFACE TO 9800 FT. **CONTINUED 10-DEC-06** AW<iR5 N-22A 12/08/2006 Assist E-Line (LDL Pre Rig) . ***Job Postponed due to Weather*** 1IIIIIIil'.. AWGRS N-22A 12/10/2006 AWGRS N-22A 12/09/2006 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 3/5/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/1 0/2007 Rig Release: Rig Number: Spud Date: 5/27/1985 End: 2/9/2007 10:30 - 12:30 2.00 MOB P PRE Rig down lines. Pull pits away from sub. Lay derrick over and back rig off well. Move pits, shop, camp from A to N pad. 12:30 - 13:30 1.00 MOB N WAIT PRE Wait on security to escort Nordic 2 to Oxbow turnoff before beginning move. 13:30 - 19:30 6.00 MOB P PRE Move camp, shop, pits to N Pad. 19:30 - 22:00 2.50 MOB N WAIT PRE Wait on security to escort Nordic 1 camp from G to C Pad. 22:00 - 00:00 2.00 MOB P PRE Move sub complex from A to N Pad. 2/10/2007 00:00 - 06:30 6.50 MOB P PRE Transport sub to N Pad,lay herculite and spot sub. 06:30 - 07:30 1.00 RIGU P PRE PJSM. Raise and pin derrick. 07:30 - 09:30 2.00 RIGU P PRE PJSM. Spot and connect Pits. 09:30 - 14:00 4.50 RIGU P PRE Spot cuttings tank,shop,camp, and support buildings. Rig up rig floor and berming. Bridle down and complete pre-spud list. 14:00 - 14:30 0.50 WHSUR P DECOMP Rig accept 14:0002/10/2007. Pre-Spud meeting with all personnel. 14:30 - 15:00 0.50 WHSUR P DECOMP Rig up secondary annulus valve. 15:00 - 15:30 0.50 WHSUR P DECOMP Rig up circulating lines from tree to cuttings tank through choke. 15:30 - 16:30 1.00 WHSUR P DECOMP Rig up DSM,pull BPV with lubricator. 16:30 - 17:00 0.50 WHSUR P DECOMP Rig up circulating lines and test to 2000 psi. 17:00 - 20:00 3.00 WHSUR P DECOMP Reverse circulate clean seawater down annulus to displace diesel freeze protect from tubing. When tubing cleared swap directions and pump down tubing until diesel out of annulus. Circulate clean seawater around through tubing cut at 9306',6 BPM @ 530 psi. Verify well is dead,shut in and blow down circulating lines. 20:00 - 21 :00 1.00 WHSUR P DECOMP Dry rod TWC,test from below to 1000 psi. Blow down and rig down circulating lines. 21 :00 - 23:30 2.50 WHSUR P DECOMP Nipple down tree and adaptor. 23:30 - 00:00 0.50 WHSUR P DECOMP Nipple up BOP's 2/11/2007 00:00 - 04:00 4.00 WHSUR P DECOMP Nipple up BOP.Cut riser to fit. 04:00 - 11 :00 7.00 BOPSU P DECOMP PJSM. Fill stack,test BOP's and related equipment,including hydraulic and manual chokes, to 250 psi low and 4000 psi high with 5 1/2" test joint. Test Hydril to 250 psi low and 2500 psi high. Test witness waived by Chuck Scheve AOGCC, test witness by Blair Neufeld and Dick Maskell BP, WSL. Change out failed 5" dart valve and test IBOP. Lower IBOP (mud saver) failed low pressure test. Grease, function and re-test, failed. 11 :00 - 16:00 5.00 BOPSU SFAL DECOMP PJSM. Remove saver sub, change out lower IBOP valve. 16:00 - 18:00 2.00 BOPSU DECOMP Test lower IBOP and outer mud cross, 250 psi low and 4000 psi high. Blow down surface equipment, and rig down testing equipment. 18:00 - 18:30 0.50 BOPSU DECOMP Circulate on top of TWC to clear any debris. 18:30 - 19:30 1.00 BOPSU DECOMP Rig up DSM lubricator, pull TWC. 19:30 - 20:30 1.00 PULL DECOMP Rig up 5 1/2" handling equipment, make up spear and engage in tubing. Back out lock down screws. 20:30 - 22:30 2.00 PULL P DECOMP Attempt to pull 5 1/2" 17# tubing. Pull 280k,work pipe, break circulation. Pull and work pipe at 325k, circulate 5 BPM @ 230 psi, work pipe while waiting on slick line. 11' of pipe stretch at 300k pull = stuck @ -5500' (not accurate Printed: 3/5/2007 2:01 :33 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/1 0/2007 Rig Release: Rig Number: Spud Date: 5/27/1985 End: 2/11/2007 20:30 - 22:30 2.00 PULL P DECOMP due to deviated hole) Release spear from tubing and lay down same. Blow down top drive. 22:30 - 00:00 1.50 PULL N DPRB DECOMP Wait on SWS E line unit to cut tubing. 2/12/2007 00:00 - 02:30 2.50 PULL N DPRB DECOMP Wait on wireline unit to re-cut tubing. 02:30 - 03:00 0.50 PULL N DPRB DECOMP Pre-job safety meeting with crew and Schlumberger personnel. Spot wireline unit. 03:00 - 05:30 2.50 PULL N DPRB DECOMP Rig up shooting nipple & sheaves for wireline 05:30 - 09:00 3.50 PULL N DPRB DECOMP Run in hole with CCL, jet cutter to 7800'. Log on depth and fire jet cutter at 7595' MD. POH with Eline & LD cutter. LD sheaves and lubricator on rig floor. 09:00 - 10:00 1.00 PULL P DECOMP MU spear and engage top tubing joint. Back out LDS. PU to 140 klbs and pipe was moving - good cut. Pull hanger to floor. Dis-engage spear. Cut control lines and flatten same. Break out tubing hanger and LD. 10:00 - 10:30 0.50 PULL N DPRB DECOMP RD all SWS equipment and clear floor. 10:30 - 11 :30 1.00 PULL P DECOMP Lay down spear and hanger, pick up single and break cross over. Clear floor and re-hang rig tongs to lay down tubing. 11 :30 - 12:30 1.00 PULL P DECOMP Rig up power tongs, and spooling unit. 12:30 - 16:00 3.50 PULL P DECOMP Lay down 51/2",17# tubing from 7595' to SSSV. Rig down spooling unit. 16:00-21:30 5.50 PULL P DECOMP Lay down 5 1/2",17# tubing from 5506' to surface. Clear and clean floor. Recovered 5 SS bands,26 clamps,SSSV, and 2 GLM's. 178 jts one 28.97' cut off. 21 :30 - 23:30 2.00 CLEAN P DECOMP Rig up 4" test joint, install test plug. Test upper and lower rams to 250 psi low and 4000 psi high. Test Hydril to 250 psi low and 2500 psi high. Test witnessed by BP rep. Blair Neufeld (WSL). Pull test plug and install wear ring. 23:30 - 00:00 0.50 CLEAN P DECOMP Bring BHA components to rig floor up beaver slide. 2/13/2007 00:00 - 03:30 3.50 CLEAN P DECOMP PJSM Pick up and make up 9 5/8" scraper assembly to 322'. 03:30 - 10:00 6.50 CLEAN P DECOMP PJSM. Pick up DP and RIH to 7560'. Up weight 155k, down 125k. 10:00 - 11 :00 1.00 CLEAN P DECOMP Slip and cut 128' of drilling line. 11 :00 - 11 :30 0.50 CLEAN P DECOMP Service top drive and draworks. 11 :30 - 13:30 2.00 CLEAN P DECOMP Tag stump at 7595'. Pump hi-vis sweep surface to surface at 570 gpm with 2065 psi. Pump one more bottoms up. Pump dry job and blow down top drive. 13:30 - 16:00 2.50 CLEAN P DECOMP POOH to 322'. Change out handling equipment. 16:00 - 17:30 1.50 CLEAN P DECOMP POOH and lay down BHA. Nothing in boot baskets. Clear and clean floor. 17:30 - 00:00 6.50 EVAL P DECOMP Spot and rig up SWS. Make up tools. RIH with USIT/CBLJGR to 7500'. Log up to surface, checking for top of cement and corrosion. 2/14/2007 00:00 - 02:00 2.00 EVAL P DECOMP Log out with USIT/CBL. TOC at 1900'. Second joint above TOC at 1824'. Cut to be at -1808'. No significant corrosion detected. 02:00 - 04:00 2.00 DHEQP P DECOMP Change out SWS line head. PJSM. Pick up and make up string shot assembly. 04:00 - 05:30 1.50 DHEQP N DFAL DECOMP RIH and locate second collar above TOC at 1824'. Spot string shot 6' above and 6' below collar and attempt to fire. Fire failed. Pull up, run back down. Pull up to space out and attempt to fire again. Fire failed. POOH with wireline to PU new string shot assembly. Printed: 3/5/2007 2:01 :33 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/10/2007 Rig Release: Rig Number: Spud Date: 5/27/1985 End: 2/14/2007 05:30 - 07:30 2.00 DHEOP N DFAL DECOMP PJSM. Trouble shoot and re-run string shot. Locate second collar above TOC at 1824'. Fire string shot. 07:30 - 08:00 0.50 DHEOP P DECOMP POOH with string shot. Fired OK. Rig down SWS. 08:00 - 09:00 1.00 CASE P DECOMP PJSM. Pick up casing cutter tools. Change out elevators. Pick up single. Make up multi-string casing cutter, pump out sub and XO's. 09:00 - 11 :30 2.50 CASE P DECOMP RIH. Locate casing collar at 1811'. Verify by locating collar above at 1771' and collar below at 1849'. Lay down 2 singles. Up weight 55k, down 50k, RT 52k. Pull up 16' and cut 9-5/8" casing at 1795'. Free torque 1k, cutting 2-4k at 50 rpm. Pump at 220 gpm with 880 psi. WOB 3-5k. 9-5/8" casing stub at 1795'. 11 :30 - 16:00 4.50 CASE N SFAL DECOMP PJSM. LRS (Hot Oil) having trouble with unit. Close bag. Line up cuttings tank and gain immediate retums without pumping. Allow to u-tube while rolling pump periodically to warm up mud lines. Waiting on LRS. Circulate 30 bbls seawater down DP taking crude returns to cuttings tank. Pump at 63 gpm with 80 psi. Shut down and monitor returns. Returns fall off to trickle. Roll pumps at 63 gpm every 15 minutes to warm up lines and wait for LRS. 16:00 - 16:30 0.50 CASE P DECOMP Rig up LRS hot oil truck. 16:30 - 21 :00 4.50 CASE P DECOMP PJSM. Circulate 75 bbls of 100 degree diesel down DP and up 13-3/8" x 9-5/8" annulus with LRS. Chase with 100 degree seawater. Pump at 42 gpm to displace diesel out of well into cuttings tank. Once diesel out of hole increase rate to 210 gpm and pump down 9-5/8" x 4" annulus through cut and into cuttings tank. Open hydril. Blow down and rig down circulating lines and LRS. 21 :00 - 22:00 1.00 CASE P DECOMP POOH. Lay down casing cutter. Cutters in good shape. Clear and clean floor. 22:00 - 00:00 2.00 CASE P DECOMP Change out top variable rams to 9-5/8" rams. Pull wear ring. Install test plug. Rig up 9-5/8" test joint. Test 9-5/8" rams and door seals to 250 psi low, 4000 psi high as per AOGCC. Pull test plug and rig down test joint. 2/15/2007 00:00 - 03:30 3.50 CASE P DECOMP PJSM. Pick up false bowl and 9-5/8" handling equpment. Install false bowl. Make up 9-518" spear assembly. RIH and engage spear. Back out lock down screws. Unseat 9-5/8" casing with 135k up weight. Free up weight 105k. Pull hanger and pack off to rig floor. 03:30 - 10:30 7.00 CASE P DECOMP Break out and lay down spear assembly. Pull and lay down 9-5/8" casing. Recovered 46 full joints and cut joint of 24.45'. Recovered 13 turbulators. Rig down tongs and false bowl. Clear and clean floor. 10:30 - 13:30 3.00 CASE P DECOMP PJSM. Pick up, steam and make up washpipe assembly, jars, bumper sub and float. RIH to 342'. Change out handling equipment. 13:30 - 14:00 0.50 CASE P DECOMP RIH to 1780'. Up and down weight 70k. 14:00 - 14:30 0.50 CASE P DECOMP Break circulation at 1 bpm. Rotate down over 9-5/8" stub at 1795'. Swallow to 1823' and pull up to 1816'. 14:30 - 15:30 1.00 CASE P DECOMP Circulate soap around with 100 degree seawater at 336 gpm with 540 psi. Blow down top drive. Remove blower hose. 15:30 - 16:00 0.50 CASE P DECOMP POOH to 342' and change out handling equipment. Printed: 3/512007 2:01 :33 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/10/2007 Rig Release: Rig Number: Spud Date: 5/27/1985 End: 2/15/2007 16:00 - 17:30 1.50 CASE P DECOMP POOH and lay down washpipe assembly. Clear floor. 17:30 - 19:30 2.00 CASE P DECOMP Pick up and make up back off tool assembly to 321'. 19:30 - 21:00 1.50 CASE P DECOMP RIH to 2115'. Fill every 5 stands. Up and down weight 75k. Rig up test pump to drill string. 21 :00 - 23:00 2.00 CASE P DECOMP Pick up and place upper anchor at 1801', lower anchor at 1827' with collar at 1811'. Pressure up string to set anchors with 1000 psi for bottom and 2500 psi for top. Attempt to break 9-5/8" connection with 5000 psi. Unsuccessful with 2 tries. Close bag and pressure up to 200 psi to take out any slack in pipe. Bleed off and pressure up to 5000 psi again to try and back off 9-5/8" casing. Unsuccessful with 2 more tries. Rig down test pump. 23:00 - 00:00 1.00 CASE N DFAL DECOMP Drop dart and open circ sub. Pump dry job and blow down top drive. POOH to 883'. 2/16/2007 00:00 - 00:30 0.50 CASE N DFAL DECOMP POOH with Backoff tool assembly to 321'. 00:30 - 01 :30 1.00 CASE N DFAL DECOMP PJSM. LD BHA. Break and lay down backoff tool assembly. Stand back DC's. Break out XO's, pump out sub and blanking sub. 01 :30 - 04:00 2.50 CASE N DFAL DECOMP Spot SWS unit for second string shot run. Running 5 strand string shot as per Jim Nigh. PJSM. Rig up E-Llne unit. 04:00 - 05:30 1.50 CASE N DFAL DECOMP RIH with E-Line string shot. Shoot 6' above and 6' below collar at 1811'. Shot fired OK. 05:30 - 06:00 0.50 CASE N DFAL DECOMP Rig down SWS E-line unit. Prepare for second run with backoff tool assembly. 06:00 - 07:30 1.50 CASE N DFAL DECOMP PJSM. Make up backoff tool BHA to 321'. 07:30 - 09:00 1.50 CASE N DFAL DECOMP Change out handling equipment. RIH to 2215' filling every 5 stands. Rig up test pump to drill string. 09:00 - 10:30 1.50 CASE N DFAL DECOMP Pick up and set top anchor at 1801' and bottom anchor at 1826'. Collar at 1811'. Pressure up drill string to 2000 psi. Connection broke at 20klbs. Back off 4 turns. 10:30 - 11 :00 0.50 CASE P DECOMP Pick up and release tool. Rig down test pump. Drop dart and open circ sub. Circulate and pump dry job. Blow down top drive. 11 :00 - 11 :30 0.50 CASE P DECOMP POOH to 321'. 11 :30 - 13:00 1.50 CASE P DECOMP Change out handling equipment. Lay down backoff tool. Rack back drill collars. Clear and clean floor. 13:00 - 13:30 0.50 CASE P DECOMP Pick up and make up 9-5/8" spear assembly to 25'. Change out handling equipment. 13:30 - 14:30 1.00 CASE P DECOMP RIH to 1795'. Up weight 53k. Pick up single. Engage spear and verify with 20k over pull. Slack off. Make 5 turns to the left. Pick up free. 14:30 - 15:30 1.00 CASE P DECOMP POOH to 25'. 15:30 - 17:30 2.00 CASE P DECOMP PJSM. Install false bowl. Lay down bumper sub. Remove spear and lay down cut joint. Cut joint at 15.14'. Service break spear assembly. Clear and clean floor. 17:30 - 19:00 1.50 CASE P DECOMP PJSM. Change out bales. Rig up to run 9-5/8", 47#, L-80, TCII casing. 19:00 - 21:00 2.00 CASE P DECOMP PJSM. Make up screw in sub/baffle collar and pup. Run ES cementer and XO. Run one joint TCII casing. 21 :00 - 22:00 1.00 CASE N SFAL DECOMP Unable to achieve optimum torque with power tongs. Swap out casing power tongs. 22:00 - 00:00 2.00 CASE P DECOMP Continue to run 9-5/8" 47#, L-80 TCII casing to 742'. 2/17/2007 00:00 - 04:00 4.00 CASE P DECOMP PJSM. Continue to run 9-5/8" 47# L-80 TCII casing. Tag up. Up weight 100k, down 95k. Printed: 3/5/2007 2:01 :33 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/10/2007 Rig Release: Rig Number: Spud Date: 5/27/1985 End: 2/17/2007 04:00 - 05:00 1.00 CASE P DECOMP Space out. Make up screw in sub to 9-5/8" casing. Screw in and work torque down. Max torque at floor 12k. Pull 250k to verify . 05:00 - 07:00 2.00 CASE P DECOMP Load cement head and verify flag working ok. Rig up for casing test and cement job. 07:00 - 07:15 0.25 CASE P DECOMP Test casing to 2000 psi for 15 min - OK. PJSM for cement job concurrent. 07:15 - 07:30 0.25 CASE P DECOMP Pressure up to 2800 psi and open ES cementer. Circ while cementers air up & prime up. Pump 5 bbls freshwater and test lines to 4000 psi. 07:30 - 08:30 1.00 CASE P DECOMP Pump 75 bbls 9.8 ppg NaCI brine followed by 120 bbls (580 sx) 15.8 ppg Class G Gasblok cement - 4 bpm @ 620 psi. 08:30 - 09:00 0.50 CASE P DECOMP Release ES cementer closing plug and displace cement with 133 bbls seawater at 5-6 bpm @ 625 psi. See dye in brine at 98 bbls away and switch returns straight to cuttings tank. Continue displacement and land plug on cementer at 133 bbls away. Got back 20 bbls cement to surface. Flush stack through kill line and open annular preventer. PU to 150 klbs on weight indicator and pressure up to 1700 psi to close cementer. Bleed off pressure and verify closed - OK. CIP at 09:00 hrs. 09:00 - 11 :00 2.00 CASE P DECOMP Rig down cement head and lines. Blow down lines. Clear floor. Suck out stack and 9-5/8" joint for cutting. 11 :00 - 14:30 3.50 CASE P DECOMP PJSM. Remove mouse hole. Let air out of boots. Break tubing spool. Nipple down. Split BOP and casing spoils. Align casing and set casing in tension with 150k in emergency slips with primary packoff. Run in lock down screws. 14:30 - 16:30 2.00 CASE P DECOMP Rig up WACH's cutter and cut 9-518" casing. Lay down cut joint. Lower stack and drop casing spool. Pull riser. Set stack back on pedistal. Remove secondary annular valve. Remove casing head from cellar. 16:30 - 21 :30 5.00 CASE P DECOMP Bring in prep, install and torque new McEvoy spoil with secondary packoff. Test packoff to 3800 psi. Hold for 30 minutes. Test OK. Install secondary annular valve. Nipple up BOP. Install mouse hole. Reassmble cellar floor. 21 :30 - 22:30 1.00 CASE P DECOMP PJSM. Change out upper rams to 3-1/2" x 6" variables. 22:30 - 00:00 1.50 CASE P DECOMP Make up test joint. Install test plug and test top rams, doors, body and flange to 250 psi low, 4000 psi high as per AOGCC. Pull test plug. Install wear ring. Break and lay down test joint. 