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Home My WebLink About200-062Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ ~- Z~:~,~. Well History File Identifier Organization (done) [] Two-Sided RESCAN DIGIT~-DATA OVERSIZED (Scannable) [] ~..Color items: ~' Diskettes, No. j [] Maps: '~ ,.~, ayscale items: [] Other, No/Type [3 Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [3 Other: [3 Logs of various kinds TOTALPAGES: 3 ? NOTES: ORGANIZED BY; BEVERLY BRE~HERYL MARIA LOWELL [] Other Project Proofing By: Date: PROOFED BY; BEVERLY BRE~~SHERYL MARIA LOWELL Scanned (done) PAGES: SCANNED BY; (at the time of scanning) BEVERLY BREN VINCENT~'~H/E"~R'~ARIA LOWELL RESCANNEDBY: BEVERLY BR~HERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ~) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged B Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2208' SNL, 2869' WEL, SEC. 02, T11 N, R13E, UM Top of Productive Horizon: 603' SNL, 692' WEL, SEC. 02, T11 N, R13E, UM Total Depth: 541' SNL, 97' EWL, SEC. 01, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 651958 y- 5974592 Zone- ASP4 TPI: x- 654101 y- 5976241 Zone- ASP4 Total Depth: x- 654889 y- 5976318 Zone- ASP4 18. Directional Survey 0 Yes B No 21. Logs Run: MWD, GR, ROP, CNL 22. Zero Other 5. Date Comp., Susp., or Aband. 10/5/2004 6. Date Spudded 05/17/2000 7. Date T.D. Reached 05/19/2000 8. KB Elevation (ft): 66.76' 9. Plug Back Depth (MD+TVD) 10813 + 9041 10. Total Depth (MD+ TVD) 10875 + 9038 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING SIZE' , 20" X 30" 13-3/8" 9-5/8" GRADE; , Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTIf'4GDEPTHM~_S7D"INGDE~l'HTVD "Hql.,¡; Top BOTTOM'TpP6oTTOM" ", :Slze', Surface 110' Surface 110' 36" Surface 2655' Surface 2655' 17-1/2" Surface 8815' Surface 8375' 12-1/4" 8307' 9289' 7894' 8829' 8-1/2" 9010' 10875' 8561' 9038' 3-3/4" ,CEMÊNTINGRECORD " 7.5 cu yds Concrete 3153 cu ft Arcticset II 1193 cu ft Class 'G', 130 cu ft AS I 401 cu ft Class 'G' 107 cu ft Class 'G' , TUalNGRECORD SIZE DEPTH SET (MD) 7", 26#, L-80 8256' 4-1/2", 12.75#, L-80 8256' - 8367' 25. ACID,' FRACTURE', ',CEMENT, SaUEEZE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9060' Set CIBP 8965' Set 1 st Whipstock, Damaged 8943' Set 2nd Whipstock 8948' P&A w/ 7.5 Bbls Class 'G' Cement PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl WT;PE:RFT. , Insulated 72# 47# 29# 6.16# 7" 2-7/8" 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED NO\! 1 5 2004 26. Date First Production: Not On Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED..... Oll-BSl Press. 24-HoUR RATE"'" 27. 24; NOV 2004 1 b. Well Class: B Development 0 Exploratory 0 Stratigraphic 0 Service 12. Permit to Drill Number 200-062 304-363 13. API Number 50- 029-20424-01-00 14. Well Name and Number: PBU F-11A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028280 17. Land Use Permit: TVD GAs-McF W A TER-BSl 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULl"ED ' PACKER SET (MD) 8256' CHOKE SIZE GAS-Oil RATIO GAs-McF W A TER-Bsl Oil GRAVITY-API (CORR) 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 Form 10-407 Revised 12/2003 0 R¡ f r, í \ Il7 i L CONTINUED ON REVERSE SIDE RBDMS BFL NOV 122004 (,ý 28. ') 29. ) GEOLOGIC MARKERS FORMATION 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". 23N 9322' 8861' None 23P 9330' 8868' 21N 9485' 8981' 21P 9490 8984' Top Zone 1B /14N 10028' 9014' 14P 10075' 9020' 13N / TDF 10612' 9040' '¿ü04 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbbl~ QAlliR- &.$ Hie Technical Assistant Date 11- {f{ -GL( PBU F-11 A 200-062 304-363 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Mary Endacott, 564-4388 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 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". SCANNED NO\f 1 5 2004 ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) Well: Field: API: Permit: F-11 B Prudhoe Bay Unit 50-029-20424-02-00 204-194 Accept: Spud: Release: Rig: 1 0/12/04 10/15/04 1 0/23/04 Nordic #1 PRE-RIG WORK 09/07/04 DRIFT TO 8280' (SLM) WI 3.625 SWAGE, SB (SB EMPTY). RUN PDS CALIPER TO 8280' SLM. 09/15/04 DRIFT WI 2.25 CENT & SAMPLE BAILER TAG @ 9510 SLM + 28' KB CORR = 9538' CORR MD. 09/16/04 CEMENT BOND LOG FROM 9395'-8257' MD, TOC FOUND AT 9028' MD. 1 0/05/04 SET BAKER 2-718" CIBP AT 9060 FT WITH E5-05 SETTING TOOL AND BAKER 05 LOW TEMP CHARGE. DID NOT TAG TO, NO PROBLEMS REACHING REQUIRED DEPTH. TAGGED CIBP TO CONFIRM SUCCESSFUL SET. 10/08/04 RAN ONE STRAND STRING SHOT FROM 9000' - 9012'. CHEMICAL CUT LINER AT 9010' AS PER PROGRAM. USED 2.125" CHC WITH ONE 1.69" X 72" CHEM TUBE, TWO CENTRALIZERS, E-LlNE JARS, CUT IN UNKNOWN FLUID AT 18° DEVIATION, 11" GAS GRAIN, ONE 2.13" WEIGHT AND SECURE FIRING SYSTEM. NO TUBING PUNCH WAS REQUESTED OR RAN DUE TO LINER HAD NO CEMENT OR PACKER ISOLATION ABOVE CUT. WHP = 50 PSI AND IA = 0 PSI AT TIME OF CUT. NO CHANGE IN PRESSURE FOR ENTIRE JOB. STRING SHOT AND CHC WERE CORRELATED TO SLB SCMT LOG DATED 16-SEPT-04 WITH GRICCL AS PER PROGRAM. TIED INTO GR AND COLLARS NEAR 9000'. TAGGED CIBP AT 9060'. PAD OP NOTIFIED WELL SHUT-IN AND SECURE. SCANNED NO\ll 5 2004 ) ) BP EXPLORATION 0 perati onsSu mrnCl~yReport Page 1" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/12/2004 Rig Release: 10/23/2004 Rig Number: N1 Spud Date: 12/27/1979 End: 10/23/2004 -Date From - To Hours Task Code NPT Phase Description of Operations 1 0/12/2004 01 :00 - 02:30 1.50 MOB P PRE PJSM on moving rig off well Move Nordic1 off of C-25b 02:30 - 04:30 2.00 MOB P PRE Scope derrick down make ready to mob to F-11 04:30 - 08:30 4.00 MOB P PRE Trave C-Pad to F-Pad 5.1 miles 08:30 - 1 0:20 1.83 MOB P PRE On F-Pad at 0830 hrs, Tool Service leveling F-11 area, Scope up derrick, NC Machinery Mechanic is working on Generator 10:20 - 10:30 0.17 MOB P PRE PJSM on moving over well. 10:30 - 11 :00 0.50 MOB P PRE Install SV platform, remove tree cap and move over well 11 :00 - 15:00 4.00 RIGU P PRE Rig Accepted at 1100 hrs 10/12/2004 Removed diesel from tree cap. Remove tree cap bolts and installing BOP's 15:00 - 20:00 5.00 BOPSUR P PRE PT BOP's as per APD # 204-194 to 3500 psi/ 300 psi. John Crisp AOGCC inspector waved witnessing BOP Test IA = 32 psi, OA 138 psi 20:00 - 21:15 1.25 BOPSUP P PRE Fill coil, circulate dart, Dart on seat at 56.4 bbls. press test inner reel valve. Open well, well is dead. Re-grease leaking Master valve. 21:15 - 21:30 0.25 PULL P DECaMP SAFETY MEETING. Review procedure, hazards and mitigation to M/U Baker fishing BHA. 21 :30 - 23:00 1.50 PULL P DECaMP M/U Baker fishing BHA #1 with 4. GS Spear, Hyd Disc, Jars, 2 x 3-1/8" drill collars, Accelerator, Swivel, Check valves and CTC. OAL = 80.8 ft. 23:00 - 00:00 1.00 PULL P DECOMP RIH with liner fishing BHA. Circ at min. rate. 10/13/2004 00:00 - 01 :00 1.00 PULL P DECOMP RIH with liner fishing BHA. Stop at 8000 ft. 01 :00 - 01 :30 0.50 PULL P DECOMP Continue to circulate 2# Biozan and displace diesel out of well. 2.2 bpm, 1660 psi. Divert diesel to tiger tank. 01 :30 - 01:45 0.25 PULL P DECOMP Stop pump,' Up wt = 30.5 K at 8250', Own wt. = 19.5K. RIH and tag fish at 8311' CTD, correct to 8312' BKB. Set down 3000 #. Pick up clean with liner, no overpull, 37.5K up wt. Flag coil at 8200' EOP. 01:45-04:10 2.42 PULL P DECaMP POH with 2-7/8. liner. Circ. at 0.5 bpm, 520 psi, 35.5K up wt at 8100'. 33.5K at 7500'. No overpull with liner for first 1000 ft off bottom. POH clean to surface. 3500 # at surface. 04:10 - 04:20 0.17 PULL P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out fishing BHA and 2-7/8. liner. 04:20 - 06:00 1.67 PULL P DECOMP Layout Baker fishing BHA, 3.70" deployment sleeve and 2-7/8" liner. LD BOT deployment sleeve with 2-7/8" PJ L = 8.34 ft 23 jts 2-7/8. Tubing len = 680.06.72 ft 1- 15.71 ft cut off2-7/8" jt Found two chem cuts (one partial) where expected only one. Total Length = 704.11ft Top 06:00 - 06:20 0.33 CLEAN P WEXIT PJSM on UR BHA Handling 06:20 - 07:00 0.67 CLEAN P WEXIT PU UR BHA wi 2 jts 2-3/8. tubing 07:00 - 08:45 1.75 CLEAN P WEXIT RIH. Set down in SSSV at 2008 ft. PU and RIH to flag. No correction at flag 08:45 - 13:40 4.92 CLEAN P WEXIT UtR using UR @ 2.00 bpm 1420 psi off btm. Didn't tag anything from 8500 ft to 8990 ft. .Clean hole. PUH to 8900 ft SCANNED NOV 1 ~5 2004 Printed: 11/1/2004 1:51:43 PM ') ') BP EXPLORATION Operations Sum maryR~p()rt Page 2'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/12/2004 Rig Release: 10/23/2004 Rig Number: N1 Spud Date: 12/27/1979 End: 10/23/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2004 13:40 - 14:10 0.50 CLEAN P WEXIT Reaming WS area again from 8900 ft to 8990 ft 14:10 - 14:20 0.17 CLEAN P WEXIT PUH to drop 3/4" ball to open CS. Displace to CS 14:20 - 15:15 0.92 CLEAN P WEXIT POOH. Op = 3.2 bpm 15:15 - 15:40 0.42 CLEAN P WEXIT OOH, LD UR BHA 15:40 - 16:00 0.33 CLEAN P WEXIT SAFETY METTING. RU PDS and SLB Eline 16:00 - 17:15 1.25 CLEAN P WEXIT RU Eline to run PDS Memory Caliper. Wait on Power Supply for PDS Computer. Make up tools, check PDS tools. Time = 1 :29 hh:mm 17:15 - 18:40 1.42 CLEAN P WEXIT RIH, Log Memory PDS Caliper log in 7", 29# liner 18:40 - 19:30 0.83 CLEAN P WEXIT POH with PDS caliper. 