2/18/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP PJSM. PU Baker tools 01 :30 - 03:00 1.50 CLEAN P DECOMP PJSM. Make up Bit and pick up BHA to 315'. 03:00 - 04:00 1.00 CLEAN P DECOMP RIH with 4" DP to 1715'. Install blower hose. 04:00 - 05:00 1.00 CLEAN P DECOMP Make up top drive. Wash down at 402 gpm with 475 psi. Tag cement at 1749'. Tag plug at 1759'. Drill out cement and top plug at 28 rpm with 1-3k torque on bottom, 1-2k torque off bottom. WOB 5-15k. Up and down weight 65k, RT 70k. 05:00 - 06:00 1.00 CLEAN P DECOMP Stop 7' above baffle adapter. Circulate hi-vis sweep surface to surface until clean. 06:00 - 06:30 0.50 CLEAN P DECOMP PJSM. Test casing to 4000 psi for 10 minutes. Good test. 06:30 - 08:30 2.00 CLEAN P DECOMP Drill out baffle collar at 1808'. Pump sweep surface to surface. 08:30 - 11 :00 2.50 CLEAN P DECOMP Remove blower hose. Blow down top drive. Continue to run in hole to 7595'. Tag tubing stump at 7595'. Rack back one stand. Up weight 150k, down 130k. 11 :00 - 12:00 1.00 CLEAN P DECOMP Circulate hi-vis sweep surface to surface at 500 gpm with 1580 Printed: 3/512007 2:01 :33 PM . . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/10/2007 Rig Release: Rig Number: Spud Date: 5/27/1985 End: 2/18/2007 11 :00 - 12:00 1.00 CLEAN P DECOMP psi. Circulate hole clean. Reciprocate and rotate at 30 rpm. Pump dry job. 12:00 - 14:30 2.50 CLEAN P DECOMP POOH to 315'. 14:30 - 16:30 2.00 CLEAN P DECOMP POOH with BHA. Stand back drill collars. Break and lay down scraper BHA. Clean out boot baskets. Recover 1/2 gallon of cement, small pieces of metal and rubber. Clear floor. 16:30 - 18:30 2.00 DHB P DECOMP PJSM. Spot and rig up SWS E-Line. Make up EZSV. 18:30-21:00 2.50 DHB P DECOMP RIH with CCL and EZSV. Set top of plug at 7240'. Weight indicator showed good set. POOH and rig down SWS. 21 :00 - 21 :30 0.50 DHB P DECOMP Line up and test 9-5/8" casing and plug to 4000 psi, hold for 30 minutes and record on chart. Good test. 21 :30 - 00:00 2.50 STWHIP P WEXIT PJSM. Pick up and makeup 9-5/8" whipstock BHA to 111'. Upload MWD. 2/19/2007 00:00 - 01 :30 1.50 STWHIP P WEXIT PJSM. Finish uploading MWD. Finish picking up BHA to 397'. PU first stand of DP and surface test MWD at 490 gpm with 715 psi. Good test. 01 :30 - 06:30 5.00 STWHIP P WEXIT RIH with 9-5/8" whipstock at 75 fpm filling every 30 stands. Pick up last stand at 7180'. Make up blower hose. Orient whipstock to 70 degrees right. Set whipstock. Up weight 160k, down 120k. 06:30 - 08:00 1.50 STWHIP P WEXIT PJSM. Displace well to 10.5 ppg LSND mud at 526 gpm with 1690 psi. Reciprocate and rotate pipe at 75 rpm. Trucks could not keep up. Slow rate to 394 gpm with 1490 psi. Circulate to 10.5 ppg in and out. SPR #1 30/20,45/350, #2 30/280, 45/350 at 7236'/0800 hrs. 08:00 - 17:00 9.00 STWHIP P WEXIT Start milling operations at 502 gpm with 2150 psi. Off bottom torque 2-3k, on bottom 5-7k at 70 rpm. WOB 2k. Up weight 160k, down 120k, RT 135k. Caught 100 pounds of metal by 1200 hrs. Finish milling window and 20' of new hole to 7270'. Pumping at 500 gpm with 2200 psi. Torque off bottom at 3k, on bottom at 4-5k at 85 rpm. WOB 8-15k. Up weight 145k, down 125k, RT 135k. Pump sweeps and clean up hole. Recovered a total of 200 pounds of metal. Ream and drift window. Pull up into casing. Mud weight in and out 10.5 ppg. 0.50 STWHIP P WEXIT 3.50 STWHIP P WEXIT WEXIT 2/20/2007 00:00 - 01 :00 1.00 01 :00 - 02:00 1.00 02:00 - 03:00 03:00 - 06:30 1.50 STWHIP P WEXIT Printed: 3/512007 2:01 :33 PM -22 9909' 10016' PERFORATION SUMMARY REF LOG: SWS-MTNL ON 04/11/98 ANGLEATTOPÆRF: 53 @ 10682 Note: Refer to Production DB for historicalperf data SIZE SPF INTERV AL 0 2" 4 10682 - 10692 2-1/8" 4 11626 - 11649 2-1/8" 4 11667 - 11691 MILLOUT WINDOW 10050' o o o 07/30/01 04/25/98 04/25/98 COMMENTS DAV/PAG RECOVERED (07/10/05) TBG PUNCH @ 9666-9668 SL SLUGGITS & PM JET CUT @ 9603' PRUDHOE SAY UNIT WELL: N-22A ÆRMIT No: "1980300 Sf> Re: 30 Day Deadline on Abandonments, N-22A (I 98-030) e e Terrie and Sondra, I do appreciate the work you ladies do. With all of us doing "much", it is important to try to keep the paperwork as minimal as we can. I think this process will help us get closer to that goal. Please call or message with questions or comments at any time. Best regards, Tom Maunder, PE AOGCC Hubble, Terrie L wrote, On 2/27/20072:19 PM: iGANNED MAR 0 9 2007 Hi Tom, I can agree with this. I just was operating under a different mindset. I have attempted to update our tracking database to include where to 'draw the line' on each well. I suspect we will still get it wrong occasionally, but this will make it more clear. I reviewed the already approved list of 1 0-403's/1 0-401's I found a few where the line was not drawn, but based upon your interpretation, I can identify where you would most likely have 'drawn the line'. Thanks for the input and for your understanding. As , it is r continuing goal to submit what is required in a timely I will submit a revised 10-407 for N-22A after again. additional IS Terrie From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, February 22, 2007 11:34 AM To: Hubble, Terrie L Subject: Re: N-22A (198-030) Terrie, I spoke with Steve Davies and I have reviewed the work plan in the file. I can see the confusion here. The work presently done on N-22A has plugged the perforations, however as Steve and I would interpret "things", the well has not been abandoned according to the regulations. It more nearly meets the regulatory criteria of suspended. There is a considerable amount of rig work to be accomplished with the 9-5/8" casing replacement. Steve and I would interpret the rig work up to the trip in hole with the whipstock to still occur within N-22A. I checked the permit for N-22B and that is where Winton has made a notation of what work is covered by the permit to drill. A similar notation (although at a different step) was made on the 403 approved for N-22A. In order to avoid redundant filing, Steve and I believe that it is entirely appropriate to file the abandonment 407 no sooner than the work authorized by the sundry has been completed and in lof3 3/9/20078: 13 AM Re: 30 Day Deadline on Abandonments, N-22A (I 98-030) e e cases like here where work is continuing following rig release. If plans really get changed and the rig is not likely to get on a well for some time, then it probably is appropriate to send in the 407 as you did. Does this work for you? I would like you input. Then it would be my intent to copy Sondra and Sharon at CP AI with the note. I believe there is a similar issue coming up at Kuparuk. Tom Thomas Maunder wrote, On 2/21/20072:02 PM: Terrie, I will speak with Steve Davies on this. The goal is to minimize paperwork and that sometimes is in conflict with meeting a time clock. I apologize for the confusion here. I will get back to you. Tom Maunder Hubble, Terrie L wrote, On 2/21/2007 11 :14 AM: Hi Tom, I just don't know what to do on these... It's very frustrating to Sondra and I, because we keep getting hit with these letters from the AOGCC about turning reports in late. In the past we tried to work both the Abandonment and the new Sidetrack 10-407's at the same time. It seemed like the sensible way to go, since a well is never truly abandoned that it being sidetracked. But, as I unck. uk 30 begins on the date we enter in box (5.) "Date Comp., Susp., or Aband." on the 10-407. But, with the most recent flurry ofletters out to 211 Managers about reports being too frequently late, we decided that the AOGCC wanted us to submit them separately so as to meet the deadline. We're trying as hard as we can to keep the AOGCC happy with us, but... So, for wells to be sidetracked, we've generally been using the cement pumped date for abandonment. Realizing of course that there is almost always further work that occurs that is pertinent, but the date we use as our target to turn in the report is 30 days from pumping cement. That said, we had to turn this in by February 2nd. We usually do show the pertinent work that occurs past the abandonment work up to approximately the date we turn in the report. In this particular well there was more work to occur, but it seemed to me more pertinent to the 10-407 for the new N-22B well and not so much for N-22A. Plus, how do we get around the 30 day deadline from when the cement was pumped. As you know though, it is our goal to provide what you want... Does this mean we need to send in a revised 10-407... Maybe we just need better guidelines from you as to what specific activities triggers the 30 day countdown to begin. Maybe our assumption of cement to perfs is incorrect. 20f3 3/9/20078:13 AM Re: 30 Day Deadline on Abandonments, N-22A (I 98-030) e e Terrie -----Original Message----- From: Thomas Maunder [mailto:tom maundcr(â),admin.state.ak.us] Sent: Thursday, February 08, 2007 9:43 AM To: Hubble, Terrie L Cc: Steve Davies; Art Saltmarsh Subject: N-22A (198-030) Terrie, We have received a 407 covering the pre-rig work on this well. There is still a lot more work to accomplish that was covered by the sundry. I know all the to be done work is planned with a rig, but it seems that submitting the 407 now is premature. According to the protocols we use over here, although N-22A is plugged it is considered suspended rather than abandoned. There is still a significant amount of work to be done prior to the casing exit which is when N-22B would begin. Message back or give a call and we can see what is best to meet the reporting requirements but keep the paperwork burden down. Thanks, Tom Maunder, PE AOGCC 30f3 3/9/2007 8: 13 AM 01/05/2007 Schlumberger NO. 4101 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth sCANtlED JÀN 1 \) 1.007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 /9Ý-ò36 Field: Prudhoe Bay WI! J b# L D e 0 oa escrlPtion Date BL Color CD 17-20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PROPILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 USIT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 USIT 11/27/06 1 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 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: . . .1.'-,"",_.1~ ............ ......,--..-..1 ...,,-...............--..... ..,.......... -.....- '-" Hi John, \S.~-ùSO That shouldn't be a problem. It is always nice to have a "hard bottom" to place cement on. You may proceed with the change in plans. Tom Maunder, PE AOGCC Rose, John G (FAIRWEATHER) wrote, On 12/19/2006 12:33 PM: Tom, We would like to make an attempt to place a CIBP into the top of the 2-7/8" liner to insure our balanced cement plug "stays in place" as planned for and approved in the earlier e-mail. If the drift run indicates that we can successfully place a CIBP into the top of the 2-7/8" liner, are you OK with this modification of the plan? Thanks- JR John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Cell 907/748-5223 Fax 907/564-4040 5CANNED DEC 1 9 2006 -----Original Message----- From: Thomas Maunder [mail to: tom maunder@admin. st:ate. ak. us] Sent: Thursday, December 14, 2006 7:35 AM To: Rose, John G (FAIRWEATHER) Cc: Hobbs, Greg S (ANC) Subject: Re: N-22A Sundry Number 306-362 John, Winton forwarded your request. I will be handling rig/well related issues for the next few months as Winton works full time on regulation issues. Your proposed change is appropriate. Since it has not proved possible to pump the cement into place as planned, spotting it as you describe should be equally effective at isolating the abandoned section of the current wellbore. You may proceed as indicated in the revised procedure. Good luck with the operations. Call or message with any questions. Tom Maunder, PE AOGCC winton Aubert wrote, On 12/14/2006 6:34 AM: Please handle. WGA -------- Original Message -------- N-22A Sundry Number 306-362 Wed, 13 Dec 2006 16:41:01 -0900 Subject: Date: 10f2 12/19/2006 1:12 PM ..l'-\.... l~-kkTJ.. UUI.J.UI) .1~UL.l.I.U""'1. -''-'V __..- From: To: CC: '~ Rose, John G (FAIRWEATHER) <J'onn.G.Rose@bp.com> Winton Aubert <winton aubert@admin.state.ak.ns> Hobbs , Greg s'(ANcsmm'.S.ª~:~~9.:::~::fÏ.?hÞ.:~:~:~ii?~:~::~~~!_~~-·------.....,.. Winton, As we have determined the injectivity into the 2-7/8" liner to be very low (-.3 bpm at 2900 psi) and therefore our ability to squeeze the liner with cement to have a very low probibility, please review the attached document which details an alternate plan to P&A this well in preparation for the planned N-22B sidetrack (Drilling Permit No. 206-161). I have "highlighted" the changes to the P&A plan in RED and have placed strike-out marks in the comments that were part of the original plan and I will give you a call tomorrow to discuss the requested change of plans. Thanks for your consideration in this matter. - JR «N-22B Sundry Application MOD. doc» /John G. Rose / /BP-Alaska Drilling Group/ /Office 907/564-5271/ /Cell 907/748-5223/ /Fax 907/564-4040/ 20f2 12/19/2006 1:12 PM '- .~' O. ;".~.~'..'...'.·.~F..:_...;. bp· '-~ -' .. ' . _~-!-_.J.. GJtL To: Winton Aubert - AOGCC Date: December 14,2006 From: John Rose - BPXA GPB Rotary Drilling Subject: N-22B I A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well N-22A in preparation for drilling the N-22B sidetrack. Please note the historical details of this well as outlined below: N-22 Well Construction: N-22 was drilled in 1985. The 13 3/8" surface casing was 2693' MD and cemented with good cement returns to surface. The 9 5/8" casing was run to 10,016' MD and cemented with a single stage of cement. The 9 5/8" x 13 3/8" annulus was used for disposal and down-squeezed with Arctic Pack. A 7" liner was run and cemented at a final well TO of 10,970' MD. The 7 x 95/8" lap failed to pressure test after the pay zone was cemented. N-22 was completed with a straddle across the leaking liner top. N-22 Production: N-22 was initially completed in Zone 2 with additional Z2 perforations added in 1989 and 1996. A squeeze was performed to repair a liner leak above the GOC in late 1993, however, additional liner damagelleakage was found in 1997 and the decision was made to sidetrack the well rather than perform additional squeeze operations. N-22A Sidetrack: N-22 was sidetracked with coil in 1998. This early CTST kicked-out in the Sag was drilled to 10,931' MD where with E-line logs were run (BHCS/DIUCNUGR). The high angle portion of the well was drilled with GRldirectional only and TD'ed at 11,803' MD where a 2-7/8" liner was run and cemented. Minor losses were noted starting at 11,604' MD, however, there were no reported problems with the primary cement job or post cement pressure test. N-22A was placed on production with 47' of high angle Z2 perforations. Reason for N-22B Sidetrack: N-22A cannot currently be produced due to annular communication and the inability to access the 2 7/8" liner precludes a rig work-over for injection conversion. N-22B Sidetrack Plan: The current sidetrack plan is de-complete the existing N-22A well to allow a whipstock exit of the parent wellbore in the existing 9-5/8" casing at -7400' MD with an 8-1/2" drilling assembly. The 8-1/2" hole will be drilled to the top of the Sag River formation where a 7" liner will then be run and cemented at -9790' MD. A 6-118" wellbore will then be built to horizontal, landing just above the base of Zone 2. The planned well runs horizontally for approximately 3404', staying above the HOT. A solid 4-112" production liner will be cemented in place. The N-22B sidetrack is currently scheduled for Nabors 2ES beginning -01/05/07. The pre-rig work for this sidetrack will be priority scheduled once Sundry approval has been obtained. Estimated Pre-Rig Start: Estimated Spud Date: 1 2/05/06 01/05/07 John Rose GPB Rotary Drilling Engineer Ph: 564-5271 CC: Well file Terrie Hubble / Sondra Stewman N-22B Application for Sundry .- '~ N-228 Planned Operations Summary (11/07/06) Pre-Ria Operations: ?:t::JCo - S~J-. 