19:30 - 20:15 0.75 CLEAN P WEXIT Layout caliper and download data. PDS Caliper showed no cement in 7" liner with a 6.18" 10. Good to go for whipstock. 20:15 - 21:00 0.75 WHIP P WEXIT Prepare SWS E-Line running I setting tools with one EC weight bar. M/U Baker Gen II, 4-1/2" x 7",29# Whipstock set for high side tool face. No RA tag as per program. 21 :00 - 22:40 1.67 WHIP P WEXIT RIH with Baker Whipstock on SWS E-Line. Tied-in with CBL GRlCCL of 01/12/80. Logged up and positioned top of whipstock at 8965' as per program. Whipstock is set with 9 deg LOHS tool face with top of whipstock at 8965'. Good indication of tool setting. Stacked wt on whipstock and logged off. Whipstock is set OK. 22:40 - 23:30 0.83 WHIP P WEXIT POH with SWS running tools. 23:30 - 00:00 0.50 WHIP P WEXIT Layout SWS tools. Rig down SWS E-Line unit. 10/14/2004 00:00 - 00:30 0.50 STWHIP P WEXIT M/U Baker 3.80" window milling BHA with 3.80" HC diamond window mill and string reamer, circ sub, hyd disc, 2 jts PH6, check valves and CTC. OAL = 81.77'. 00:30 - 02:00 1.50 STWHIP P WEXIT RIH with window milling BHA #3. circ at 0.6 bpm. Tag whipstock pinch point at correct depth of 8970'. Flag coil at 8970'. 02:00 - 04:30 2.50 STWHIP P WEXIT Milling 3.80" window thru 7", 29# L-80 liner. 2.6 bpm, 2050-2200 psi, 3-4K WOB, slow milling, stacking wt with only 100 psi motor work, 2 stalls, Milled to 8972'. 04:30 - 06:00 1.50 STWHIP P WEXIT Milling window, 2.6 bpm, 2050-2200 psi, 4-5K WOB, stacking wt, slow ROP. Had very large stall at 8972.5 ft. Window not milling normal. Start stacking at 8971'. 06:00 - 09:30 3.50 STWHIP P WEXIT Milling window. Op = 2.6/2.6 CTP 2050/2142 psi. WOB 0 to 400lbm. The top of the window may be in question due to the orginal tag. Window milling acts normal starting at 8974 ft. CT stacking up in 7" 09:30 - 10:50 1.33 STWHIP P WEXIT Milling window. Op = 2.612.7 CTP 2050 I 2380 psi. WOB 0 to 18001bm. CT is stacking up in the 7" liner. Motor work, wt coming off slow, center section of mill could be damaged. 10:50 - 11 :00 0.17 STWHIP N DPRB WEXIT PU to 8960 ft, RIH, tagged at 8970 ft 5 time with motor work. Not able to get past top of whipstock. Top of whipstock must be damaged. 11:00 - 12:05 1.08 STWHI P N DPRB WEXIT POOH to set another WS and cement in place n'l c~ \::;, ?nrJ~ SCANNEr; N " f Printed: 11/1/2004 1:51:43PM ) ) BP EXPLORATION Operations Summary Report Page 3 .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/12/2004 Rig Release: 10/23/2004 Rig Number: N1 Spud Date: 12/27/1979 End: 10/23/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2004 12:05 - 13:35 1.50 STWHIP N DPRB WEXIT OOH LD Milling BHA, Mill cored with one jet welfded shut PT Casing to 400 psi, 20 minutes P = 300 psi 13:35 - 16:50 3.25 STWHIP N DPRB WEXIT RU Eline to reset WS PU WS orient to Pos Tool and confirmed. CCL to TOW 15.37 ft 16:50 - 18:30 1.67 STWHIP N DPRB WEXIT RIH and tie-in with GR. Position top of whipstock at 8943', tool face at 3 deg left of high side. Set whipstock, good indication of set at 42 seconds, saw 400# wt loss, log off. 18:30 - 19:30 1.00 STWHIP N DPRB WEXIT POH with SWS E-Line tools, recover 100% of BHA, all looked OK. 19:30 - 20:00 0.50 STWHIP N DPRB WEXIT RID SWS E-Line equipment. 20:00 - 20: 15 0.25 STWHIP N DPRB WEXIT M/U cementing nozzle and 6' stinger. OAL = 8'. 20:15 - 21:25 1.17 STWHIP N DPRB WEXIT RIH with cementing BHA. Held PJSM while RIH. Reviewed procedure, hazards and mitigation for pumping cement. Tagged Whipstock at 8958' with 3K WOB. Whipstock is inplace. Correct depth to 8948' CTD. Pick up 10 ft and flag coil at 8938'. 21 :25 - 22:00 0.58 STWHIP N DPRB WEXIT Press test cement line. Circ. 50 bbl fresh water to jet whipstock area. 22:00 - 22: 15 0.25 STWHIP N DPRB WEXIT Stage 15.8 PPB, G Cement, Pump 7.5 bbls cement. Stage 10 bbl fresh water behind cement with cementers. 22: 15 - 22:40 0.42 STWHIP N DPRB WEXIT Displace with 2# Biozan using rig pumps. Tag whipstock and pick up 1 ft. Jet whipstock with fresh water prior to cement reaching nozzle. Jet with 3.4 bpm, 2900 psi, Reciprocate coil from 8947-8920'. RIH and lay in cement from 8945 ft up to WCTOC of 8740'. Lay in at 1 bpm, pull at 27 fpm. Pull to safety at 8500'. Cement in place at 2230 hrs. 22:40 - 23:30 0.83 STWHIP N DPRB WEXIT WOC to gravity swap across whipstock. 3.8 bbls capacity below whipstock to swap with 7.5 bbls cement above whipstock. 23:30 - 00:00 0.50 STWHIP N DPRB WEXIT Dress off cement to 8928'. Circ out cement contaminate to surface with 2# Biozan at 3.1 bpm. 10/15/2004 00:00 - 02:00 2.00 STWHIP N DPRB WEXIT POH with cementing nozzle while chasing contaminated cement to surface. Discard all contaminated returns. 3.1 bpm. 02:00 - 02: 15 0.25 STWHIP N DPRB WEXIT Jet stack and all surface lines. 02: 15 - 02:30 0.25 STWHIP N DPRB WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U window milling BHA. 02:30 - 02:50 0.33 STWHIP N DPRB WEXIT M/U 3.80. HC diamond window mill and 3.80. HC diamond string reamer, motor, circ sub, hyd disc, 2 jts PH6, check valves and CTC. OAL = 81.8 ft. 02:50 - 05:00 2.17 STWHIP N DPRB WEXIT RIH with 3.80. window milling BHA. SWS UCA cement sample was at 600 psi at 5 hours. Cement in place for 6 hrs at 0430 hrs. Mill down to 8942' and set down at pinch point. correct depth to 8948'. 05:00 - 06:00 1.00 STWHIP N DPRB WEXIT Mill 3.8. window, 2.6 bpm, 1500 psi free spin, 1500-2000 PSI, 2K WOB. Milled to 8949'. 06:00 - 11:30 5.50 STWHIP P WEXIT Mill 3.80. window. Qp = 2.57/2.65 bpm, CTP = 1500/1715 psi, WOB 2-3klb Stall 8952.4 ft, PU and restart Milling window. Exited casing at approximately 8956 ft, Drilled 10ft formation to 8966 ft ~~CANN[ri NO\! 1 ~~; 200~~ Printed: 11/112004 1:51:43PM ) ) BP EXPLORATION Operations Summary Report Page 4- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-11 F-11 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/12/2004 Rig Release: 10/23/2004 Rig Number: N1 Spud Date: 12/27/1979 End: 10/23/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/15/2004 11 :30 - 13:10 1.67 STWHIP P WEXIT Back reaming window to 8944 ft. Reamed back to 8966.5 ft, Backed reamed and started mud swap with 50 bbl behind CT, dry tagged at 8966 ft. Clean window 13:10 - 15:00 1.83 STWHIP P WEXIT POOH chasing new Flo-Pro to surface 15:00 - 15:30 0.50 STWHIP P WEXIT LD Milling BHA. Window Mill 3.8"; String Mill 3.78. No-Go. Core point, good looking mill 15:30 - 17:15 1.75 DRILL P PROD1 Cut CT, install SLB CTC, pull tested to 40k Ibf and PT to 4k psi. PU DS100 BC bit, 1.04 deg motor and Sperry MWD tools. OAL = 65.22 ft 17:15 - 18:55 1.67 DRILL P PROD1 RIH and shallow hole tested at 3400 ft, OK. RIH to 8850'. 18:55 - 19:10 0.25 DRILL P PROD1 Orient TF to 20L. 19:10 - 21:00 1.83 DRILL P PROD1 Ran thru window clean. Tagged TO at 8972'. Corrected dept to 8966'. Drilled Sag River and Shublik, 2.6/2.6 bpm, 2800 - 3 0 psi, 36L, 21 deg incl, Drilled to 8990'. 21 :00 - 23:00 2.00 DRILL P PROD1 Drilling Shublik, 2.6/2.6 bpm, 2800-3800 psi, incl, 10-20 fph, Drilled to 9012'. 23:00 - 23:15 0.25 DRILL P PROD1 Orient TF to 1 OOL. 23:15 - 00:00 0.75 DRILL P PROD1 Drilling Shublik, 2.6/2.6 bpm, 2800- incl, 10-20 fph, Drilled to 9024'. 10/16/2004 00:00 - 02:30 2.50 DRILL P PROD1 Drilled Shublik, 2.6 / 2.6 bpm, incl, 15 fph, Drilled to 9062' 02:30 - 03:45 1.25 DRILL P PROD1 Drilled Shublik, 2.6 / 2.6 m, 2700 - 3800 psi, 90L, 21 deg incl, 20 fph, Drilled t 090'. 03:45 - 04:30 0.75 DRILL P PROD1 Drilled 24, 2.6/2 bpm, 2700 - 3800 psi, 90L, 21 deg incl, 30 fph, Drilled 9110'. 04:30 - 04:45 0.25 DRILL P PROD1 Wiper trip t indow. Clean hole. 04:45 - 05:15 0.50 DRILL P PROD1 Log GR 'e-in. Added 3 ft to CTD. 05:15 - 05:25 0.17 DRILL P PROD1 RIH ean to TD. 05:25 - 06:00 0.58 DRILL P PROD1 ed 24, 2.6/2.6 bpm, 2700 - 3800 psi, 90L, 21 deg incl, 30 fph, Drilled to 9135'. 06:00 - 08:47 2.78 DRILL P Drilling TF @ 111L in 2-4 Qp = 2.74/2.87 bpm, CTP = 2600/ 2875 psi. Vol P = 298 bbl. 08:47 - 10:11 1.40 DRILL P Drilling TF @ 111L to 86L in 2-3 Qp = 2.74/2.87 bpm, CTP = 2600/2875 psi. Vol P = 298 bbl. Top 23 at approximately 9197 ft. Drilled to 9207 ft, unable to get DLS/BR to make turn. 10: 11 - 11 :35 1.40 DRILL PROD1 POOH, 11 :35 - 12:00 0.42 DRILL PROD1 BHA handling. OS 100 at 1-1, PU HTC RWD RR bit adjusted motor to 1.37 deg 12:00 - 13:00 PROD1 Weld up 6 CT reel spokes 13:00 - 15:25 PROD1 RIH, shallow hole test at 3400 ft. Tagged window at 8957 ft. Orient TF to HS Went through 15:25 - 15:30 P PROD1 Tagged at 9207 ft Orient TF to 90L P PROD1 Drilling TF @ 83L in 2-3 Qp = 2.74/2.87 bpm, CTP = 2600 / 2875 psi. Vol P = 294 bbl ROP = 5 to 30 ftlhr Drilled to 9226'. 18:00 - 20:00 2.00 DRILL P PROD1 Drilling 23. slow, hard drilling, 2.6/2.6 bpm, 2750 - 3600 psi, 100L, 20 deg incl, 10 fph. Drilled to 9244'. Printed: 11/1/2004 1:51:43 PM SCt.\NNEr') l 5 200l} ~ ~ ~u!A\uŒ (ID~ !A\~!A\~æ!A\ AI/ASIiA OIL AND GAS ¡ CONSERVATION COMMISSION / ¡ , / FRANK H. MURKOWSKI, GOVERNOR / / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~............:j . . ". .N' Re: Prudhoe Bay F-IIA Sundry Number: 304-363 Dear Ms. Endacott: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF THE COMMISSION DATED this .