1. MIRU pumping & E-line services to confirm injectivity capability/rate into the current coil sidetrack (top 2-7/8" liner -9862' MD) as follows; · Drift the 5-1/2" x 4-1/2" tubing down to the top of the fill/junk in the 4-1/2" liner at -9700' MD. . Run LDL as follows; i. Run static temp pass to top of fish -9700' MD (-100 fpm) ii. Locate spinner log at top of fish-9700' iii. Establish injectivity down IA and log up to confirm "flow path" of the injection fluid (record stop counts) iv. While logging up, note temp log data to confirm possible cretaceous leaks in the 9-5/8" casing 2. As the injectivity rate as determined in Step #1 indicates a very low injectivity potential into the 2-7/8" liner(-.3 psi at 2900 psi), a balanced cement plug will be set from the top of the 2-7/8" liner at 9862' MD back up to 200' above the 9-5/8" x 5-1/2" packer at 9712' MD with -TOC at 9512' MO (see calculations below): 4-1/2" liner f/9712' - 9862' MD = 9-5/8" casing x 4-1/2" liner f/9712' - 9857' MD = 5-1/2" liner f/9512' - 9712' MD = 9-5/8" casing x 5-1/2" liner f/9512' - 9712' MD = TOTAL Cement Volume Required = 2.3 bbls 7.9 bbls 4.6 bbls 8.9 bbls 23.4 bbls (Note: To insure cement access to the 9-5/8" x 5-1/2" annulus above the packer at 9712', a tubing punch will be done in the middle in the first full joint of 5-1/2" tubing above the packer (tubing punch at -9666' MD) prior to laying the cement plug.) ^ssuming confirmed injoctivity into 2-7/8" liner in Step 1t1, RU wrvicc coil to pump P&^ cement:ts follows; · RIH with a 5-1/2" retainer on the service coil and set in the middle of the last full joint of 5-1/2" tubing at -0666' MD. · Est:tblish injoctivity and squeeze -1-1 bbls of 15.8 ppg cement through the ret:tiner (cased hole volume from PBTD at 11,7-11' MD to a700' MD). · Un-sting from the cement retainer and dump -2.5 bbls of 15.á ppg cement (oqu:tl to 100' of cement) on top of the retainer. 3. Make GR/JB run and tag the top cement at -9512' MD. 4. Pressure test the cement plug to 2067 psi to confirm integrity (.25 psi per vertical foot to top cement plug). 5. Run E-line gyro to the top of the cement plug to clear up some anti-collision issues with the directional plan for the planned sidetrack. 6. Jet cut tbg in the middle of the first full joint of 5-1/2" tubing below the #1 GLM at 9267' MD (cut tubing at -9306' MO). Jot cut tbg in the middle of the full joint of 5-1/2" tbg above the top of the cement plug at -9255 MD (this is also the first full joint of 5-1/2" tubing abovc the sliding sleeve which is located at a630' MD). 7. Fluid pack the well with seawater and bleed OA, IA and tubing pressures to zero. PPPOT-T and PPPOT-IC. Function all LOS, repair or replace as necessary. CMIT the T x IA to 3500 psi. MIT the OA to 2000 psi. 8. Freeze protect the IA and tubing with diesel to - 2200' md. 9. Bleed all pressures to zero. Set BPV. Secure well. 10. Verify that the well house is removed and that the flow lines are disconnected. If necessary, level the pad. Rig Operations: 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection and displace well to SW. hOC-~ ..\-~"---~ 3. Monitor OA, IA and T for pressure. Verify well is dead. ~e:. > .' 4. Set TWC and pressure test T x IA to 600 psi to confirm barriers (LOT = 12.5 ppg at 2715' TVD). ~~~~~ 5. Nipple down tree. Nipple up and test BOP. Pull TWC. .:20G- \Co \ N-22B Application for Sundry ~' --- 6. RU spooling unit for dual encapsulated control lines. Pull 5-%" tubing, control line and control line bands from pre-rig cut at -9255' MD. 7. MU an 8-1/2" clean-out assembly to include a 9-5/8" casing scrapper and clean-out the well to top of the tubing stub at -9255' MD. 8. MIRU E-line. Make CCUGR/JB and USIT logging runs from tubing stub to surface looking for casing leaks and evidence of TOC behind 9-5/8" casing. 9. With E-line, make string-shot across the first connection below the planned cut point in the 9-5/8" casing (as determined in Step #8) to improve the potential for a clean back-off at the connection. 10. MU Baker 9-%" mechanical cutter, RIH and make initial cut above down squeeze cement as determined using USIT log data in step #8 (TOC should be -2200' MD). Circulate through cut to confirm cut. (NOTE: The cut point should be -16' above the 9-5/8" collar which will be backed-off in step #11.) 11. Circulate through cut with surfactant wash per MI to clean annulus. POOH. 12. Remove we, C/O to 9-%" rams and test ram cavity. 13. MU spear and pull 9-%" csg from the cut point and laying it down. 14. Make clean ouU wash over run with to 9-%" csg stub (may be 2 separate runs per BOT). 15. MU Baker 9-5/8" back-off assembly and RIH and back-off at 1 st casing collar below the 9-5/8" cut point. 16. PU 9-%" screw-in sub wI HES ES cementer. TIH and screw in to csg stub. PU 100,000# and set in emergency slips. 17. RU Schlumberger cement and cement OA to surface using ES Cementer (lead cement job w/9.8 ppg brine). 18. C/O rams to 3-%" x 6" variables and test. Install WB. 19. PU 8-1/2" clean-out BHA on 4" drill pipe and clean-out the 9-5/8" casing to -8000' MD. (NOTE: Drill-out the ES cementer per HES procedure.) 20. RIH w/CIBP, set at -7430' MD per CCUGR log in step #8. 21. PU 9-%" whipstock and TIH to CIBP at -7430'. Test casing and CIBP to 4000 psi for 30 minutes and record test. 22. Displace to 10.9 ppg fresh water lSND milling fluid (per MI). 23. Shear off of whipstock, mill window and 20' of new formation and perform FIT to 11.9 ppg. 24. POOH and lD milling assembly. 25. MU the 8-%" drilling assembly wI DIR/GRlRES/PWD 26. Drill 8-%" intermediate interval as per directional plan. 27. Drill ahead to casing point at Top Sag River to an estimated depth of 9790' MD. 28. Run and cement the 7" BTC-M 26# liner to 9790' MD (with 150' lap). Set hanger and liner top packer. 29. Release running tool, circulate out excess cement and POOH. (NOTE: If USIT indicates holes in the 9-%" casing, it may be necessary to adjust liner lap or run and cement a 7" scab liner.) 30. MU 6-%" BHA with DIR/GR/RES/NEU/DENNibration and RIH to shoe tract. 31. Pressure test wellbore to 4000 psi for 30 minutes, record test. 32. Drill shoe tract. Swap over to 8.5 ppg Flo-Pro SF mud and drill 20' of new formation. Perform FIT to 10.1 ppg. 33. Drill the 6-%" production interval as per directional plan to and estimated TD of 13,194' MD. 34. Run and cement a 4-%",12.6#, l-80 liner. Ensure that there is 150' of overlap from the 7" shoe. Set liner hanger and liner top packer. Displace well to clean seawater above the liner top. 35. MIRU SWS. Run USIT/CBl in both the 4-%" & 7" liners to confirm cement quality. 36. RU Schlumberger and RIH wI 600' 2-%" 2906 Powerjet guns set @4 SPF. Tag PBTD. 37. Put guns on depth and fire. POOH and verify all shots fired. 38. Run 4-%", 12.6#, 13Cr-80 completion wI Baker S-3 permanent packer. Space out and land tbg. 39. Install TWC and test to 1,000 psi. 40. ND BOPE and NU adapter flange and tree. Test to 5,000 psi. 41. Pull TWC. 42. Reverse circulate corrosion inhibitor and seawater. Reverse in sufficient diesel for freeze protection to 2200' MD and allow to u-tube. 43. Drop ball and rod and set packer. 44. Test tubing and annulus to 4,000 psi for 30 minutes each, record tests. 45. Set BPV and secure the well. 46. RDMO. Post-Ria Work: 1. Install well house and flow lines. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'X' nipple below the packer. 3. Install GlM valves as required. N-22B Application for Sundry '-0 '-' Surface Northing Easting Offsets TRS Location 5966610 634407 706' FSL /531' FWL 11 N, 13 E, Sec 8 Target Northing Easting Offsets TRS Location 5963163 637399 2485' FSU1831 FEL 11 N, 13 E, See 17 Bottom Northing Easting Offsets TRS Location 5963294 639824 2571' FSU59T FWL 11 N 13 E, Sec 16 N-22B Application for Sundry -. . : ' FRANK H. MURKOWSKI, GOVERNOR ALASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W, 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, Well Name N-22A Sundry Number: 306-362 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions cf approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any rèquired 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 let-eer, 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, o '. N Chairman DATED thistfday of November, 2006 End. (q~--03Ò A'~ /1/ ß/C~_()_" _,,_._' " RiA W'"/' ~IAI~ FAlA5KA : I~ . AdM UI{)~ /7> ~ ALASKA OIL AND GNiCONSERVATrONCOMMJSSION : yr" r APPLICATION FOR SUNDRY APPROYJŒ ~ 11//"1/:6 1. Type of Requesf. 181 Abandon o Alter Casing o Change Approved Program 110' 2693' 10019' Liner 302' 1941' 20 MC 25.280 I o Suspend o Repair Well o Pull Tubing o Perforate o Stimulate o Waiver o Operation Shutdown o Plug Perforations o Perforate New Pool 4. Current Well Class: / 181 Development 0 Exploratory o Stratigraphic 0 Service WóA- II ¡~, ¡'DO~ r) u {) /') \j fí : " ; ';" ,;; .'" ' o Time~ o Re-Enter Suspended Well o Other 5. Permit To Drill Number 198-030 / 6. API Number: ,/ 50-029-21349-01-00 8. Well Name and Number: PBU N-22A / 11. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool , '. .,' , '. Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8966 None 9716 TVD Burst Collaose MD / 20" x 30" 1 ~-~/8" 9-5/8" 110' 2R9~' 10019' 11n' 2RQ3' 84Q2' 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation: 110. KB Elevation (ft): ADL 028283 80.3' 1'); ;;'::/'>,/ ,;;»'/,):1;)/;/., > ", ",./,,', ». ....c, Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 11807 8958 11741 Casino Lenoth :;¡ze Structural Conductor Surface Intermediate Production Liner 7" 9748' - 10050' 9862' - 11803' 82M' - 8514' P.~77' - 8959' 2-7/8" 4930 6P.70 2670 4760 7240 13450 5410 13890 / Tubing Size: / Tubing Grade: Tubing MD (ft): 5-1/2", 17# x 4-1/2", 12.6# L-80 9909' I Packers and SSSV MD (ft): 9712'; ('/ I 9857' 14. Well Class after proposed work: o Exploratory ~ Development 0 Service Perforation Depth MD (ft»1 Perforation Depth TVD (ft): I 10682' - 11691' /' I 8887' - 8972' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker packer; 7" x 4-1/2" Baker 'SAB' packer 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program .,-' 15. Estimated Date for / . Commencina Ocerations: Decembßr 5, 2006 17. Verbal Approval: Dat~/ Commission Representative: 18. I hereby certify that the foregoil)9 is true and correct to the best of my knowledge. Printed Name Greg HjJfÍj s ' / Title Senior Drilling Engineer f~, -¡ Signature 16. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ ./ o Plugged 181 Abandoned o WINJ 0 WDSPL Contact John Rose, 564-5271 Phone 564-4191 Commission Use On Iv Date II/I/o. Prepared By NamelNumber: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 181 Location Clearance Other: T -e s t- to~) E +0 Subsequent Form Required: l e> - I Approved Bv: Fonn 10-403 Revised 06/2006 4-000 f ~ . ~aCOMMISSIONER V VI '- uRtGINA,I_ APPROVED BY THE COMMISSION I Sundry Number: ~()(p - 8IP?-. "-----._r Date If, ¡'f-ðb R80MS 8Ft Submit In Duplicate J 5 2006 . . Obp G~~AY To: Winton Aubert - AOGCC Date: November 7, 2006 From: John Rose - BPXA GPB Rotary Drilling Subject: N-22BA Application for Sundry Approval - P&A for Sidetrack Operations / Approval is requested for the proposed P&A of PBU well N-22A in preparation for drilling the N-22B sidetrack. Please note the historical details of this well as outlined below: N-22 Well Construction: N-22 was drilled in 1985. The 13 3/8" surface casing was 2693' MD and cemented with good cement returns to surface. The 9 5/8" casing was run to 10,016' MD and cemented with a single stage of cement. The 9 5/8" x 13 3/8" annulus was used for disposal and down-squeezed with Arctic Pack. A 7" liner was run and cemented at a final well TD of 10,970' MD. The 7 x 9 5/8" lap failed to pressure test after the pay zone was cemented. N-22 was completed with a straddle across the leaking liner top. N-22 Production: N-22 was initially completed in Zone 2 with additional Z2 perforations added in 1989 and 1996. A squeeze was performed to repair a liner leak above the GOC in late 1993, however, additional liner damage/leakage was found in 1997 and the decision was made to sidetrack the well rather than perform additional squeeze operations. N-22A Sidetrack: N-22 was sidetracked with coil in 1998. This early CTST kicked-out in the Sag was drilled to 10,931' MD where with E-line logs were run (BHCS/DIUCNUGR). The high angle portion of the well was drilled with GR/directional only and TD'ed at 11,803' MD where a 2-7/8" liner was run and cemented. Minor losses were noted starting at 11,604' MD, however, there were no reported problems with the primary cement job or post cement pressure test. N-22A was placed on production with 47' of high angle Z2 perforations. Reason for N-228 Sidetrack: N-22A cannot currently be produced due to annular communication and the inability to access the 2 7/8" liner precludes a rig / work-over for injection conversion. N-228 Sidetrack Plan: The current sidetrack plan is de-complete the existing N-22A well to allow a whipstock exit of the parent wellbore in the existing 9-5/8" casing at -7400' MD with an 8-1/2" drilling assembly. The 8-1/2" hole will be drilled to the top of the Sag River formation where a 7" liner will then be run and cemented at -9790' MD. A 6-1/8" wellbore will then be built to horizontal, landing just above the base of Zone 2. The planned well runs horizontally for approximately 3404', staying above the HOT. A solid 4-1/2" production liner will be cemented in place. The N-22B sidetrack is currently scheduled for Nabors 2ES beginning -01/05/07. The pre-rig work for this sidetrack will be priority scheduled once Sundry approval has been obtained. /~ Estimated Pre-Rig Start: Estimated Spud Date: 12/05/06 01/05/07 John Rose GPB Rotary Drilling Engineer Ph: 564-5271 CC: Well file Terrie Hubble / Sondra Stewman N-22B Application for Sundry . . N-22B Planned Operations Summary (11/07/06\ Pre-RiQ Operations: 1. MIRU pumping & E-line services to confirm injectivity capability/rate into the current coil sidetrack (top 2-7/8" liner -9862' MD) as follows; · Drift the 5-1/2" x 4-1/2" tubing down to the top of the fill/junk in the 4-1/2" liner at -9700' MD. · Run LDL as follows; i. Run static temp pass to top of fish -9700' MD (-100 fpm) ii. Locate spinner log at top of fish-9700' iii. Establish injectivity down IA and log up to confirm "flow path" of the injection fluid (record stop counts) iv. While logging up, note temp log data to confirm possible cretaceous leaks in the 9-5/8" casing 2. Assuming confirmed injectivity into 2-7/8" liner in Step #1, RU service coil to pump P&A cement as follows; · RIH with a 5-1/2" retainer on the service coil and set in the middle of the last full joint of 5-1/2" tubing at -9666' MD. · Establish injectivity and squeeze ~'" 14 bls Of~5.8" ,pg cement through the retainer (cased hole volume from PBTD at 11,741' MD to 9706~Md). · Un-sting from the cement retainer and dump 2.5 bls of 15.8 ppg cement (equal to 100' of cement) on top of the retainer. . 3. Make GR/JB run and tag the top cement at -9566' MD. /' 4. Pressure test the cement plug to 2050 psi to confirm integrity (.25 psi per vertical foot to top cement plug). 5. Run E-line gyro to the top of the cement plug to clear up some anti-collision issues with the directional plan for the planned sidetrack. & 6. Jet cut tbg in the middle of the full joint of 5-1/2" tbg above the top of the cement plug a -925 0 (this is also the first full joint of 5-1/2" tubing above the sliding sleeve which is located at 9630' MD). .", 7. Fluid pack the well with seawater and bleed OA, IA and tubing pressures to zero. PPPOT-T and PPPOT-IC./ Function all LOS, repair or replace as necessary. CMIT the T x IA to 3500 psi. MIT the OA to 2000 psi. /' 8. Freeze protect the IA and tubing with diesel to - 2200' md. 9. Bleed all pressures to zero. Set BPV. Secure well. 10. Verify that the well house is removed and that the flow lines are disconnected. If necessary, level the pad. Ria Operations: 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection and displace well to SW. 3. Monitor OA, IA and T for pressure. Verify well is dead. 4. Set TWC and pressure test T x IA to 600 psi to confirm b~rs (LOT = 12.5 ppg at 2715' TVD). 5. Nipple down tree. Nipple up and test BOP. Pull TWC. 6. RU spooling unit for dual encapsulated control lines. Pull 5-W' tubing, control line and control line bands from pre-rig cut at -9255' MD. 7. MU an 8-1/2" clean-ou; assembly to include a 9-5/8" casing scrapper and clean-out the well to top of the tubing stub at -9255' MD. / , 8. MIRU E-line. Make CCUGR/JB and USIT logging runs from tubing stub to surface looking for casing leaks and evidence of TOC behind 9-5/8" casing. 