& day of September, 2004 Enc!. r'- ~ i¡J4A ., (~Ptlrot STATE OF ALASKA RE " ALASKA Oil AND GAS CONSERVATION COMMISSION ' C E , VE 0 APPLICATION FOR SUNDRY APPROVAL SEP 2 92004 20 MC 25.280 ORIG'NAL R8DMS BF L Alaska Oil & Gas Cons. Commission 1. Type of Request: Anchorage III Abandon 0 Repair Well III Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. a Development 6 Exploratory 200-062 / 3. Address: 0 Stratigraphic 0 Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20424-01-00 7. KB Elevation (ft): 66.76' 9. Well Name and Number: PBU F-11A /' 8. Property Designation: 10. Field / Pool(s): ADL 028280 Prudhoe Bay Field / Prudhoe Bay Pool 11. :T'ii) ~~ >,i ~ ',.' . ,., ',,', Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10875 9038 10813 [B 9041 None None Casing. ) ,.')i) """.,.' ) .) Siið.', Ti)' X/it T\lBY. ':T,'itSurst .. ,"" .' it - f"'~n~' ""~r 110' 20" x 30" 110' 110' ~ 2655' 13-3/8" 2655' 2655' 5380 2670 8815' 9-5/8" 8815' 8375' 6870 4760 I inAr 982' 7" 8307' - 9289' 7894' - 8829' 8160 7020 Liner 2563' 2-7/8" 8312' - 10875' 7899' - 9038' 13450 13890 Peñoration Depth MD (ft): Peñoration Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 10125' - 10800' 9025' - 9041' 7",26# x 4-1/2", 12.75# L-80 8367' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'SAB' packer; Packers and SSSV MD (ft): 8256' 7" Otis SSSV Nipple 2008' 12. Attachments: 13. Well Class after proposed work: / a Description Summary of Proposal 0 BOP Sketch 0 Exploratory a Development 0 Service 0 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 5, 2004 0 Oil 0 Gas 0 Plugged a Abandoned 16. Verbal Approval: Date: 0 WAG DGINJ DWINJ 0 WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott A Title CT Drilling Engineer '-ff)¡j ) j J., /Ÿ A1tYlfl /(J j/ ¿3/8 /04- Prepared By NamelNumbe~ SiQnature Þhone 564-4388 Date Terrie Hubble, 564-4628 I JV' Commission Use Only 7 '-" I Sundry Number: . '?o '-1-. -:s (0 "< Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: AuJ p J t.?V e d r...orlM- Ie - 4o{ Y'êj c.Ú N? d fø, ,CA' ~ 1Y &-1£/( IM.PJI F -11 ß \ S"b'~"emF~~ ' ) 4-0'1 APPROVED BY Date ~ rg" / (J(þV Approved BJ---/' ~ COMMISSIONER THE COMMISSION Form 10-403 R~d 0 ~ ~ /Subnj£ In D6plicate SEP 3 0 1004 r'- ~ bp To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: Sep.28,2004 Re: CTD Sidetrack of well F-11A ~' F-11A is scheduled for a thru-tbg sidetrack with CTD rig, Nordic 1. From a through tubing whipstock, F-~iII build from a Sag River kick off to a Zone 1 B/2A target. A 2 7/8" clap will be set to isolate all perfs/, The following describes work planned to prep for sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. 1. Confirm mechanical integrity. 2. eline set Clap, chemical cut existing 2 7/8" liner / 3. service coil will check liner is free Prep will likely begin Oct. 5th, Nordic 1 is currently scheduled to arrive on the well - 10th Oct., Nordic 1 will pull the existing 2 7/8" liner and set the whipstock. 7Jlx/ ~~a¿¡ff- M.S. Endacott CTD Drilling Engineer CC: Well File Terrie Hubble r'- TREE = 6"(Ný WELlHEAD- McBlOY ACTUA TOR = OTIS KB. ELBI - 66.76' BF. ELEV = 38.16' KOP= 3400' flt'ax Angle = 95 @ 9779' !ßtum tvD - 9329' !ßtumlVD= 8800' SS 13-318" CSG, 72#, L-80, ID = 12,347" 8256' 2655' 7" mG, 26#, L-80, AB-IJ4S, 0.0383 bpf, ID = 6.276" Minimum 10 = 2.372" @ 8312' 2-7/8" LNER TOP OF 7' LI\R 8312. 8307' TOP OF 2- 7/8" LNR 4-112" TOO, 12.75#, L-80, 0,0152 bpf, ID = 3.958" 8367' 9-518" CSG, 47#, L-80, ID = 8.681" PERFORATION SUWMARY Re= LOG: SWS 01/09/80 ANGLEATTOPÆRF: 86 @ 10125' IIbte: Refer to Production DB for historical perf data SIZE SA' INTERVAL Opn/Sqz Dð. TE 2" 6 10125-10150 0 05129/04 2" 4 10200 - 10300 0 06iU1/00 2" 4 10340-10600 0 06iU1/oo 2" 4 10720 - 10800 0 06iU1/oo Œ§J1 9620' 7" LI\R, 29#, L-BO, 0.0371 bpf, ID = 6.184" 9673' F-11 A ~ SAFETY NOTES: CTD HORIZONTAL SIDE TRACK. 70o@ 9526' AND90o@ 9712' . 2008' 7' OTISSSSV NIP, ID= 3.813" 8302' 8312' 8334' 8367' 8361' 9265' 4-112" OTIS X NIP, 10 = 3.813" ŒR..OYMENT SLEBIE 4-112" BAKERSOS TOO TAIL HELtvD TT LOG NOT AVALABLE I MA RKER JOINT MLLOUT WINOOW: 3.80" FROM 9289' TO 9295' 2- 7/8" LNR, 6.16#, STL, L-80, 0.00579 bpf, 10 = 2.441" DATE REV BY OOMWENTS Dð. TE RBI BY COWM8'JTS 01/14/80 ORIGINAL OOrvPLEIlON OS/21/00 CRM cm HORIZ SOTRK COMPLET 03/06/01 SIS-MH OONV ERrED TO CANVAS 03/10/01 SIS-MD ANAL 03/04/02 RI\VTP OORRECTIONS ffiUŒlOE BA Y UNT WELL: F-11 A PERMIT No: 200-0620 API No: 50-029-20424-02 SEC2, T11N, R13E BP Exploration (Alaska) 1REE': 6" erN r'- WaLHEAD: McEVOY ACTUATOR: OTIS KB. aEV: 66.76' BF. aEV: 3S.16' KOP: 3400' Max Angle : 95 @ 9779' Datum MD: 9329' DatumTVO: SSoo'SS 1 13-3IS" CSG, 72#, L-SO, D: 12.347" I 2655' I Minimum ID = 7" TBG, 26#, L-SO, AB-U4S, 0.03S3 bpf, D: 6.276" TOP OF 7" LNR 8256' 830T 8320' TOCaSsUmng Sag River KOP H 14-112" TBG, 12.75#, L-SO, 0.0152 bpf, D: 3.95S" I 8367' 9-5/S- CSG, 47#, L-SO, D: S.6S1" IWHIPSTOa< H 8965' F-11 B ~ SAFETY NOTES: CTD HORIZONTAL SIDE TRACK - 70° @ 9526' AND 90° @ 9712' PROPOSED cm SIDETRACK . 2008' -17" OTIS SSSV NIP, D: 3.S13" I ÆRFORA l1ON SUMMARY REF LOG: SWS 01/09/S0 ANGLE AT TOP PERF: S6 @ 10125' Note: Refer to Production DB for historical perf data SIZE SPF MERVAL Opn/Sqz DATE 2" 6 10125 - 10150 0 OS/29/04 2" 4 10200 - 10300 0 06/01100 2" 4 10340 - 10600 0 06/01/00 2" 4 10720 - 10S00 0 06/01/00 7" X 4-1/2" XO 9-5/S" X 4-1/2" BAKER SAB PKR. D : 4.00" 4-1/2" OTIS X NIP. D: 3.S13" Top of 3-3/16" liner 3-1/2" X NIP ID: 2.S13" 4-1/2" OTIS XN NIP, MILLED? D: 3.725" 4-1/2" BAKffi SOS TBG TAL aMD TT LOG NOT A V ALABLE 9060' HCut and Pun 2-7/S" Doer I TOC(SCMT) H 9028' I I 3-3/16"X2-7/S"LinerH 10950' I 3-3/16 x 2-7/S X-over 17" LNR, 29#, L-SO, 0.0371 bpf, D: 6.184" H 9673' MiU,OlJT'vVIN[)()'!<! :,8('" fT(o\1 9289' TO 929b' DATE REVBY COMMENTS DATE REVBY COM\1ENTS 01/14/80 ORIGNAL COMPLETION 09/16/04 MSE PROPOSED ern ST 05121/00 CRM ern HORIZ SOTAK COMPlET 03I06IO1 SIS-~ CONVERTED TO CANVAS 03110101 SIS- MD FNAL 03104102 RWTP CORRECTIONS FRUDHOE BAY UNIT WaL: F-11B PERMrr No: API No: 50-029-20424-02 SEC2, T11N, R13E BP exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 . Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Repair Well 0 Pluq PerforationsD Pull TubingO Perforate New PoolO Operation Shutdown 0 Perforate ŒJ 4. Current Well Class: Stimulate D OtherO WaiverD Time ExtensionD Re-enter Suspended WellO 5. Permit to Drill Number: 200-0620 Name: BP Exploration (Alaska), Inc. Development [!] Exploratory D Service D 6. API Number 50-029-20424-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 66.76 8, Property Designation: ADL-0028280 11. Present Well Condition Summary: Total Depth Stratigraphic 0 9. Well Name and Number: F-11A 10, Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool measured 10875 feet Plugs (measured) None Effective Depth true vertical 9038.1 feet Junk (measured) None measured 10813 feet true vertical 9040.5 feet Casing Conductor Liner Liner Production Surface Length 80 982 2563 8787 2626 Perforation depth: Size 20" 9'1.5# H-40 7" 29# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 30 110 30.0 - 110.0 1490 470 8307 - 9289 7894.4 - 8829.1 8160 7020 8312 - 10875 7899.1 - 9038.1 13450 13890 28 - 8815 28.0 - 8375.3 6870 4760 29 - 2655 29.0 - 2654.9 4930 2670 Measured depth: 10125 -10150. 10200 -10300, 10340 -10600,10720 -10800 True vertical depth: 9025.19 - 9026.53,9027.95 - 9028.44,9030.18 - 9039.47,9043.23 - 9041.26 Tubing ( size. grade, and measured depth): 7" 26# L-80 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 4-1/2" Baker SAB Perm Packer 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descnptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - @ 26 @ 8256 @ 8256 8256 8367 '. I' Qil-Bbl 927 Representative Daily Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 1301 1405 16 7 0 0 1443 42.9 44.3 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas 0 Development Œ] Service D WAG 0 GINJD WIr'>JJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. .K 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Garry Catron Garry Catron f{ '" -"'--' ê1 Signature Form 10-404 Revised 4/2004 Tille Production Technical Assistant C al./~ Date 8/9/04 Phone 564-4657 OR\G\NAL " 't ' 1~1J b J. j1 I 4 ,II \ I -. l \ ' Li'. ,-1_- "1 ',\.:' \- I. l:. F-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/28/04 MIRU CTU #5. MU MHAlPDS GR/CCL IN CARRIER. PARTIAL KILL WI 1% KCL. RIH WI GR/CCL. CONTINUED ON 05/29/04 WSR. 05/29/04 CONTINUED FROM 05/28/04 WSR. RIH WI MEM CCUGR. LOG INTERVAL 10210'-9250' WI FLAG @ 10075'. POOH. MU/RIH WI 251 OF 2" 6 SPF GUN. TIE INTO FLAG. SHOOT INTERVAL 10125'-10150' POOH. RDMO. DSO TO POP. FLUIDS PUMPED BBLS 78 200 278 Methonal/W ater 1 % KCL TOTAL Page 1 1REE = WELLH;A 0 = AClUA TOR = KB. 8..EV = BF. 8..EV = KOP= rv'ax Angle = Datum MD = Datum lV 0 = 6"Cffl Mc EV OY 011S 66.76' 38.16' 3400' 95 @ 9779' 9329' 8800' SS 113-318" CSG, 72#. L-80. 10 = 12.347" H 2655' 7" TBG, 26#. L-80, AB-IJ4S, -i 8256' 0.0383 bpf. ID = 6.276" Minimum ID = 2.372" @ 8312' 2-7/8" LINER 1 TOP OF ì' LNR 1-1 8307' ITOP OF 2-7/8" LNR 1-1 8312' 14-1/2" TBG.12.75#, L-80. 