9. With E-line, make string-shot across the first connection below the planned cut point in the 9-5/8" casing (as determined in Step #8) to improve the potential for a clean back-off at the connection. 1 O. MU Baker 9-%" mechanical cutter, RIH andæ initial cut above down squeeze cement as determined using USIT log data in step #8 (TOC should be - 2 MD). Circulate through cut to confirm cut. (NOTE: The cut point should be -16' above the 9-5/8" colla ich will be backed-off in step #11.) 11. Circulate through cut with surfactant wash pèr MI to cle§Iß annulus. POOH. 12. Remove WB, C/O to 9-%" rams and test ram cavity. .,/ 13. MU spear and pull 9-%" csg from the cut point.arrd" laying it down. 14. Make clean out! wash over run.witlíto 9-%" c¿g stub (may be 2 separate runs per BOT). 15. MU Baker 9-5/8" back-off assembly and RIH and back-off at 1 sl casing collar below the 9-5/8" cut point. 16. PU 9-%" screw-in sub w/ HES ES cementer. TIH and screw in to csg stub. PU 100,000# and set in emergency slips. ~ ' 17. RU Schlumberger cement and cement OA to s rfac using ES Cementer (lead cement job w/9.8 ppg brine). / 18. C/O rams to 3-Y2" x 6" variables and test. Inst . N-22B Application for Sundry . . V\ 19. PU 8-1/2" clean-out BHA on 4" drill pipe and clean-out the 9-5/8" casing to -8000' MD. (NOTE: Drill-out the ES cementer per HES procedure.) 20. RIH w/CIBP, set at -7430' MD per CCUGR log in step #8. 21. PU 9-%" whipstock and TIH to CIBP at -7430'. Test casing and CIBP to 4000 psi for 30 minutes and record / test. 22. Displace to 10.9 ppg fresh water LSND milling fluid (per MI). 23. Shear off of whipstock, mill window and 20' of new formation and perform FIT to 11.9 ppg. 24. POOH and LD milling assembly. 25. MU the 8-%" drilling assembly wI DIR/GR/RES/PWD 26. Drill 8-%" intermediate interval as per directional plan. 27. Drill ahead to casing point at Top Sag River to an estimated depth of 9790' MD. 28. Run and cement the 7" BTC-M 26# liner to 9790' MD (with 150' lap). Set hanger and liner top packer. 29. Release running tool, circulate out excess cement and POOH. (NOTE: If US IT indicates holes in the 9-%" casing, it may be necessary to adjust liner lap or run and cement a 7" scab liner.) 30. MU 6-Ys" BHA with DIR/GR/RES/NEU/DENNibration and RIH to shoe tract. 31. Pressure test wellbore to 4000 psi for 30 minutes, record test. 32. Drill shoe tract. Swap over to 8.5 ppg Flo-Pro SF mud and drill 20' of new formation. Perform FIT to 10.1 ppg. 33. Drill the 6- Ys" production interval as per directional plan to and estimated TO of 13,194' MD. 34. Run and cement a 4- W', 12.6#, L -80 liner. Ensure that there is 150' of overlap from the 7" shoe. Set liner hanger and liner top packer. Displace well to clean seawater above the liner top. 35. MIRU SWS. Run USIT/CBL in both the 4-%" & 7" liners to confirm cement quality. 36. RU Schlumberger and RIH wI 600' 2-~" 2906 Powerjet guns set @4 SPF. Tag PBTD. 37. Put guns on depth and fire. POOH and verify all shots fired. 38. Run 4-%",12.6#, 13Cr-80 completion wI Baker S-3 permanent packer. Space out and land tbg. 39. Install TWC and test to 1,000 psi. 40. NO BOPE and NU adapter flange and tree. Test to 5,000 psi. 41. Pull TWC. 42. Reverse circulate corrosion inhibitor and seawater. Reverse in sufficient diesel for freeze protection to 2200' MD and allow to u-tube. 43. Drop ball and rod and set packer. 44. Test tubing and annulus to 4,000 psi for 30 minutes each, record tests. 45. Set BPV and secure the well. 46. RDMO. . ........ ~ ~ ~ ~ M ~ c j \- Post-RiQ Work: 1. Install well house and flow lines. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'X' nipple below the packer. 3. Install GLM valves as required. Surface Offsets TRS Location 706' FSL I 531' FWL 11 N, 13 E, See 8 Target Offsets TRS Location 2485' FSU1831' FEL 11 N, 13 E, See 17 Bottom Offsets TRS Location 2571' FSU59T FWL 11N,13E,Sec16 N-228 Application for Sundry TREE = WELLHEAD = ACTUATOR = KB. ELE,V = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= 6" MCEVOY MCEVOY ? 80.3' 44.5' 3100' 108 @ 11517' 10670' 8800' SS . N-22A 2107' -15-1/2" OTIS SSSV LAND. NIP, ID = 4.562" . 113-3/8" CSG, 72#, L-80, 10= 12.347" I GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 6 3941 3807 29 OTIS RA 5 6492 5703 42 OTIS RA 4 7792 6722 35 OTIS RA 3 8654 7411 39 OTIS RA 2 9109 7756 43 OTIS RA 1 9266 7870 44 OTIS RA TOPOF 2-7/8" LNR I 9629' -15-1/2" OTIS XA SLIDING SLY, ID = 4,562" Minimum ID = 2.441" @ 9862' TOP OF 2-7/8" LINER 9697' -1 BKR PBR I 9862' 9857' 9862' 9907' -19-5/8" X 5-1/2" BKR A<R I -15-1/2" X4-1/2" XO I -1 FISH-IBP & TOOLS (6/29/05) I -17" X 4-1/2" BKR SAB A<R, ID - 3.875" I -1 DEPLOYMENT SUB I -14-1/2" MILLED OTIS XN NIP, 10 = 3.80" I -14-1/2" TUBING TAIL WLEG, ID = 3.958" I H ELMD TT NOT LOGGED I 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I TOPOF 4-1/2" TBG I TOP OF 7" LNR I 14-1/2" TBG, 12.6#, L-80, ,0152 bpf, ID = 3,958" I 9909' 9909' 19-5/8" CSG, 47#, L-80. 10 = 8.681" I 10016' ÆRFORA TION SUMMARY REF LOG: SWS-MTNL ON 04/11/98 ANGLE AT TOP ÆRF: 53 @ 10682 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10682 - 10692 0 07/30/01 2-1/8" 4 11626 - 11649 0 04/25/98 2-1/8" 4 11667-11691 0 04/25/98 MILLOUT WINDOW 10050' I PBTD I -1 FISH - 6" X 2" CHKS/ 2.11" X 7" NOZZLE I 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1 1 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" I DATE 03/28/86 04/25/98 1 0/05/02 06/29/05 07/05/05 05/31/06 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION BIWTP WAr-IER SAFETY NOTE RWLlPJC FISH-IBP & TOOLS EZL/TLH WAIVER SFTY NOTE DELETED CO/DTM ÆRF CORRECTION (6/13/04) DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: N-22A ÆRMIT No: "1980300 API No: 50-029-21349-01 SEC 8, T11N, R13E BP Exploration (Alaska) TREE = 6" MCEVOY N-221 PROPOSED Wellhead ~ McEvo ACTUATOR = KB.,B.5V = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= SSH ? 80.3' 44,S' 3100' 101 @ 10886' I BOT 9-S/8" WHIPSTOCK H I HES CIBP H PBTD 9-S/8" CSG, 47#, L-80, ID = 8.681" H Î 10016' 9981' Fm=(RA.TO\I~ ÆF LOO SJ\&MIN.. 0\104111/00 AN3£ATl(pFBT: 53@10082 N:te: Rter to A"odx:tion œ for nstorical perf Œta SIZE SFF INIffiJ AL Qn'&¡z [)ð.lE DATE 03/28/86 04/25/98 10/0S/02 06/29/0S 07/0S/0S OS/31/06 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION BrvvTP WAIVER SAFETY NOTE RWLlPJC FISH-IBP & TOOLS EZLITLH WAIVER SFTY NOTE DELETED CO/DTM ÆRF CORRECTION (6/13/04) I 2200' H HES 4-112" X NIPPLE, ID = 3.813" I I -I [J -2154' -2200' 2693' I H HES 9-S/8" ES CEMENTER, ID = " I I., 9-S/8" CSG, 47#, L-80, BTC SCREW IN SUB, ID =" H 13-3/8" CSG, 72#, L-80, ID = 12.347" 1 The need for an e x Ie n d e d 7" lin e r la p 0 r 7" sea b lin e r to address 9-5/8" casing con c ern swill be con s id ere d . 7280' BOT 7" X 4-1/2" ZXP LINER TOP PKR, FLEXLOK LINER HANGER W/14' TBS, ID = " 7400' H KICK OFF POINT I GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 6 S TBD DMY 4 TBD DMY 3 TBD DMY 2 TBD DMY 1 TBD Shea -9405' HHES 4-1/2" X NIPPLE, ID = 3.813" H BOT 7" X 4-1/2" S-3 ÆRM PKR, ID =" HHES 4-1/2" X NIPPLE, ID - 3.813" l-i HES 4-112" X NIPPLE, ID -3.813" I BOT 7" X 4-1/2" ZXP LINER TOP PKR, FLEXLOK LINER HANGER W/14' TBS, ID =" -9426' -9451' -9472' -9622' 9790' HT' CSG, 26#, L-80, BTC-M, ID = ", BPF = 1 13194' DA TE REV BY 11/01/06 jgr COMMENTS N-22B Planned Well PRUDHOE BA Y UNrr WELL: N-22Bi ÆRMrr No: API No: SO-029-21349-02 SEC8, T11N, R13E BP Exploration (Alaska) -=' STATE OF ALASKA 'v--~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Add Perfs 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown_ Pull tubing _ 70S' FSL, 531' FWL, Sec. 08, T11N, R13E, UM At top of productive interval 2384' FNL, 1658' FEL, Sec. 17, T11N, R13E, UM At effective depth 2121' FNL, 331' FEL, Sec. 17, T11N, R13E, UM At total depth 2095'FNL,275'FEL,Sec. 17, T11N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Liner Sidetrack Liner Size 20" x 30" 13-3/8" 9-5/8" Length 110' 2656' 9982' 1222' 1941 ' 7" 2-7/8" Stimulate _ Alter casing _ 5. Type of Well: Development _X Exploratory_ Stratigraphic_ Service_ (asp's 634407, 5966610) (asp's nla) (asp's 638883,5963863) (asp's 638939,5963890) 11803 feet 8959 feet Plugs (measured) Plugging _ Perforate _X Repair well _ Other _ 6. Datum elevation (DF or KB feet) RKB 80 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number N-22A 9. Permit number / approval number 198-030 10. API number 50-029-21349-01 11. Field / Pool Prudhoe Bay Oil Pool RECEIVED AUG 1 3 2001 Alaska Oil & Gas CO'ns. Commission Anchorage True Vertical Depth 147' 2693' 8492' 8295' - 9063' 8377' - 8959' Measured Depth 147' 2693' 10019' 9748' - 10970' 9862' - 11803' Perforation depth: measured Open Perfs 10682' - 10692', 11626' - 11649', 11667' - 11691' 11741 feet 8966 feet Junk (measured) true vertical Open Perfs 8887' - 8893', 8974' - 8971', 8981' - 8977' Cemented 72 c.f. concrete 3720 c.f. 2120c.f. 389 c.f. 104 c.f. Tubing (size, grade, and measured depth) 5-1/2",17#, L-80 TBG @ 9712' MD. 4-1/2",12.6# from below PKR to Tubing Tail @ 9909'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker Packer @ 9712'. 7" x 4-1/2" Baker SAB Packer @ 9857'. 5-1/2" Otis SSSV Landing Nipple @ 2107'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl 242 1731 553 Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run_ Daily Report of Well Operations Oil X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A%~ d J~ Hie' TeeholeaIAss;s.ao' DeWayne R. Schnorf/ I..e:;/ l \ 628 Form 10-404 Rev 06/15/88 · Casing Pressure Gas Lift Tubing Pressure 179 201 2365 16. Status of well classification as: 1050 Gas Lift \r..... \lAl o R l:J 'l\ ,~ Suspended Service Date August 06. 2001 Prepared by DeWayne R. Schnorr 564-5174 ~ SUBMIT IN DUPLICATE - q-e'll C°mplian e Report File on Left side of folder 198-030-0 MD 11807 ~PRUDHO~E BAY MiT ' '~:2~X ....... 50['"029:2i349:0i TVD 08878 o'~mpletion Date: ~4/25/98 Completed Status: 1-OIL BP EXPLORATION Current: Sent Received T/C/D OH 8/26/98 8/26/98 T Name Interval D 8702 -.~'~2~ SPERRY GR L BHCAC/GR ~'f~AL 9980-10905 L CN/GR ~Fd~AL 9980-10896 L DGR/NGP-MD ,~AL 9982-11803 L DGR/NGP-TVD ~AL 8382-8878 L IEL/GR "~INAL 9980-10923 L MCNL OH 4/12/98 4/15/98 OH 4/12/98 4/15/98 OH 8/26/98 8/26/98 OH 8/26/98 8/26/98 OH 4/12/98 4/15/98 CH 8/25/98 8/27/98 ~INAL 9850-11746 q/II/q3 2 T 8566 ~/' SCHLUM IEL/CN/BHCS/PDC/GR OH 7/30/98 7/31/98 T 8608 (..~ SCHLUM MNCL CH 8/25/98 8/27/98 Daily Well Ops ~//~_/.~ff-- ~_~ Are Dry Ditch Samples Required? yes ~d Rec~- Was the well cored? yes no~~ Analysis Descri ' . rio Sa~npt'~ Comments: Monday, May 01, 2000 Page 1 of 1 STATE OF ALASKA ALASKA O,,_-~,~ND GAS CONSERVATION COMf~,'~dSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] PeRorate [--I Pull Tubing [--lAIter Casing I~ Repair Well [--lOther 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 706' NSL, 531' EWL, SEC. 08, T11N, R13E, UPM At top of productive interval 2384' SNL, 1658' WEL, SEC. 17, T11N, R13E, UPM At effective depth 2121' SNL, 331' EWL, SEC 17, T11N, R13E At total depth 2096' SNL, 5013' EWL, SEC. 17, T11N, R13E t5. Type of well: [] Development [--] Exploratory [] Stratigraphic [--]Service 6. Datum Elevation (DF or KB) KBE = 80.30' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number N-22A 9. Permit Number / Approval No. 98-30 10. APl Number 50- 029-21349-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11807' feet Plugs (measured) 8878' feet 11741' feet Junk (measured) 8885' feet Length Size Structural Conductor 110' 20x30" 8 c.y. Surface 2657' 13-3/8" 3720 c.f. Intermediate 9983' 9-5/8" 2120 c.f. Production Liner 1941' 2-7/8" 104 c.f. Cemented MD TVD 136' 137' 2693' 2693' 10019' 8447' 9862'-11803' 8332'-8914' PeRoration depth: measured 11667'-11691';11626'-11649' true vertical 8895'-8890'; 8900'-8894' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) SSSV @ 2107' ! ::J :? :2 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl 205 544 169 Casing Pressure 186 Tubing Pressure 0 Subsequent to operation: 409 642 408 !15. Attachments I16. Status of well classifications as: [--~ Copies of Logs and Surveys run I [~ Oil [--] Gas i--I Suspended [] Daily Report of Well Operations 7. I hereby cert_j.f¥ that the forego'¢'~ is true ancJ. c.c~rrect to the best of my knowledge Signed "~~.~. ~,. ,~~/~"~~~..~/~~ . ~. Title Technical Assistant IV Prepared By Name/Number: Service 2OO Date ~plicat~ Form 10-404 Rev. 06/15/88 Submit In Du ...... N-22A DESCRIPTION OF WORK COMPLETED Stimulation Operation O7/25/98 A Acid Stimulation Treatment was performed using the following fluids: SUMMARY Moved in rig up Dowell CTU #2. Safety Meeting. MU tools (2.1" dump nozzle, 2" stinger, checks). PT lubricator & Rig in hole with well flowing. Dry tag @ 11083' in the belly of the well. Come on line and try to jet fill. Not much progress made after 45 mins of jetting. Probably scale. Call for DS Acid Pumpers. Pump 5 bbls 12%/10% HCL/XYL. Get past dry tag @ 11083'. Keep rig in hole. Tag up @ 11565'. Work it. Acid out the nozzle. Large break in pressure. Work on down to 11645'. Make it down to 11650' when all acid out the nozzle. Let soak, don't gain any ground. Pump additional 8 bbls acid. Work coil down to 11,743' (PBTD) before acid is at nozzle. Pulled out of hole and pump acid out nozzle. Rig in hole and tag again at 11,660'. Let soak. Rig in hole to 11,700'. Injection pressure slowly climbing but stabilizes approx. 3000 psig at 0.8 bpm. Decide to proceed with acid stimulation as per program. Pumped 60 bbls 12/10 HCL acid. Injection pressure averaged about 3500 psig @ 0.35 bpm and did not show signs of improvement after a short soak. It was decided at this point to abort the remainder of the treatment. The acid was over-displaced into the perforations 30 bbls. Pulled out of hole. Rig down DS #2. Rigged up Trico to back flow well in attempt to clean up the perforations. Fluids Pumped BBLS. Description 561 Sea Water 73 12% HCL/10% Xylene 28 Gel 634 Total Pumped N-22A Stimulation Operation O7/28/98 A Scale Inhibitor Treatment was performed using the following fluids: SUMMARY Rig in hole with dump jet nozzle. Could not get past #6 glm @ 3941'. Pulled out of hole. Marks indicate tools may have been locating in mandrel. Added additional stinger and rig in hole. Rig in hole to below perfs to 11,715 ctmd, pu o 11,600, started circulating down coil but could not rig in hole without reducing rate. Cleaned liner with biozan and chased to surface while flowing and gas lifting. Shut in gas lift, loaded well, shut wing, and injection rate was 2 bpm @ 1860. Start scale inhibition and pump as per program with wax bead diversion (note that gas entered wellbore from annulus). Pulled up to 7300 ctmd and displaced with final flush and the well was tight. Pulled out of hole and coil parted on reel and it appears it parted at a butt weld. Reel was to be swapped anyway so pulled to surface and emptied reel with N2. Plan to have well put on production at 7:00 am (12hrs shut in period). Fluids Pumped BBLS. Description 54 Biozan (mix of 50/50 blend) 30 Scale Inhibitor 4 150 lbs wax beads in 30 pptg HeC 589 Fresh water w/2% KCL 677 Total Pumped GeoQuest 500 W, International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11466 Company: Field: Alaska OII & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 8/25/98 ~o. OI 0 Well Job # Log Description Date BL RF Sepia LIS Tape C-16 ~ "~ ~'~'~ 98428 RST-SlGMA 980430 1 1 1 , N-22A ~ ~t~'o~3~;:~ 98432 MCNL 980411 1 I 1 .... ....... ,, , , ..... , ,,, ,, ,, , , .... ,, , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED AUG 2 7 1998 ~ab UUII~. ~ilJllll~[IO~ Anchoraae Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 26, 1998 N-22A, AK-MW-80179 1 LDWG formatted Disc with verification listing. API#: 50-029-21349-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF ~ TRANSMITrAL LETrER TO TIlE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. An~ogage., g&aska ~8 ~ ,.w ~ ,', ii, ~ ~.,~1..i Date: BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. 0 !:! I I--I_11M G SEI:IL~I C Ec~ To: WELl, LOG TRANSMITYAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Forrnation Evaluation Logs N-22A, AK-MW-80179 August 26, 1998 N-22A: 2" x 5" MD Gamma Ray Logs: 50-029-21349-01 1 Blueline 1 Folded Sepia 2" x 5" TVD Garnrna Ray Logs: 50-029-21349-01 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPY BY SIGNING AND RETURNING THE ATFACHED COPIES OF THE TRANSMYFFAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99~51~ Date: AUG 2 6 1998 Alaska 0it & Gas C0n~. O:mmi~si0n Anchom~ BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11381 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape N-22A ~.