0.0152 bpf. ID= 3.958" 1-1 8367' F-11A <I> ~ ~ ~ --d 1 ,," .... .i. --I 19-5/8" CSG. 47#. L-80. ID= 8.681" 1-1 8815' ~ 1 WHIPSTOa< 1-1 9286' PERFORATION SUMMARY RB= LOG: SWS 01/09/80 ANGLEATTOP ÆRF: 86 @ 10125' I\bte: Refer to Production DB for histoncal perf data SIZE SFF INTERVAL Opn/Sqz DA TE 2" 6 10125 - 10150 0 OS/29/04 2" 4 10200-10300 0 06/01/00 2" 4 10340 - 10600 0 06/01/00 2" 4 10720 - 10800 0 06/01/00 I A3TD H 9620' 1 7" LNR. 29#. L-80. 0.0371 bpf, ID = 6.184" H 9673' ~ . SAFETY NOTES: CTDHORIZONTAL SlDETRACK- 700@ 9526' AND 90° @ 9712' 2008' H T' OTIS SSSV NIP. ID = 3.813" 1 8256' HT' X 4-1/2" XO 1 8256' H9-518"X4-1/2"BAKERSABPKRID=4.00" 1 8302' H 4-1 (2." OTIS X NIP. ID = 3.813" I 8312' 1-1 DEFLOYMS\JT SLEEVE 1 8334' 1-14-1 (2." OTIS XN NIP. ID = 3.725" 1 8367' 1-14-1 (2." BAKER SOS TBG TAIL 1 8361' 1-18..rv1DTTLOGNOTAVALABLE 1 9265' I-IMARKER JOINT 1 MlLLOUT WINDOW: 3.80" FROM 9289' TO 9295' 1 PBTD 1-1 10812' 12-7/8" LNR 6.16#, STL. L-80. 0.00579 bpf, ID = 2.441" 1-1 10875' 1 COMMS\JTS DATE REV BY COMt.,'IENTS DATE REV BY 01/14/80 ORIGINAL COrvPLErION OS/21/00 CRM CTD HORlZ SD1RK COMPLET 03/06/01 SIS-MH CONVERTEDTO CANVAS 03/10/01 SIS-MD ANAL 03/04/02 RNiTP CORRECTIONS ffiUDHOE SA Y UNIT W8..L: F-11A PERMIT No: 200-0620 API No: 50-029-20424-02 SEC 2. T11N. R13E BP Exploration (Alaska) 10/07/03 Schlumberger NO. 2984 Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD 'P2-11 I t'~:~ "lq r~--, SBH TEMP & PRESSURE SURVEY 10/03107 GNI-01 'I~ -:~ -c~~ TEMP & PRESS SURVEY 10/04103 D.S. ~3-27/( lc~ I~; I~ ~_ LDL 10/01/07 D.S. 6-21A ~~~ LDL ~0/01103 D.S. 14-32 ~ ~~ LDL 10103103 c-23a ~-~ ~0~ MEM PPROF & IPROF LOG 09101103 F-13A ~ ~ ~ ~ MEM PPROF & IPROF LOG 09108~03 F-~ IA '~~ ~ MEM PPROF & IPROF LOG 09109~03 MPS-02 ~ INJECTION PROFILE 10104103 ~Ps-~o, ~ossg~34 c. EmT SCaT (PDC) 03/03/03 ~MPS-=0 ~~q ~ ~0SSg=34 SCMT 03/03/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~_~,~ !~, ~ - Date Delivered: OCT 0 -, ~. , ,"'~! ~',~ ¢", Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'CFN: Beth Permit to Drill No. 2000620 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. PRUDHOE BAY UNIT F-1 IA Operator BP EXPLORATION (ALASKA) INC MD 10875 TVD 9038 Completion Date 5/21/2000 ~-~/" Completion Status 1-OIL Current Status 1-OIL APl No. 50-029-20424-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No (data taken from Logs Portion of Master Well Data Maint) DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Interval Data Digital Digital Log Log Run OH / Dataset Type Media Format NN~ Scale Media No Start Stop CH Received Number Comments C ~--CNL 2 FINAL 8900 10806 D ~_//' NGP-MD 25 FINAL 9270 10875 q.J~ NGP-TVD 25 FINAL 8744 8971 Well Cores/Samples Information: CH 6/2712000 OH 7/18/2000 .~ fj ~, OH 7/18/2000 .31 ~j' ~,.~ O 7/18/2000 09581'"' 9271-10841 C 6/27/2000 09637 ¢ 8880-10810 Interval Name Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/¢9 Chips Received? ~ Analysis Received? ~ Daily History Received? ~Y N Formation Tops Receuived? ~ N Comments: Compliance Reviewed By: MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission' ,V Julie Heusser, ~'~'~\ DATE: March 27, 2001 Commissioner ~ Tom Maunder, ~..~o~ ~oc,._~::>% P. I. Supervisor FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests. Prudhoe Bay Unit · BPX / F-Pad March 27. 2001- I traveled to BPX's F-Pad in the Prudhoe Bay Field to-witneSs Safety Valve System tests. Merv Liddelow, BPX representative in charge of testing, 'performed the tests in a safe and proficient manner. Of the 24 wells tested, 13 failures were witnessed. Wells F-01 and F-15 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been corrected and successfully re-tested within 24 hours. The AOGCC test report is attached for reference. I conducted 24 well house inspections concurrent with the SVS tests, with n° exceptions noted. SUMMARY: I witnessed SVS tests and conducted well house 'inspectionS on BPX's F-Pad in the Prudhoe Bay Field. 24 wells, 48 components tested. 13 failures, 27.08% failure rate.. 24 well house inspections conducted. Attachments: SVS PBU F Pad 3-27-01 JJ cC,; N,.O,N~ONFIDENTIAL SVS PBU F Pad 3-27-0 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Uffit~ad: PBF/PBU/F-Pad Separator psi: LPS 153 Date: 3/27/01 j ii HPS 650 '11 ...... I' I ' i "' ' "11 E:~2f~}; ~:r~EL~;~'$J1&{E~ [~~ .... 7 ............... I ........... Well Permit Separ Set LfP Test Test Test Date .. .Oil, WAG, Gm J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ~-0i' ~700460 650 550 490 P 5 ' OIL F-02 1700560 650 550' 530 P P .OIL . F-03 1700580 ~-04 1710020 ' F-OS 1716090 650 550'! 