~ .-~ (...~L.~ 98352 IEL~BHC,CN 980407 I 7/3O/98 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: SchhJmberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by(~~: ~~~"'~ STATE OF ALASKA ALASK/ AND GAS CONSERVATION COMMt._ N CT Sidetrack well WELL COMP~:~TION OR RECOMPLETION REPORT A'~'~'' LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service,~;',~,¢,. .,..... ...., 2. Name of Operator -~ 1 7. Permit Number ,,?~. ,;~ BP Exploration (Alaska)Inc. 98-30 (~::,., 3. Address ~~-j 8. APl Number ':Ojg~,...~. -.~.,. .~. 50-029-21349-01 '~3.~ ¢.~^ P.O. Box196612, Anchorage, Alaska 99519-6612 .I/ .o 9. Unit or Lease Name %2,-.~ 4. Location of well at surface ~. ~~' 706' NSL, 531' EWL, SEC. 08, T11 N, R13E, UPM (corrected~'r;r~!.~ ' ~. ~:"'~%" Prudhoe Bay Unit ~'~'~ At top of productive interval ~ ~:,'~: : 110. Well Number 2384' SNL, 1658' WEL, SEC. 17, T11N, R13E, UPM (corrected) ~'~ N-22A At total depth !i' '"-'/~!'~i-i~'~i~!i~ ~ 11. Field and Pool 2096' SNL, 5013' EWL, Sec. 17, T11N, R13E~ ~.._,,~.~_ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and serial~N;5. Pool KBE - 80.30 AMSLI ADL 028283 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 4/3/98I 4/11/98I 4/25/98I N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional SurveyI 20. Depth where SSSV set]2_l. Thickness of Permafrost 11807 8878 FTI 11741 8885 FTI [] Yes [] No I 2107 MD ! 1900' (Approx.) 122. Type Electric or Other Logs Run BHCS/DIL/CNL/GR 23. CASING~ LINER AND CEMENTING RECORD CASING S Eq-I-ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20x30 Insulated Conductor Surface 110 36" 8 c.¥. 13-3/8" 72# L-80 Surface 2693 17 1/2" 3720 c.f. 9-5/8" 47# L-80 Surface 10019 12-1/4" 2120 c.f. 7" 26# L-80 9748 10970 8-1/2" 389 c.f. 2-7/8" 6.16# L-80 9862 11803 3-3/4" :104 c.f. 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) MD TVD 11667-11691 8895-8890 11626-11649 8900-8894 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST © I ¢ IA L Date First Production IMethod of Operation (Flowing, gas lift, etc.) : ' ' 4/26/98 I Flowing Date of Test Hours Tested PRODUCTION OIL-DEL iGAs-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO I FOR TEST Flow Tubing Casing Pressure ~,ALCULATED OIL-DEL GAS-MCF WATER-DEL O~L GRAWTY-API (CORR) Press. _~4-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. -- ..... , Ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TSAG 10031 8420 TSHU 10079 8455 TSAD 10224 8542 TZ3 10520 8718 31. List of Attachments Summary Daily Drilling Reports, Surveys 32' I hereby c~~x~°r~e and c°rrect t° the best °f mY kn°wledge /~ Signed Th~r~¢Mi,,~ Title Coiled Tubing Drilling TA Date ~ ~ lC/ Prepared By Name/Number: Theresa Mills 564-5894 ~NSTRUCTIONS 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 §: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: 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 Rev. 07-01-80 Well: N-22A Accept: 4/1/98 Field: Prudhoe Bay Spud: 4/3/98 APl: 50-029-21349-01 Release: 4/13/98 Permit: 98-30 CTD Unit: Nordic #1 Date Day Depth 4/2/98 '1 Finish move DS/N #1 from Z-14a. Accept rig for operations at 1400 hfs 4/1/98. Remove N-22 gas lift line to fit rig substructure. NUBOPE. Perform initial BOPE test-witness waived by AOGCC. RU hardline to bleed IA pressure of 1600 psi to flowline. Bleed to 300 psi. OA 1600. Check well for pressure and had 300 psi. Bleed to zero. Fill hole with 11 bbls SW. MU BHA. Fill CT with SW. RIH with BHA #1 (1.0 deg motor/3.80" pilot mill). 4/3/98 2 10060 Continue RIH w/BHA #1. Circ out gas, crude and MeOH. Tag XN nipple at 9911 ft and correct to 9907 ft BKB. Mill out nipple. RIH and tag cement at 9981 ft. Orient TF to Iow side and drill firm cement to 10,040 ft. Orient TF to high side and drill until casing contact at 10050 ft O'OVV). POOH. M/U BHA #2 with 3 deg bent motor, 1.5 deg bent sub and 3.80" window mill. RIH. Correct Depth to flag. Orient high side. RIH clean to TD at 10050'. Time drill per procedure to start window. At 10052.5', started getting motor work and weight loss. Ledge established. Mill window to 10055.5' at about 1 fi/hr, 3000# WOB (max without stalling), TF reactive to 15L. Stalls becoming more frequent. Lower WOB to stabilize. TF wandering CW, ROP increasing, losing motor work at 10057' (BOVV). PUH and orient around. RIH to 10057' and continue milling at 15L. High ROP and little motor work as before. 4/4/98 3 1 OO68 Mill formation to 10062 ft. Backreamed bottom window area. POOH. Layout BHA #2. Displace seawater in CT with Nitrogen. Safety meeting. Cut off CTC and pull end to reel and secure it. Pick reel. Repair one drive pin. Set in replacement reel of CT. Pull CT to injector and stab CT. Safety meeting with night crew. MU hardline. Drift coil with 1-1/4" ball. MU CTC and pull test/PT. MU BHA #3 to dress window: 3 deg motor, string reamer, and pilot mill. RIH. Tag at 10042' with 40L TF. Orient to 16L. Tag at 10050'. Ream down to 10053' with good motor work (several stalls) and broke through. RIH to TD at 10059'. Correct to 10062'. Backream bottom of window area. Displace well to new FIo-Pro. Tie-in log (add 2'). Drilled another 4' to get log. Corrected TD at 10068'. POOH. 4/5/98 4 10515 POOH with BHA #3 (window dress). M/U drilling BHA #.4 with a 1.25 deg bent motor. RIH. Correct depth to flag. Orient TF. Drill build/turn interval from 10068' - 10268'. Drill turn 10,268' - 10515' while holding inclination at about 55 deg. Made full wiper trips at 10190', 10300'. 4/6/98 5 10677 Drill from 10515 - 10588 ft. Into Zone 3. POOH for Tri-cone bit and 0.8 Deg. motor. M/U BHA #5. Service injector head and guide arch. Nordic centrifuge down. R/U MI solids van to process mud. Rig generator #1 floated a valve. Cat mechanic fixing generator. Still able to operate with Generators #1 & 3. RIH with BHA #5. Tag TD and correct CTD. Drill 55 deg inclination hole from 10588'- 10677'. Average ROP = 15 FPH in Zone 3. Drilled 5-1/2 hours with tri-cone. No drilling break but should be near top of Zone 2. POOH for bit change (worn cutters, 1/8" undergage). MU BHA #6 with DS49 bit. RIH. 4/7/98 6 10931 RIH with BHA #.6. Ream open hole to TD. Hole in good condition. Sperry MWD tools locked in GR mode. POOH. Change out Sperry MWD and motor. RIH with BHA #7. Re-log across Zone 3. New data shifts curve left. Re-orient TF. Drill from 10677' - 10812'. Wiper trip to window. Continue drilling with several stops to pump-up surveys (erratic MWD data). Drill to 10,923' (logging pt). Wiper trip to window. Tie-in (add 8'). RIH to corrected TD of 10,931'. Flag pipe. POOH. LD BHA. Clear floor. RU Atlas for open hole logs. 4/8/98 7 11113 M/U Atlas Open Hole logging tools. Held Safety Meeting. RIH with BHCS / DIL / CNL / GR. Sat down with tools 10 ft out window. Work thru. RIH and sat down at 10320 ft [58 deg. incl.]. Work thru and RIH to TD of 10929 ft BKB. Log 300 ft repeat pass off bottom. Log final pass. OW(:; at 10742 ft BKB, 8749 FT $$. Bottom of Zone 3 at 10682 ft. POOH and R/D Atlas. RIH with BHA #8 with 2.5 deg motor to build angle. Orient TF to high side and run in open hole. Check MWD surveys to verify directional. Drilled to 11038' Bit stacking. Wiper trip to window. Orient TF to HS. Drilling from 11038' to 11048', Orient TF to HS. Drillinq at 1L from 11048' to 11113' Proiected 98.6° at bit. POOH to change motor BH (1°). 4/9/98 8 11363 POOH to change motor to a BH of 1 deg. Change out motor, re-run same bit. Check orienter. TIH, Tie In (no Correction ) Tagged bottom at 11113'. Orient TF and Drilling Drilled from 11113' to 11260' Unable to drill. POOH and Changed bit and directional package. TIH, Tagged bottom at 11255' Orient TF. Drilled from 11255' to 11363' at RS TF. Turned TF to 90 4/10/98 9 11660 Drill to 11515', unable to get bit to drill. POOH, change out motor, re-run same bit. TIH.Tie in and no correction.(10105') TIH. Orient TF, Drilling Iossing 2 to 3 BPH. Drilled to 11660. Wiper trip at 11660' Drilling. Unable to get bit to drill. ( 50% to 60 % Pyrite and Chert) Bit Trip. Changed Bit & RIH. 4/11/98 10 11803 Drill to TD of 11,800'. Short trip to window. GR log for correlation. Correct depth to TD of 11803'. POOH for liner. Ran Liner. PU CTLRT and TIH. Tagged bottom at 11803' Cir wellbore with 2% KCL. Dropped 5/8" ball. Pumped 50 bbl 2% KCL and Released Liner with 2400 psi. Completed 2% KCL fluid pack. Wait on Cementers and Vac Trucks. RU Cementers. Batch Mix Cement. At Density at 05:15 hrs. PT surface equipment to 4000 psi Pumped 3 bbl water ahead, 18.4 bbl Class "G" 15.8 ppg. SD and Lanched dart. 4/12/98 11 11740 Dropped Dart. Launched Dart with 300 psi. Pumped 5 bbl Water behind, SD, checked dart, Dart gone. Displaced cement at 2.7 bpm. Dart landed at LWP at 52.3 bbls, ( +2 bbl excess than calculated) Sheared at 3400 psi. Pumped 11 bbl (calculated tubing volume to latch collar.)and plug bumped. Total volume = 63 bbl. Pressured up to 3000 psi. Checked Floats and they held. With 500 psi, CTP, un-stung from Deployment sleeve and washed up excess cement on top of Liner top. POOH chasing cement to surface. PU 2.25" nozzle and 1%" CS Hydril. TIH and wash into liner. Tag up at 11600', broke thru and spud obstruction downhole. Work down to PBTD of 11741 '. Pull uphole to 11250' and run back to PBTD-OK. POOH to 9700'. Cement compressive strength 2500 psi. Test liner top to 1500 psi-OK. POOH and PU CNL memory logging tools. TIH with CNL GR Memory tools Logged from 9850' to 11740' Ran 300' repeat section. POOH. Stand Back CSH in Derrick 4/13/98 12 Finish laying down Memory Logging tools, check data-OK. TIH and freeze protect well from 1700' to surface (top 100' is straight MeOH). Purge CT w/N2. Clean pits, rig down lines. Release Rig 12:00 hrs. 4/12/98 4121198 Field crew put well on w/GL to unload well to Station #6. Shot fluid level @ 3450'. Shut GL in to allow Whp to come down to LHP. 4122198 Miru CTU#6, 14620 of 1.75" coil. CTV= 33.4 bbls. Perform weekly BOP function test. MU Baker 1-11/16" tools & PDS GR/CCL. Rih Tag TD @ 11744'. Log 40 fpm from PBTD to 10800' then speed up to 60 fpm. Stop @ 9400' & shoot FL for underbalance calculation. Pooh. OOH, have data. Create log tied into CNL dated 1 l-April-1998. This log is 5' off depth from OH logs. Flag is @ 11562', which is the top of the CTC. 4123198 Wait on slim no-go CTC. MU CTC. PTto 4000 psig. MU 1-11/16" checks, hyd disc. MU 1- 11/16" firing head. Rih to Flag. Correct depth to 11561.3'. Pull into firing position @ 11655'. Drop %" delrin ball and chase to firing head w/32.2 bbls FSW. Pressure up to 3100 psig. See WHP increase to 700 & CTP fell to 500 psig. Pooh. Experience 2000 # overpull @ 9870'. OOH. Gun didn't fire. Delrin ball went past seat in firing head. After having over pull thru liner top area & gun not firing, decide to make c/o run w/2.11" nozzle to ensure 2-1/8" guns are still feasible to run. 4124198 Checks broke on c/o run, leaving 0.5' of check valves & 2.11" x 0.6' swirl nozzle @ 11700' we suspect. Rig up w/3 stingers and 2" nozzle for drilt run & to push fish to btm. Find PBTD @ questionable depth. Lost faith in our flag. Mechanical counter broke @ Iovejoy on drift run. Pooh. Rig up PDS to flag coil. Flag coil @ 10600' which turns outto be 11642' on the log. 4/25/98 DS Safety Meeting. Start rig up-find small leak on trolley hose. Lay down and fix. Start in hole w/Gun #1 (2-1/8" x 10.5'loaded/2.6'blank/10.5' loaded, 4 spf, 25J charge, 60 deg phased, RO). Shoot Gun #1 from 10662 to 10686', tied into 5' off depth SWS MTNL dated 1 l-Apr-98. Gun#1 was shot from 11667-11691' OH measurements. Rih w/gun #2 (2-1/8" x 10' loaded/2.6' blank/ 10' loaded, 4spf ,25J, 0 deg phased, RO). Shoot gun #2 from 11621-11644', tied indto 5' off deptdh SWS MTNL log. Gun#2 was shot from 11626-11649' OH measurements. Perforation Summary: Gun #1 11667' - 11691' (21') 2-1/8", 4 spf, 25J UJ Charge, 6.5 gm, 60 deg phased. Gun #2 11626'- 11649' (20') 2-1/8", 4 spf, 25J UJ Charge, 6.5 gm, 0 deg phased. Note: Fish @ PBTD (6" of 2" checks & 2.11" x 7" nozzle). EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN ORIGINAL Company: BP Exploration? Inc. Rig: DowellflNordic #1 Job No: 96611 Well: N-22eow Location: Prudhoe Bay, Alaska AFE No: 4Pl109 Calculation Method: Minimum Curvature Mag. Declination: 28.100 BHI Rep: Howard Wagoner Vertical Sect. Plane: 81.720 GRID Grid Correction: 1.020 Job Start Date: 4-3-98 Vertical Sect. Plane: 82.740 TRUE Total Correction: 27.080 Job End Date: Measured Depth from: RKB DLS per (ft/m): 100.00 True Vertical Depth from: Sea level Meas. Incl. GRID Subsea Coords. - GRID Coords. - ASP TRUE Coords. - TRUE Dogleg Vertical Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) Section Comments . (deg) (deg) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (del~) Lat. (Y) Dep. (X) (Deg/100ft) (from TiP) 10000.00 42.57 136.48 8397.40 -2937.90 3055.60 5963672.384 637462.~45 137.50 -2991.90 3002.80 0.00 0.00 ,,, 10052.00 42.58 136.90 8435.69 -2963.50 3079.73 5963646.785 637486.977 137.92 -3017.92 3026.47 0.50 20.20 10083.50 49.31 134.63 8457.58 -2979.69 3095.53 5963630.594 637502.777 135.65 -3034.39 3041.98 22.00 33.5(I 10110.10 50.55 133.16 8474.71 -2993.80 3110.20 5963616.483 637517.446 134.18 -3048.76 3056.40 6.30 46.0{1 10146.70 50.45 125.31 8498.01 -3011.64 3132.04 596359{4.645 637539.289 126.33 -3066.99 3077.92 16.50 65.0(1 10178.20 51.50 121.27 8517.85 -3025.06 3152.50 5963585.223 637559.740 122.29 -3080.77 3098.13 10.50 83.30 10209.30 50.19 118.10 8537.49 -3037.01 3173.44 5963573.278 637580.6~3 119.12 -3093.09 3118.86 9.00 102.30 10239.20 52.12 113.53 8556.25 -3047.13 3194.40 5963563.153 637601.641 114.55 -3103.58 3139.63 13.50 121.60 10267.90 54.58 109.49 8573.38 -3055.56 3215.81 5963554.726 637623.059 110.51i -3112.39 3160.89 14.20 141.60 10295.70 55.99 103.87 8589.22 -3062.10 3237.69 5963548. l 81 637644.937 104.89 -3119.32 3182.65 17.40 162.30 10329.00 58.18 97.89 8607.33 -3067.36 3265.13 5963542.926 637672.371 98.91 -3125.07 3209.99 16.40 188.70 10363.00 56.34 97.01 8625.72 -3071.07 3293.48 5963539.216 637700.726 98.03 -3129.28 3238.27 5.80 2 ! 6.20 10396.50 57.131 91.56 8644.10 -3073.15 3321.40 5963537.131 637728.642 92.58 -3131.86 3266.15 13.80 243.50 10424.40 57.30 84.88 8659.22 -3072.42 3344.82 5963537.860 637752.065 85.90 -3131.55 3289.58 20.10 266.80 10454.80 56.87 82.07 8675.74 -3069.53 3370.17 5963540.758 637777.416 83.09 -3129.10 3314.98 7.90 292.30 10486.10 55.11 77.15 8693.26 -3064.86 3395.68 5963545.423 637802.924 78.17 -3124.89 3340.57 14.20 318.30 10519.50 54.14 74.16 8712.59 -3058.12 3422.06 5963552.165 637829.3(15 75.18 -3118.62 3367.06 7.90 345.30 10566.30 55.36 67.61 8739.62 -3045.60 3458.13 5963564.685 637865.378 68.63 -3106.75 3403.35 11.70 382.80 10602.90 54.32 64.32 8760.70 -3033.42 3485.46 5963576.864 637892.70 65.34 -3095.06 3430.89 7.90 411.60 10629. l 0 54.49 59.39 8775.96 -3023.38 3504.23 5963586.909 63791 1.476 60.41 -3085.35 3449.84 15.30 431.70 ! 0664.80 54.40 58.16 8796.72 -3008.32 3529.07 5963601.965 637936.312 59.18 -3070.74 3474.94 2.80 458.40 10698.70 51.33 61.15 8817.19 -2994.66 3552.38 5963615.626 637959.62 62.17 -3057.49 3498.49 I 1.40 483.40 10744.70 50.63 64.72 8846.15 -2978.40 3584.19 5963631.887 637991.434 65.74 -3041.80 3530.58 6.20 517.20 10785.20 50.10 68.01 8871.99 -2965.89 3612.75 5963644.392 638019.999 69.03 -3029.81 3559.37 6.40 547.30 10825.10 50.24 68.09 8897.55 -2954.44 3641.17 5963655.845 638048.419 69.11 -30 i 8.86 3587.99 0.40 577. I 0 10863.50 51.65 68.27 8921.74 -2943.36 3668.86 5963666.928 638076. I 01 69.29 -3008.27 3615.86 3.70 606.10 10895.30 52.61 64.20 8941.27 -2933.24 3691.82 5963677.046 638099.064 65.22 -2998.56 3639.00 10.60 630.20 10931.00 54.67 62.73 8962.43 -2920.39 3717.54 5963689.892 638124.781 63.75 -2986.18 3664.94 6.70 657.50 ! 0961.90 61.88 63.61 8978.67 -2908.54 3740.98 596370 i .740 638 i 48.222 64.63 -2974.75 3688.59 23.40 682.40 10993.70 70.15 68.61 8991.59 -2896.83 3767.52 5963713.454 638174.769 69.63 -2963.51 3715.34 29.70 710.40 I 1021.1 O: 74.50 67.60 8999.91 -2887.09 3791.74 5963723.190 638198.985 68.62 -2954.21 3739.73 16.20 735.80 ,, Meas. Incl. GRID Subsea Coords. - GRID Coords. - ASP TRUE Coords. - TRUE Dogleg Vertical Depth Angle Azi. TVD N(+~S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Azi. N(+~S(-) E(+)/W(-) Section Commen~ (deg) (deg) (~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (de~) Lat. (Y) Dep. (X) (De~/100ft) (from TIP) ~I063.00 84.30 71.00 9007.61 -2872.57 3830.22 5963737.709 638237.466 72.02 -2940.37 3778.46 24.70 776.00 11088.00 91.40 70.12 9008.55 -2864.27 3853.76 5963746.019 638261.008 71.14 -2932.49 3802.15 28.60 800.40 11115.60 95.62 69.90 9006.86 -2854.85 3879.65 5963755.434 638286.891 70.92 -2923.53 3828.19 15.30 827.40 11157.00 97.10 74.50 9002.27 -2842.27 3918.81 5963768.010 638326.054 75.52 -2911.66 3867.57 11.60 868.00 11190.90 98.10 79.60 8997.78 -2834.74 3951.54 5963775.540 638358.790 80.62 -2904.71 3900.44 15.20 901.50 -- 11224.10 99.60 83.60 8992.67 -2829.95 3983.99 5963780.333 638.91.234 84.62 -2900.49 3932.96 12.70 934.20 11263.70 98.20 84.90 8986.55 -2826.03 4022.91 5963784.252 638430.159 85.92 -2897.27 3971.95 4.80 973.30 11298.10 100.20 87.70 8981.05 -2823.84 4056.80 5963786.445 638464.040 88.72 -2895.68 4005.87 9.90 1007.20 __ 11338.00 103.10 91.20 8972.99 -2823.46 4095.86 5963786.826 638503.106 92.22 -2895.99 4044.93 11.30 1045.90 __ 11369.10 101.80 93.30 8966.28 -2824.65 4126.20 5963785.633 638533.448 94.32 -2897.73 4075.25 7.80 1075.80 11418.30 103.70 89.10 8955.42 -2825.66 4174.17 5963784.621 638581.410 90.12 -2899.59 4123.19 9.20 1123.10 ~1447.40 105.60 85.76 8948.06 -2824.40 4202.29 5963785.880 638609.530 86.78 -2898.83 4151.32 12.90 1151.10 11478.90 106.70 82.80 8939.29 -2821.39 4232.39 5963788.893 638639.633 83.82 -2896.36 4181.48 9.70 1181.30 __ 11516.70 107.67 79.40 8928.12 -2815.81 4268.06 5963794.476 638675.304 80.42 -2891.41 4217.24 9.00 1217.40 Ii' 11559.50 105.64 74.50 8915.85 -2806.54 4307.99 5963803.740 638715.231 75.52 -2882.86 4257.33 ii.90 1258.30 ~ 11590.50 103.00 74.30 8908.18 -2798.47 4336.91 5963811.817 638744.159 75.32 -2875.30 4286.39 8.50 1288.10 11626.60 100.20 73.30 8900.93 -2788.60 4370.87 5963821.684 638778.113 74.32 -2866.04 4320.52 8.20 1323.10 11665.50 98.06 68.50 8894.75 -2776.03 4407.15 5963834.251 638814.391 69.52 -2854.12 4357.01 13.40 1360.70 11703.10 96.80 67.10 8889.89 -2761.95 4441.66 5963848.339 638848.910 68.12 -2840.65 4391.78 5.00 1397.00 i1740.10 96.10 65.40 8885.73 -2747.14 4475.32 5963863.146 638882.560 66.42 -2826.44 4425.69 4.90 1432.40 11775.80 96.70 64.00 8881.75 -2731.98 4507.39 5963878.3071 638914.634 65.02 -2811.85 4458.02 4.30 1466.30 11803.00 97.16 62.93 8878.47 -2719.92 4531.55 5963890.369 638938.791 63.95 -2800.22 4482.39 4.30 1492.00 State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 12-Apr-98 Well Name Services Bluelines R/F Sepia Film Induction Electrolog/GR 1 1 0 1 1 0.~ q~- o%o:iN-22 A .. N-22 A N-22 A z~q. os--~ J-26 BHC-Acoustilog/GR CN/GR 1 1 0: CN/GR (Cased Hole) 1 1 0 CN/GR (Cased Hole) 1 1 Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOF~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 19. 1998 Ted Stagg Coiled Tubing Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Re; Prudhoc Bay Unit N-22A BP Exploration (Alaska) Inc. Permit No. 98-30 Sur. Loc. 706'NSL. 53 I'EWL. Sec. 08, TI 1N. R13E. UM Btmnholc Loc. 2132'SNL. 228'WEL. Sec. 17. TI 1N. RI3E. UM Dcar Mr. Stagg: Encloscd is thc approved application for permit to rcdrill thc above referenced well. Thc pcrmit to rcdrill docs not cxcmpt you from obtaining additional permits rcquircd by lax',' from other govcrnmcntal agcncics, and docs not authorize conducting drilling operations until all other requircd permitting determinations are made. Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficicnt notice (approximatcly 24 hot, rs) must bc given to allow a rcprcscntativc of the Commission to witness a test of BOPE installed prior to drilling ncw hole. Notice max' be given bv contacting the Commission pctrolcum field inspector on thc North Slope pager at 659-3607. Chairmat~.....~~ BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA A ..... SKA ~:.,_ AND GAS CONSERVA'.._/.jN CO~_.MlSSlON PERMIT TO DRILL CTD Sidetrack 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [~ Re-Entry [] Deepenl [] Service [] Development Gas D Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) i10. Field and Pool BP Exploration (Alaska) Inc. KBE = 80.30 AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028283 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 706' NSL, 531' EWL, SEC. 08, TllN, R13E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2384' SNL, 1658' WEL, SEC. 17, TllN, R13E, UPM N-22A Attotal depth 9. Approximate spud date Amount $200,000.00 2132 SNL, 228' WEL, Sec. 17, T11N, R13E 3/5~98 12. Distance to nearest property line 113. Distance to nearest well 4. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028284 @ 228'I No Close Approach 2560 11,797' MD, 8859' !16. To be completed for deviated wells .17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10,050' Maximum Hole Anqle 90° Maximum surface 3380 psig, At total depth (TVD) 3322 @8700' psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2 7/8" 6.16# L-80 ST-L 1920 9880 8309 11,797 8859 122 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations. FEi.3 1~ ?~ ~9~ Present well condition summary - · Alaska 0ii ~; .... -~-~'~ · Total depth: measured 10970 feet Plugs (measured) Anchor~gs true vertical 9195 feet Effective depth: measured 10834 feet Junk (measured) fill at 10834' MD BKB (08/89) true vertical 9094 feet Casing Length Size Cemented MD TVD Structural Conductor 110 20 x 30 8 c.y. 146 146 Surface 2657 13 3/8 3720 c.f. 2693 2693 Intermediate 9983 9 5/8 2120 c.f. 10019 /8491 Production Liner 1222 7 389 c.f. 9748-10970 8294-9195 Perforation depth: measured 10570'-10600',10610'-10630'0RI6INAL true vertical 8819'-8864' (two intervals) 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Plot [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify that the fore. gging is true and correct to the best of my knowledge SignedT~¢ $(~qq ~~ .~¢-~(--//~.L¢¢ Title Coiled Tubing Drilling Engineer Date ~~? ~' Commission Use Only I I Date I See cover letter Permit Number APl Number Approval ?~ - ,~ 0 50- 0 2. '¢' - -~-//~ ~z ¢ _ ~ / ~t I°l I~ for other requirements Con~litions of Approval: Samples Required [] Yes [~ No Mud Log Re~luired/E3 YesJ~ No Hydrogen Sulfide Measures /'~ Yes [] No Directional Survey Required .l~ Yes [] No [] [] [] /~ [] [] Required Working Pres.sure for BOP E 2M; 3M; ~(?M; by or~le0~t; 15M[ILO" I q~'~ ApprovedBy ?~¢'f ~'~,~' ~,/¢~,, Commissioner the commission eate~,. Form 10-401 Rev. 12-01-85 ~.,~,:u ~,,?,!~,d By Submit '~Tri~ic~te Johnston BPX N-22a Sidetrack Summary of Operations: The well is being sidetracked to reduce GOR and improve PI. This sidetrack will be conducted in two phases. Well Prep: Planned for 2/25/98. · Rig up service coil and abandon existing perfs with 20 bbls Class G and 8 bbls fiber cement. · Cement will be pressure tested and tagged, with AOGCC witness. Top of fiber cement to be at approx. 10,000' MD. Top perforation at 10,550' MD. Milling / Drilling: Planned for 3/5/98 · RU coil drilling unit and mill window from cement whipstock using solids free FIoPro. · Directionally drill per attached directional plan. · Complete with fully cemented 2 7~8" liner. Mud Program: Window milling: FIoPro Drilling: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,880' MD and cemented with approx. 20 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,050' MD (8,434' TVD ss) - TD: 11,797' MD (8,859' TVD ss) ~ Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging [] A Gamma Ray log will be run over all of the open hole section. [] E-line logs (GR/Induction) will be run in the Iow angle build section of the sidetrack, prior to building to horizontal. TREE: 6" McE' WELLHEAD: McE'., ACTUATOR: OTIS ',~'- 22a Pro 13-3/8", 72 CC/fi, L-80, BTRS. FOC -- KOP: 2800' MAX ANGLE: 44°/9500' 5-1/2", 17 CC/fi, L-80, BRTS TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT OTE: O PERFS BEHIND STRADDLE. STRADDLE RUN BECAUSE LINER LAP WOULD NOT TEST. 7" LINER 9748' 9-5/8", 47CC/ft, 6' L-80, BTRS ~1 0,01 I~ PERFORATION SUMMARY REF LOG' SWS-BHCS- 6-10-85 ,N ERV^ P N,SOZ'D 31/8"I 4110,570-10,600' pPEN/3-28-86 3 3/8'1 4 J10,61.0,-10,63,0' ~OPEN/8-24-89 3 3/8"/6 110,550-10,570 ~en 4/26/96 Cemented 2 7~8" liner Class G cement over perforations with fiber cement cap for whipstock PBTD ~ 7" , 26 CC/fi, L-80, IJ4S [ 10,970'1 KB. ELEV = 80.30' BF. ELEV =44.50' SSSV LANDING NIPPLE ( OTIS )( 4.562" ID) 2107' GAS LIFT MANDRELS (OTIS w/ RA LATCH/ N° MD(BKB) TVDss 941' 807' 492' 702' 792' 722' 654' 410' 109' 756' 266' 869' OTIS SLIDING SLEEVE TYPE "XA" (4.562" ID) AKER PBR 9-5/8" BAKER PACKER ( FHL)( 4.000 "ID) 9629' 9697' I 9712' I 4 1/2", 12.6 CC/fi, L-80, BTRS TAILPIPE 4 1/2 .... X" NIPPLE ( OTIS ) ( 3.813" ID) 9763' BAKER7"SAB PACKER I 9852, (3.875" ID) 4 1/2 .... XN" NIPPLE ( OTIS ) ( 3.725" ID) 4 1/2" TBS TAIL I 9904' (VVLEG) (ELMD) 19909' N-22 8800 8850 8900 8950 9000 Vertical Section 500 Path Distance (Feet) 1,000 1,500 2,000 I I I 2,500 3,000 Angle~K.O.= 43 deg MD:10050 '49 deg' DL 3= 8 deg/100 58 deg -- - TZ2 -.log point.~ Tot Drld: 1747 ft Marker Depths {~Orig Wellbore tsA I 8,4201it TvD TSHU I 8,456 lit TVD TSAD I 8,542 Itt TVD TZ3 I 8,7~81it TVD Kick Off 8,434 It TVD I 10,050 It MD I Deprtr ~KO 4,288 It MD KO Pt lO,O501 MD New Hole 1747I I Total MD 11,797 TVD TD 8,859 DLS deg/100 Tool Face Length Curve I 16 0 40 Curve 2 16 -75 200 Curve 3 8 -90 240 Curve 4 8 90 180 Curve 5 8 -90 220 Curve 6 24 0 167 Curve 7 6 90 200 Curve 8 6 -90 500 1,747 Drawn: 2/10/98 10:57 Plan Name: Case 104 -2,800 -3,300 -3,800 3,( O0 N-22 3,500 4,000 4,500 5,000 5,500 X distance from Sfc Loc IWell Name N-22 I CLOSURE Distance 5,345 ft Az 121 deg NEW HOLE E/VV (X) N/S (Y) Kick Off 3,079; -2,962 TD 4,580 -2,756 State Plane 638,987 5,963,854 Surface Loc 634,407 5,966,610 DLS deg1100 Tool Face Length Curve 1 16 0 40 Curve 2 16 -75 200 Curve 3 8 -90 240 Curve 4 8 90 180 Curve $ 8 -90 220 Curve 6 24 0 167 Curve 7 6 90 200 Curve 8 6 -90 500 1,747 Drawn: 2/10/98 10:57 Plan Name: Case 104 N-22A CT Drilling & Completion BOP DJ 22.5" 18"I 38" 2 3/8" CT 110,000 psil Pack-Off I 7 1116" Annular Blind/Shear 7 1/16" Pipe/Slip ~ 2 3/8" I~ Pipe ~1~ ~ 2 318" -- 7 1116" -- ~ Slips ~1~ -~ 2 718" SWAB OR MASTER VALVE · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ .~-~,//~I¢'~ INIT CLASS WELL NAME /¢~/.¢'~ /0/%~.2~/Z¢ PROGRAM: exp [] dev}~i~' redrl}~ serv [] wellbore seg E: ann. disposal paFa req ~ GEOL AREA ¢ ~ ¢-.) UNIT# ././~'~?~_,) ON/OFF SHORE o ADMINISTRATION APPR ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12, 13. Permit fee attached...................... J IN Lease number appropriate ................... N Unique well name and number .................. "r N Well located in a defined pool ................. '/' N Well located proper distance from drilling unit boundary .... 'r N Well located proper distance from other wells .......... 'r N Sufficient acreage available in drilling unit ........... .~ N If deviated, is wellbore plat included ........... N Operator only affected party ................. N Permit can be issued without conservation order ........ ~ N Permit can be issued without administrative approval ...... 'Y N Can permit be approved before 15-day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24 25 26 27 28 29 Conductor string provided ................... Y N Surface casing protects all known USDWs ........... Y N CMT vol adequate to circulate on conductor & surf csg ..... Y N CMT vol adequate to tie-in long string to surf csg ........ Y N CMl will cover all known productive horizons .......... (~)N .,~ -- Casing designs adequate for C, T, B & permafrost ...... Cy..)N '~- -~--- Adequate tankage or reserve pit ................. If a re-drill, has a 10-40:3 for abandonment been approved... N If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ...... , .......... BOPE press rating appropriate; test to ~:;'~ psig. N ---- -- Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H:S gas probable ................. '~ N GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... 31 Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. N 34. Contact name/phone for we_eklyprogress reDo. ds" Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION' .,., RNC ",3 co cc Comments/Instructions: t-t(')W/llt - A \F(')RMR\~I~,'.hlmI r,',v Oh'~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUFiBERGER ....... AUG 27' 1998 .............................. A]emka Oil & $~ Oon~,, Commission .............................. A~om,g~ COMPANY NAIViE : BP EXPLORATION WELL NAM~ : N-22A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 500292134901 REFERENCE NO : 98432 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC REEL NAME : 98432 CONTINUATION # : PREVIOUS REEL : CO~ : BP EXPLORATION, PRUDHOE BAY, N-22A, API #50-029-21349-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC TAPE NAME : 98432 CONTINUATION # : 1 PREVIOUS TAPE : COFk4ENT : BP EXPLORATION, PRUDHOE BAY, N-22A, API #50-029-21349-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: N-22A API NUMBER: 500292134901 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 21-AUG-98 JOB NUMBER: 98432 LOGGING ENGINEER: C. YON OPERATOR WITNESS: C. PARKER SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 iN RANGE: 13E FAUL : 4575 FSL: FEL: 4748 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 80.30 DERRICK FLOOR: 79.30 GROUND LEVEL: 44.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 10018.0 47. O0 2ND STRING 7. 000 10970.0 26. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: IEL LDWG CURVE CODE: GR RUN NUM~ER : 1 PASS NUMBER: 1 DATE LOGGED: 7 -APR- 98 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888.0 10861.0 10769.5 10638.5 10629.5 10580.0 10563.5 10551.5 10527.5 10521.5 10518.0 10506.5 10490.0 10467.5 10449.5 10420.5 10415.0 10386.5 10370.0 10361.5 10340.0 10314.0 10302.0 10292.5 10273.0 10267.0 10259.5 10241.5 10238.5 10188.0 10164.5 10146.5 10130.0 10116.0 10108.0 10091.0 10084.0 10070.5 10043.5 10036.5 10019.0 10014.0 9991 . 0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 88889.0 10862.0 10770.0 10639.0 10629 5 10580 0 10563 5 10552 0 10528 0 10522 0 10517 5 10507 5 10489 5 10468 0 10449 5 10420 5 10415 5 10386.0 10370 5 10361 5 10341 0 10314 5 10302 5 10293 5 10274 0 10267 5 10261.5 10242.0 10239.0 10188.5 10165.0 10146.5 10130.0 10116.0 10108.5 10090.5 10084.0 10070.0 10043.0 10035.0 10019.0 10013.5 9991.5 100.5 MCNL 88889.0 10862.0 10770.0 10639.0 10629.5 10580.0 10563.5 10552.0 10528.0 10522.0 10517.5 10507.5 10489.5 10468.0 10449.5 10420.5 10415.5 10386.0 10370.5 10361.5 10341.0 10314.5 10302.5 10293.5 10274.0 10267.5 10261.5 10242.0 10239.0 10188.5 10165.0 10146.5 10130.0 10116.0 10108.5 10090.5 10084.0 10070.0 10043.0 10035.0 10019.0 10013.5 9991.5 100.5 PAGE: ,, LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 ~KS: CONTAINED HEREIN IS THE MCNL DATA ACQUIRED ON BP EXPLORATION WELL N-22A ON il-APR-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT MCNL MAIN PASS GRCH TO THE BASELINE GA~9~A RAY SPECIFIED BY THE CLIENT (GR. IEL) ; AND THE MCNL MAIN PASS NRAT TO GR. IEL. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CO-RVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~f~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11720.0 9804.0 MCNL 11730.0 9804.0 $ CURVE SHIFT DATA - PASS TO PASS (ICIEASURED 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: ** 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 0 * * SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CArT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V O0 000 O0 0 1 1 1 4 68 0000000000 * * DA TA * * DEPT. 11731.000 GRCH. CNT -999.250 NRAT. CNT 7.001 CCL.CNT -999.250 DEPT. 9804.500 GRCH. CNT 27.887 NRAT. CNT 39.486 CCL.CNT 85.000 NCNT. CNT 5685.052 FCNT. CNT -999.250 NCNT. CNT 1025.262 FCNT. CNT 31.829 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVTu?4BER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~Jh~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11716.0 11438.0 MCNL 11726.0 11438.0 $ CURVE SHIFT DATA - PASS TO PASS (MF~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH MCNL 88888.0 88888.5 88888.0 11720.5 11720.5 11716.0 11717.5 11705.5 11707.0 11700.5 11701.0 11700.0 11701.0 11671.5 11673.0 11665.5 11666.5 11658.0 11659.0 11656.0 11657.0 11646.5 11647.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 11638.5 11629.0 11626.0 11611.5 11604.0 11599.5 11592.5 11590.5 11588.0 11572.5 11568.5 11558.5 11557.0 11556.5 11555.0 11553.0 11551.0 11549.5 11546.5 11544.5 11543.5 11540.5 11536.0 11528.0 11527 0 11524 5 11522 5 11522 0 11506 5 11504 5 11504.0 11501.0 11498.5 11497.5 11488.5 11487.0 11485.0 11477.0 11469.5 11465.5 11456.5 11451.5 11448.5 11445.0 11443.5 100.0 $ REMARKS: 11592.0 11573.0 11559.5 11558.0 11554.5 11551.0 11547.5 11545.0 11541.0 11537.5 11528.5 11525.5 11522.5 11505.5 11499.0 11488.0 11465.0 99.5 11640.0 11630.5 11627.0 11613.0 11605.0 11601.0 11593.0 11589.0 11569.5 11560.5 11557.5 11551.5 11545.5 11528.0 11523.5 11507.5 11505.0 11502.5 11498.5 11490.0 11485.5 11478.0 11472.0 11457.5 11453.0 11449.0 11447.0 11444.0 100.5 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 ArRAT TO THE MAIN PASS NRAT. ALL OTHER MCNL CURVES WERE CARRIED WITH THE NRAT SHIFT. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: LIS FORMAT DATA ** 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 SERVUNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11726.000 GRCH. CNT -999.250 NRAT. CNT 8.003 CCL. CNT -999.250 DEPT. 11437.500 GRCH. CNT 14.732 NRAT. CNT -999.250 CCL.CNT -999.250 NCNT. CNT 5693. O16 FCNT. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : OOiCO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS MCNL $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 9 TYPE REPR CODE VALUE 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 NU~iB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 i 1 4 68 0000000000 GRCH CNAV GAPI O0 000 O0 0 3 i 1 4 68 0000000000 CVEL CNAV F/HR O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNAV CPS O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNAV CPS O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNAV O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11726.000 GRCH. CNAV -999.250 CVEL.CNAV 11.940 NCNT. CNAV 5638.507 FCNT. CNAV -999.250 NRAT. CNAV 7.629 DEPT. 9804.500 GRCH. CNAV 27.887 CVEL.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 NRAT. CNAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 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: 1 DEPTH INCREMENT: 0.1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11736.5 9787.0 MCNL $ LOG HEADER DATA DATE LOGGED: Il-APR-98 SOFTWARE VERSION: 0033A TIME LOGGER ON BOTTOM: 1210 il-APR-98 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): 9850.0 BOTTOM LOG INTERVAL (FT) : 11746.0 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): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER GR MCNL 10970.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 11 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): 1500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 19000 TOOL STANDOFF (IN): REMARKS: TIED INTO ATLAS INDUCTION 07-APR-98 THIS FILE CONTAINS THE RAW MCNL DATA FOR THE MAIN PASS. $ 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 0.1 9 65 FT 11 66 36 12 68 13 66 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUPIB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 CVEL PS1 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 RCNT PS1 CPS O0 000 O0 0 4 1 1 4 68 0000000000 RCFT PS1 CPS O0 000 O0 0 4 1 1 4 68 0000000000 RTiFR PS1 O0 000 O0 0 4 1 1 4 68 0000000000 CCL PS1 V O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11736.000 CVEL.PS1 -999.250 GR.PS1 -999.250 RCNT. PS1 RCFT. PS1 -999.250 RTI~R.PS1 -999.250 CCL.PS1 -999.250 DEPT. 9786.500 CVEL.PS1 -1008.250 GR.PS1 99.250 RCNT.PS1 RCFT. PS1 -999.250 RTNR.PS1 -999.250 CCL.PS1 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE ArUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 13 DEPTH INCREMENT: 0.1 FILE SUMM3~RY VENDOR TOOL CODE START DEPTH 11732.5 MCNL $ 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 GAM~A RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) SURFACE TEMPERATURE (DECF) : 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): STOP DEPTH 11419.5 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 Il-APR-98 0033A 1210 Il-APR-98 9850.0 11746.0 1800.0 NO TOOL NU~BER GR MCNL 10970.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE 14 FAR COUNT RATE HIGH SCALE (CPS): 1500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 19000 TOOL STANDOFF (IN): REMARKS: TIED INTO ATf~AS INDUCTION 07-APR-98 THIS FILE CONTAINS THE RAW MCNL DATA FOR THE REPEAT PASS. $ 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 0.1 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 NUM~ SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 CVEL PS2 F/HR O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS2 CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS2 CPS O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS2 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS2 V O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-AUG-1998 16:49 PAGE: 15 ** DATA ** DEPT. 11732.000 CVEL.PS2 -999.250 GR.PS2 RCFT. PS2 -999.250 RTNR.PS2 -999.250 CCL.PS2 -999.250 RCNT. PS2 -999.250 DEPT. 11419.000 CVEL.PS2 -999.250 GR.PS2 -999.250 RCNT. PS2 RCFT. PS2 -999.250 RTNR.PS2 -999.250 CCL.PS2 85.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN · FLIC TAPE NAME : 98432 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, N-22A, API #50-029-21349-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/08/21 ORIGIN : FLIC REEL NAME : 98432 CONTINUATION # : PREVIOUS REEL COMMENT : BP EXPLORATION, PRUDHOE BAY, N-22A, API #50-029-21349-01 * ALASKA COMPUTING CENTER * * .... WESTERN ATI.~S LOG ..... * * ....... PROCESSED BY ....... * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : N-22A FIELD NAM~ : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API ND-FiBER : 500292134901 REFERENCE NO : 98352 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 98/07/17 ORIGIN : FLIC REEL NAME : 98352 CONTINUATION # : PREVIOUS REEL : CO~94ENT : BP EXPLORATION, N-22A, PRUDHOE BAY, API #50-029-21349-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/17 ORIGIN : FLIC TAPE NAME : 98352 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, N-22A, PRUDHOE BAY, API #50-029-21349-01 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING RUN 1 98352 RECK R WHITLOW N-22A 500292134901 BP EXPLORATION (ALASKA) WESTERN ATLAS 15-JUL-98 RUN 2 RUN 3 8 liN 13E 4575 4748 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3. 750 7. 000 10057.0 80.30 79.30 44.50 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED OPEN HOLE IEL, BCS, AND CNT DATA AQUIRED ON BP EXPLORATION'S N-22A WELL. THE GAM~A RAY IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. THIS IS A WESTERN ATLAS LOG PROCESSED BY SCHLUMBERGER. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUM~4ARY LDWG TOOL CODE IEL BCS CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10923.0 10060.0 10905.0 10058.0 10895.0 10058.0 BASELINE DEPTH 88888.0 10883.0 10852.5 10721.0 10689.5 10671.5 10639.5 10629.5 10567.0 10552.0 10530.5 10518.5 10508.5 10488.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT 88888.5 10883.5 10852.0 10719.5 10689.5 10671.0 10639.0 10629.5 10567.0 10552.0 10531.0 10517.5 10508.5 10489.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 10418.5 10415.0 10411.5 10370.5 10361.5 10339.0 10314.0 10297.0 10286.0 10267.5 10264 0 10244 5 10242 5 10213 5 10209 5 10205 5 10188 0 10164.5 10146.5 10138.0 10131.5 10117.5 10110.5 10087.5 10068.5 10036.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 10419.0 10415.0 10412.0 10370.0 10361.5 10338.0 10314.0 10298.5 10286.5 10267.0 10264.0 10245.0 10242.0 10214.0 10209.5 10205.5 10188.0 10165.0 10146.5 10137.0 10130.5 10117.0 10110.0 10087.5 10068.0 10037.5 101.0 RUN NO. PASS NO. ............... M~RGE TOP MERGE BASE THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE CURVES HAVE BEEN DECIMATED AND CLIPPED OF INVALID COUNTS AT FIRST READING AND AT CASING. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN THE CNT CURVES AND THE BASE GAMMA RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 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 NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 189759 O0 000 O0 0 1 1 1 4 68 0000000000 GR IES GAPI 189759 O0 000 O0 0 1 1 1 4 68 0000000000 SP BCS MV 189759 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F 189759 O0 000 O0 0 1 1 1 4 68 0000000000 SN IES 0A74~I189759 O0 000 O0 0 1 1 1 4 68 0000000000 ILD IES 0H~I189759 O0 000 O0 0 1 1 1 4 68 0000000000 TENS IES LB 189759 O0 000 O0 0 1 1 1 4 68 0000000000 TEND IES LB 189759 O0 000 O0 0 1 1 1 4 68 0000000000 CVEL IES F/HR 189759 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 189759 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 189759 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 189759 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10929.000 GR.IES -999.250 SP.BCS -4.182 DT. BCS SN. IES -999.250 ILD. IES -999.250 TENS.IES 6264.711 TEND. IES CVEL.IES 1439.856 CNTC. CNT -999.250 CFTC. CNT -999.250 NPHI.CNT DEPT. 10058.000 GR.IES 63.011 SP.BCS 34.143 DT. BCS SN. IES -999.250 ILD. IES -999.250 TENS.IES 6264.844 TEND.IES CVEL.IES 1199.880 CNTC. CNT 238.891 CFTC. CNT 89.186 NPHI.CNT -999.250 624.665 -999.250 -999.250 1033.528 30.103 ** END OF DATA ** .. . LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASSNUFiBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE IEL CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (ME3~SURED DEPTH) START DEPTH STOP DEPTH ..................... 10058.0 9966.0 10058.0 10022.0 BASELINE DEPTH 88888.0 10883.0 10852.5 10721.0 10689.5 10671.5 10639.5 10629.5 10567.0 10552.0 10530.5 10518.5 10508.5 10488.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT ....... 88888.5 10883.5 10852.0 10719.5 10689.5 10671.0 10639.0 10629.5 10567.0 10552.0 10531.0 10517.5 10508.5 10489.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 10418.5 10415.0 10411.5 10370.5 10361.5 10339.0 10314.0 10297.0 10286.0 10267.5 10264.0 10244.5 10242.5 10213 5 10209 5 10205 5 10188 0 10164 5 10146 5 10138 0 10131 5 10117 5 10110.5 10087.5 10068.5 10036.5 100.0 $ 10419.0 10415.0 10412.0 10370.0 10361.5 10338.0 10314.0 10298.5 10286.5 10267.0 10264.0 10245.0 10242.0 10214.0 10209.5 10205.5 10188.0 10165.0 10146.5 10137.0 10130.5 10117.0 10110.0 10087.5 10068.0 10037.5 101.0 REMARKS: THIS FILE CONTAINS THE EDITED CASED HOLE DATA. THE CURVES HAVE BEEN DECIMATTED AND CLIPPED OF INVALID COUNTS AT CASING AND AT LAST READING. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN THE CNT CURVES AND THE IEL GAMMA RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 7 TYPE REPR CODE VALUE 9 65 FT 11 66 32 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 NUM~ NTgM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUAiB SAMP ELE~ CODE (HEX) DEPT FT 189759 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CArT CPS 189759 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNT CPS 189759 O0 000 O0 0 2 1 1 4 68 0000000000 GR IEL GAPI 189759 O0 000 O0 0 2 1 1 4 68 0000000000 HTEN IEL LB 189759 O0 000 O0 0 2 1 1 4 68 0000000000 TENS IEL LB 189759 O0 000 O0 0 2 1 1 4 68 0000000000 CVEL IEL F/HR 189759 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU 189759 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10058.000 NCNT. CNT 238.891 FCNT. CNT 89.186 GR.IEL HTEN. IEL 1033.528 TENS. IEL 6264.844 CVEL.IEL 1199.880 NPHI. CNT 63. 011 30.103 DEPT. 9980.500 NCNT. CNT -999.250 FCNT. CNT -999.250 GR.IEL 68.773 HTEN. IEL -999.250 TENS. IEL -999.250 CVEL.IEL -999.250 NPHI. CNT -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUM~UU~Y FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH IEL 10940.0 10058.0 BHC 10940.0 10058.0 CN 10940.0 10058.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~VA RAY CN COMPENSATED NEUTRON BHC COMPENSATED SONIC IEL INDUCTION ELECTRIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 07-APR-98 JO01 1.1 10931.0 10929.0 9966.0 10929.0 TOOL NUFiBER ........... 1310XA GR 2418XA CN 1605EA/MAAC 811XA IEL 3. 750 10057.0 10058.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FLO- PRO 8.80 9.5 5.8 0.079 0.114 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REFiARKS: TIED INTO SONIC LOG DATED lO-JUN-85 NEJL~ THE WINDOW AT 100 CL = 39,000 PPM MAX. DEVIATION = 58.2 DEG AT 10329'. IEL AFFECTED BY HIGH SALINITY MUD AND BOREHOLE RUGOSITY NO STANDOFFS OR CENTRALIZERS WERE RUN IN ORDER TO GET DOWN. THIIS FILE CONTAINS THE RAW OPEN HOLE MAIN PASS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 21 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 10 TYPE REPR CODE VALUE 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 NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NDI~B SAMP ELEM CODE (HEX) DEPT FT 189759 O0 000 O0 0 3 1 1 4 68 0000000000 SN IEL 0P~4~189759 O0 000 O0 0 3 1 1 4 68 0000000000 SP BHC MV 189759 O0 000 O0 0 3 1 1 4 68 0000000000 SSN CN CPS 189759 O0 000 O0 0 3 1 1 4 68 0000000000 LSN CN CPS 189759 O0 000 O0 0 3 1 1 4 68 0000000000 GR IEL GAPI 189759 O0 000 O0 0 3 1 1 4 68 0000000000 CHT IEL LB 189759 O0 000 O0 0 3 1 1 4 68 0000000000 TTENIEL LB 189759 O0 000 O0 0 3 1 1 4 68 0000000000 SPD IEL F/HR 189759 O0 000 O0 0 3 1 1 4 68 0000000000 AC BHC US/F 189759 O0 000 O0 0 3 1 1 4 68 0000000000 RT IEL 0H~4189759 O0 000 O0 0 3 1 1 4 68 0000000000 CNC CN PU 189759 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10940.000 SN. IEL 8.274 SP.BHC -4.281 SSN. CN LSN. CN 20.000 GR.IEL 0.000 CHT. IEL 369.696 TTEN. IEL SPD.IEL 1439.856 AC. BHC 50.000 RT. IEL 7.416 CNC. CN DEPT. 10058.000 SN. IEL 0.252 SP.BHC 34.143 SSN. CN LSN. CN 89.204 GR.IEL 63.011 CHT. IEL 1033.528 TTEN. IEL SPD. IEL 1199.880 AC. BHC 223.357 RT. IEL 0.271 CNC. CN 0.000 5110.027 0.000 238.860 6264.844 30.088 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUM~ER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH IEL 10950.0 BHC 10950.0 CN 10950.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION EArDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : STOP DEPTH 10574.0 10574.0 10574.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CN COMPENSATED NEUTRON BHC COMPENSATED SONIC IEL INDUCTION ELECTRIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS 07-APR-98 JO01 1.1 10931.0 10929.0 9966.0 10929.0 TOOL NUMBER ........... 1310XA GR 2418XA CN 160SEA/MA AC 811XA IEL 3.750 10057.0 10058.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 12 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.5 FLUID LOSS (C3): 5.8 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 079 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 114 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : FLO- PRO 8.80 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: TIED INTO SONIC LOG DATED lO-JUN-85 NEAR THE WINDOW AT 100 CL = 39,000 PPM MAX. DEVIATION = 58.2 DEG AT 10329'. IEL AFFECTED BY HIGH SALINITY MUD AND BOREHOLE RUGOSITY NO STANDOFFS OR CENTRALIZERS WERE RUN IN ORDER TO GET DOWN. THIS FILE CONTAINS THE RAW OPEN HOLE REPEAT PASS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 13 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUAIB ND?4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT 189759 O0 000 O0 0 4 1 1 4 68 0000000000 SN IEL 0H~189759 O0 000 O0 0 4 1 1 4 68 0000000000 SP BHC MV 189759 O0 000 O0 0 4 1 1 4 68 0000000000 SSN CN CPS 189759 O0 000 O0 0 4 1 1 4 68 0000000000 LSN CN CPS 189759 O0 000 O0 0 4 1 1 4 68 0000000000 GR IEL GAPI 189759 O0 000 O0 0 4 1 1 4 68 0000000000 CHT IEL LB 189759 O0 000 O0 0 4 1 1 4 68 0000000000 TTEN IEL LB 189759 O0 000 O0 0 4 1 1 4 68 0000000000 SPD IEL F/HR 189759 O0 000 O0 0 4 1 1 4 68 0000000000 AC BHC US/F 189759 O0 000 O0 0 4 1 1 4 68 0000000000 RT IEL 0P~4~189759 O0 000 O0 0 4 1 1 4 68 0000000000 CNC CN PU 189759 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10950.000 SN. IEL 0.000 SP.BHC -80.000 SSN. CN LSN. CN 20.000 GR.IEL 0.000 CHT. IEL 500.000 TTEN. IEL SPD.IEL 0.000 AC.BHC 50.000 RT. IEL 0.000 CNC. CN DEPT. 10574.250 SN. IEL 0.000 SP.BHC -80.000 SSN. CN LSN. CN 20.000 GR.IEL 27.947 CHT. IEL 500.000 TTEN. IEL SPD. IEL 0.000 AC.BHC 50.000 RT. IEL 0.000 CNC. CN 0.000 3000.000 0.000 0.000 3000.000 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 14 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMPIARY VENDOR TOOL CODE START DEPTH IEL 10058.0 CN 10058.0 $ LOG HEADER DATA STOP DEPTH .......... 9980.0 9980.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CN COMPENSATED NEUTRON BHC COMPENSATED SONIC IEL INDUCTION ELECTRIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 07-APR-98 JO01 1.1 10931.0 10929.0 9966.0 10929.0 TOOL NUMBER 1310XA GR 2418XA CN 160SEA/MA AC 811XA IEL 3. 750 10057.0 10058.0 FLO- PRO 8.80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 15 MUD PH: 9.5 FLUID LOSS (C3): 5.8 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OPff4M) AT TEMPERATURE (DEGF): MUD AT NiEASURED TEMPERATURE (MT): O. 079 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 114 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN) REMARKS: TIED INTO SONIC LOG DATED lO-JUN-85 NEAR THE WINDOW AT 100 CL = 39,000 PPM MAX. DEVIATION = 58.2 DEG AT 10329'. IEL AFFECTED BY HIGH SALINITY MUD AND BOREHOLE RUGOSITY NO STANDOFFS OR CENTRALIZERS WERE RUN IN ORDER TO GET DOWN. THIS FILE CONTAINS THE RAW MAIN PASS CASED HOLE DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 08:53 PAGE: 16 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ArUFI~ ArUf4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189759 O0 000 O0 0 5 1 1 4 68 0000000000 SSN CN CPS 189759 O0 000 O0 0 5 1 1 4 68 0000000000 LSN CN CPS 189759 O0 000 O0 0 5 1 1 4 68 0000000000 GR IEL GAPI 189759 O0 000 O0 0 5 1 1 4 68 0000000000 CHT IEL LB 189759 O0 000 O0 0 5 1 1 4 68 0000000000 TTENIEL LB 189759 O0 000 O0 0 5 1 1 4 68 0000000000 SPD IEL F/HR 189759 O0 000 O0 0 5 1 1 4 68 0000000000 CNC CN PU 189759 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10058.000 SSN. CN 238.860 LSN. CN 89.204 GR.IEL CHT. IEL 1033.528 TTEN. IEL 6264.844 SPD. IEL 1199.880 CNC. CN DEPT. 9980.000 SSN. CN 118.851 LSN. CN 20.130 GR.IEL CHT. IEL 500.000 TTEN. IEL 3000.000 SPD.IEL 0.000 CNC. CN 63.011 30.088 68.773 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/07/17 ORIGIN · FLIC TAPE NAME : 98352 CONTINUATION # '. 1 PREVIOUS TAPE : COMmOn, VT : BP EXPLORATION, N-22A, PRUDHOE BAY, API #50-029-21349~01 Sperry-Sun Drilling Services LIS Scan Utility Wed Aug 19 14:40:56 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/08/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-80179 STEVE LATZ SEVCIK/WHITL N-22A 500292134901 'D ECE VE AUG 2 6 1998 Oii & G .s Cons. Commission Anchorage BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 19-AUG-98 MWD RUN 2 AK-MW-80179 STEVE LATZ SEVCIK/WHITL MWD RUN 3 AK-MW-80179 S. LATZ SECVICK/WHIT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-80179 S. LATZ WHITLOW/MCMU MWD RUN 5 AK-MW-80179 S. LATZ' WHITLOW/MCMU MWD RUN 7 AK-MW-80179 S. LATZ WHITLOW/MCMU JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 AK-MW-80179 STEVE LATZ PARKER/HILDR MWD RUN 9 AK-MW-80179 STEVE LATZ PARKER/HILDR MWD RUN 10 AK-MW-80179 STEVE LATZ PARKER/HILDR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 11 AK-MW-80179 STEVE LATZ PARKER/HILDR MWD RUN 12 AK-MW-80179 STEVE LATZ PARKER/HILDR 8 llN 013 706 531 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 80.30 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13. 375 2693.0 2ND STRING 9. 625 10016.0 3RD STRING 7.000 10057.0 PRODUCTION STRING 3.750 11803.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA VERTICAL DEPTHS (SSTVD). 3. MWD RUNS 1-3 ARE PILOT HOLE/WINDOW MILLING RUNS. 4. MWD RUNS 1, 2 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 5. MWD RUNS 3-7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS (SOLAR-175). THE CHANGE FROM NGP TO DGR OCCURS AT 10037'MD, 8424'SSTVD. 6. MWD RUNS 8-12 ARE DIRECTIONAL WITH NGP. THE CHANGE FROM DGR TO NGP PROBES OCCURRED AT 10897'MD, 8942'SSTVD. 7. MWD RUNS 1-12 REPRESENT WELL N-22A WITH API #: 50-029-21349-01. THIS WELL REACHED A TOTAL DEPTH OF l1803'MD, 8878'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 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 FI LE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9957 . 0 11776.5 ROP 9984 . 0 11802.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9957 0 10013 5 10016 0 10017 5 10019 0 10021 0 10027 0 10031 0 10032 5 10034 5 10037 0 10042 5 10046 0 10064 0 10076 5 10088 0 10090 5 10093 0 10096.5 10100 5 10102 0 10104 5 10108 5 10110 0 10113 0 10116 0 10130 0 10137 0 10143 0 10146 5 10165 0 10188 0 10192 0 10198 0 10199 0 10200 5 10205 5 10211 5 10222 5 10229 0 10236 5 10238 5 10242.0 10245.0 10264.5 GR 9956.5 10013.0 10015.5 10017.5 10018.5 10021 0 10026 5 10030 0 10032 5 10034 0 10036 5 10041 5 10047 0 10066.5 10079.0 10088.5 10091.0 10093.5 10096.5 10100.0 10101.5 10106.0 10108.5 10110.5 10112.5 10114.0 10129.5 10138.0 10144.5 .0147.5 10166.5 10190.0 ~0193.5 10198 0 10200 5 10201 5 10205 0 10212 0 10222 5 10230 0 10237 0 10238 0 10240 5 10244 5 10265 5 - EQUIVALENT UNSHIFTED DEPTH 10267. 10269. 10273. 10286. 10293 10296 10298 10302 10304 10310 10314 10317 10318 10321 10340 10359 10361 10366 10370 10373 10382 10384 10386 10412 10415 10418 10420 10422 10426 10427 10434 10448 10467 10485 10489 10494 10504 10507 10508 10515 10517 10522 10524 10526 10528 10531 10547 10550 10552 10553 10557 10558 10560 10563 10565 10568 10579 10591 10599 10604 0 5 5 5 0 5 5 0 0 5 0 5 5 5 0 0 5 5 0 0 0 0 0 0 0 5 5 5 0 0 5 5 5 0 5 0 5 0 5 0 5 0 5 0 0 0 5 0 0 5 0 5 0 5 0 5 5 0 0 0 10269.0 10271.5 10274.0 10288.0 10293.0 10296.5 10298.0 10302.0 10304.5 10310.0 10314.5 10318.0 10318.5 10321.0 10338.5 10359.0 10361.5 10365.5 10370.0 10374.5 10381.5 10383.5 10385.0 10411.5 10415 0 10417 5 10419 5 10422 0 10425 5 10427 0 10433 5 10448 0 10466 5 10486 5 10489 0 10493 5 10504.5 10507.5 10509.0 10515.0 10516.5 10520.5 10524.0 10525.0 10525.5 10530.5 10546.5 10549.5 10551 5 10553 0 10556 0 10559 0 10561 0 10566 5 10568 5 10572 5 10584 5 10595 5 10603 5 10608 5 10612 10623 10627 10629 10638 10639 10643 10743 10745 10747 10750 10769 10833 10835 10853 10856 10861 11802 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: 10616. 10626. 10631. 10632. 10641. 10643. 10646. 10740. 10742. 10743 10747 10767 10832 10833 10852 10856 10861 11802 DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP MERGE BASE 1 9982.0 10050.0 2 10050.0 10062.0 3 10062.0 10070.0 4 10070.0 10590.0 5 10590.0 10677.0 7 10677.0 10931.0 8 10931.0 11113.0 9 11113.0 11255.0 10 11255.0 11515.0 11 11515.0 11660.0 12 11660.0 11803.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP NFWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9957 11802.5 10879.8 3692 9957 Last Reading 11802.5 ROP 2 . 3873 1597 . 35 82 . 8353 3638 GR 16. 3022 307 . 407 46. 3809 3640 9984 11802.5 9957 11776.5 First Reading For Entire File .......... 9957 Last Reading For Entire File ........... 11802.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 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 ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9956.5 10024.5 ROP 9983.5 10050.0 $ LOG HEADER DATA DATE LOGGED: 02-APR-98 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: 42.5 MAXIMUM ANGLE: 42.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10050.0 9982.0 10050.0 NGP $ NATURAL GAP~VDA 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 (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 NGP SPC 164 3.800 3.8 SEAWATER/BIOZAN .00 .0 .0 0 .0 .000 .000 .000 .000 91.4 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9956.5 10050 10003.2 188 9956.5 GR 45.04 79.13 59.5246 137 9956.5 ROP 11.95 48.31 35.766 134 9983.5 Last Reading 10050 10024.5 10050 First Reading For Entire File .......... 9956.5 Last Reading For Entire File ........... 10050 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 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 ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10026.5 10040.0 ROP 10052.5 10061.5 $ LOG HEADER DATA DATE LOGGED: 03-APR-98 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: 42.6 MAXIMUM ANGLE: 42.6 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): MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10062.0 10050.0 10062.0 TOOL NUMBER NGP SPC 164 3.800 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SEAWATER/BIOZAN .00 .0 .0 0 .0 .000 .000 .000 .000 91.4 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10026.5 10061.5 10044 71 10026.5 GR 71.15 139.54 94.8068 28 10026.5 ROP 41.8871 52.1599 48.2703 19 10052.5 Last Reading 10061.5 10040 10061.5 First Reading For Entire File .......... 10026.5 Last Reading For Entire File ........... 10061.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Nunmber ........... 1.0.0 Date of Generation ....... 98/08/19 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 ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10040.5 ROP 10062.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : STOP DEPTH 10044.5 10070.5 04-APR-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10070.0 10062.0 10070.0 45.1 47.1 TOOL NUMBER SOLAR GM 74165 3.800 3.8 S EAWAT E R/BI OZAN .00 .0 .0 0 .0 RESISTIVITY (OHN~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .6 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 92.0 First Name Min Max Mean Nsam Reading DEPT 10040.5 10070.5 10055.5 61 10040.5 GR 106.345 159.853 141.522 9 10040.5 ROP 13.4933 40.2169 26.1128 18 10062 Last Reading 10070.5 10044.5 10070.5 First Reading For Entire File .......... 10040.5 Last Reading For Entire File ........... 10070.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 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 ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10046.5 ROP 10074.0 $ 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 10563.0 10590.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA_MMA P~AY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MTJD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) NfUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 05-APR-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10590.0 10070.0 10590.0 50.2 58.2 TOOL NUMBER SOLAR GM 74165 3.750 3.8 FLO- PRO 8.80 65.0 9.0 6.4 .000 .000 .000 .000 92.0 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR I~D 4 API 4 1 68 ROP MWD 4 FT/H 4 1 68 Code .6 Offset 0 4 8 Channel 1 2 3 Name Min Max Mean Nsam DEPT 10046.5 10590 10318.2 1088 GR 20.1755 307.407 71.2082 1034 ROP 2.3873 495.117 63.3076 1033 First Reading 10046.5 10046.5 10074 Last Reading 10590 10563 10590 First Reading For Entire File .......... 10046.5 Last Reading For Entire File ........... 10590 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 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 ....... 98/08/19 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: 5 DEPTH INCREMENT: .5000 FILE SUI~iARY VENDOR TOOL CODE START DEPTH GR 10564.0 ROP 10590.5 $ 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 10650.0 10677.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS4) 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) : 06-APR-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10677.0 10590.0 10677.0 54.3 54.5 TOOL NUMBER SOLAR GM 78655 3.750 3.8 FL O- PRO 8.80 65.0 9.5 5.6 .000 .000 .000 .000 73.0 .6 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 5 API 4 1 68 ROP MWD 5 FT/H 4 1 68 Code Offset 0 4 8 Channel 1 2 3 Name Min Max Mean DEPT 10564 10677 10620.5 GR 20.0546 63.5967 33.2269 ROP 6.8278 64.2857 20.6642 First Last Nsam Reading Reading 227 10564 10677 173 10564 10650 174 10590.5 10677 First Reading For Entire File .......... 10564 Last Reading For Entire File ........... 10677 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 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 ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log 7 header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH GR 10650.5 ROP 10677.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE 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 10904.0 10930.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 07-APR-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10931.0 10677.0 10931.0 50.1 52.6 TOOL NUMBER SOLAR GM 74165 3.750 3.8 FLO-PRO 8.80 65.0 9.5 5.6 .000 .000 .000 .000 75.0 .6 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 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10650.5 10930.5 10790.5 561 10650.5 GR 16.3022 33.7309 22.9634 508 10650.5 ROP 5.0991 928.125 70.0128 507 10677.5 Last Reading 10930.5 10904 10930.5 First Reading For Entire File .......... 10650.5 Last Reading For Entire File ........... 10930.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10905.0 ROP 10932.0 STOP DEPTH 11086.0 11112.5 $ 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 (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 08-APR-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11113.0 10931.0 11113.0 54.7 84.0 TOOL NUMBER NGP SPC 164 3.750 3.8 FLO PRO 8.80 65.0 9.0 5.6 .000 .000 .000 .000 77.3 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10905 11112.5 11008.8 416 10905 GR 18.9314 167.281 34.5608 363 10905 ROP 23.1128 900 89.2958 362 10932 Last Reading 11112.5 11086 11112.5 First Reading For Entire File .......... 10905 Last Reading For Entire File ........... 11112.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11086.5 11228.0 ROP 11113.0 11254.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 08-APR-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 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 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 MEMORY 11255.0 11113.0 11255.0 95.6 99.6 TOOL NUMBER NGP SPC 164 3.750 3.8 FLO PRO 8.80 65.0 8.3 7.0 .000 .000 .000 .000 80.0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AP1 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 11086.5 11254 11170.2 336 11086.5 11254 GR 22.4706 81.4704 36.4959 284 11086.5 11228 ROP 5.6628 1597.35 181.578 283 11113 11254 First Reading For Entire File .......... 11086.5 Last Reading For Entire File ........... 11254 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11229.0 11489.0 ROP 11257.0 11515.0 $ LOG HEADER DATA DATE LOGGED: 09-APR-98 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: 98.2 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11515.0 11255.0 11515.0 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 (OHlV~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 106.7 TOOL NUMBER NGP SPC 102 3.750 3.8 FLO PRO 8.80 65.0 8.3 7.0 · .000 .000 .000 .000 79.7 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 API 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11229 11515 11372 573 11229 GR 20.8037 85.5779 39.14 521 11229 ROP 30.5085 943.945 100.073 517 11257 Last Reading 11515 11489 11515 First Reading For Entire File .......... 11229 Last Reading For Entire File ........... 11515 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW 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 STOP DEPTH GR 11489.5 11635.5 ROP 11516.5 11660.0 $ LOG HEADER DATA DATE LOGGED: 09-APR-98 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: 100.2 MAXIMUM ANGLE: 107.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11660.0 11515.0 11660.0 TOOL NUMBER NGP SPC 102 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 FLO PRO 8.80 65,0 9.5 5.6 .000 .000 .000 .000 .6 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 3 180.0 First Name Min Max Mean Nsam Reading DEPT 11489.5 11660 11574.8 342 11489.5 GR 23.1627 118.269 42.1454 293 11489.5 ROP 28.1347 556.881 84.408 288 11516.5 Last Reading 11660 11635.5 11660 First Reading For Entire File .......... 11489.5 Last Reading For Entire File ........... 11660 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11636.0 11776.0 ROP 11661.5 11802.0 $ LOG HEADER DATA DATE LOGGED: 10-APR-98 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: 96.1 MAXIMUM ANGLE: 98.1 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): MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11803.0 11660.0 11803.0 TOOL NUMBER NGP SPC 102 3.750 3.8 FLO PRO 8.80 MUD VISCOSITY S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 65.0 9.5 5.6 .000 .000 .000 .000 .6 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 82.0 First Name Min Max Mean Nsam Reading DEPT 11636 11802 11719 333 11636 GR 21.5686 82.5062 33.4548 281 11636 ROP 50.4411 431.91 110.452 282 11661.5 Last Reading 11802 11776 11802 First Reading For Entire File .......... 11636 Last Reading For Entire File ........... 11802 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File