330 i 4 ' ' OIL F-06 1710120 .... '" ~-07 1720230 ...... F-08 1740110 .. F-09 'i796760 '650 ' 550 '540 ~ 4 ..... OIL ~ ' , , , i , ~ , 2000670 , 2000620' 6~0 ' 55'0 ' 510' P 4 ' ' OIL F-12 '17910561 '650 ' 550 P P " ' oil F-13A 1961520 650 550 530 P ' 4 OIL F-14 1800120 V-i ' 650 55b 480 '3 P' ' ' OIL F-leA 1961600 650 550 410 P 'P- OIL F-I~A"' 1941630 153 '125 130' P 'P' ' OiL F-19 1811060 F-2i 1890560 153 ' 125 ' 115 P 'P 0IL F-22 1890620 " 650 ~50 0 2 P OIL F-23A 1990740 153 125 ' 0 2 P ' 'oiL F-24 1831540 F-26A' 1981890 ....... -27 ' J861690 i" , , , ', ,,'" ' ,' -28 1861590 Is i , I I , 1 F-29 1861330 F-30 1891100 V-31 1861570 650 550 0 2 P ' " 0iL F-32 18~0330 650 550 530 p p ., ., OIL F-33 1960030 . !F-34A 1961090 F-35 ' 1880810 650' 550 ~801' P "P .... OIL F-36 1951960 153 125 Oi 2 P OIL ~-37 ' 1890990 650~ '550 530' P P ' ' ' OIL ! RJF 1/16/01 Page 1 of 2 SVS PBu F Pad 3-27-01 JJ1 "I I' ' '! ' I ..... II ' " ' '~''" ' ' ' ' "' ' . " Well Permit Separ Set 'L~ Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI ,Trip Code Code Code Passed GAS or ~YCLr F-38 1901350 F-39 1901410 153 125 115 P P OIL F-40 1911170 ~01 ' 550 ~50 P ' P .... 'OIL F-41 ' 1911040'650 ~50 490 'P ~ ' OIL F-42 "i9oi58o ' 650 58o 53o 'e e "' om F-43 1'9i0750 153 125 ' 0 '1 P ...... OIL . F-44 1910080 F-~5 1910280 .... ' F-46 1901780 650 550 ~40 3 ' P ............. OIL F-47A 2000350 , F-48 1910860 , , ~ , ~ , , . . Wells: 24 Components: 48 Failures: 13 Failure Rate: Remarks: F-1, F-15 shut-in, operator rep. oas that all other, failures repaired and passed retest. RJF 1/16/01 Page 2 of 2 SVS PBU F Pad 3-27-01 JJ1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: DATE: Tom Maunder, P. I. Supervisor December 7, 2000 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX / F-Pad Thursday, December 7, 2000: I traveled to BPX's F-Pad in the Prudhoe Bay Field to witness Safety Valve System tests. Merv Liddelow, BPX representative in charge of testing, performed the tests in a safe and proficient manner. Of the 28 wells tested, 10 failures were witnessed. For the most part, frozen contaminants (water) in the block valves upstream of the pilots and in the SSV hydraulic control lines caused the failures. On 12/8/00 Mr. Liddelow indicated to me that aii SVS failures had been corrected and successfully re-tested. The 17.~'% SVS failure rate requires a 90-da~/test cycle for this pad. The AOGCC test report is attached for reference. I conducted 28 well house inspections concurrent with the SVS tests. Due to recent high winds, several well houses were drifted with snow inside. In addition, SVS hydraulic fluid leaks were noted on wells F-12 and F-13A. Mr. Liddelow indicated that these items would be addressed. No other exceptions were noted. SUMMARY: I witnessed SVS tests and conducted well house inspections on BPX's F-Pad in the Prudhoe Bay Field. 17.8% failure rate = 90 day test cycle. 28 wells, 56 components tested. 10 failures. 17.8% failure rate. 28 well house inspections conddcted. ' Attachments: SVS PBU F Pad 12-7-00 JJ CC: · NON-CONFIDENTIAL SVS PBU F Pad 12-7-00 JJ.doc Alaska Oil and Gas Conservation CommisSion Safety Valve System Test Report Operator: BPX Submitted By: Jeff Jones Date: 12/7/00 Operator Rep: Merv Liddelow Field/Unit/Pad: PBF/PBU/F Pad AOGCC Rep: Jeff Jones Separator psi: LPS 156 HPS 828 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE F-01 1700460 828 550 525 P P ' OIL F-02 i'~00560 828 550 500 P P OIL , , F-03 1700580 · , F-04 1710020 156 125 125 P P OIL ,,, F-05 1710090 F-06 1710120 ,,,, F-07 1720230 F-08 1740110 I F-09 ~790760 ' F-10A'' 2000670 · ' ' ' F-11A 2000620 828 550 500 P P OIL F-1.2 1791070 828 5~0 550 P P OIL F-13A' 1961520 828' 550 .525 P P OIL F- 4' i800120 I F-15 1811300 '828 550 490 P P 0IL F-16A 1961600 156 125 0 1 P OIL F-17A 1941630 156 125 .130 P P OIL F-19 1811060 F-21 1890560 156 1251 125 P P OIL: F-22 1890620 156 125 1~5 P P oil~ , I , .... F-23A 1990740 156 125 125! P P OIL F-24 1831540 F-26A 1981890 156~ 125 125 P 4 OIL , ,, F-27 1861690 828! 550 0 1 P OIL F-28 1861590 828! 550 500 P P OIL F-29 1861330 8281 550 250 3 4 OIL , F-30 1891100 F-31 1861570 F-32 '"18903301 828 550 520 P P OILI F-33 1960030i F-34A 19610901 F-35 188081.0 828 550 525 P P OIL F-36 1951960 828. 5'50 0 2 P " OIL F-37 , 1890990 828 550 550! P P OIL Page 1 of 2 SVS PBU F Pad 12-7-00 JJ.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI .PSI Trip Code Code Code Passed GAS or CYCLE F-38 19013'50 · F-39 1901410 156 125 1251 P P OIL F-40 1911170 828 550 0 ']' 5 OIL F-41 1911040 828 550 530 P P OIL F-42 1901580 F-43 1910750! 156 125 125 P P " O~L F-44 1910080 F-45 1910280i 828 550 0 1 ' P OIL F-46 1901780 828 550 50 . 3 P OIL F-47A 2000350 156! 125 130 "P P OIL F-48 1910860 156 125 100 P P OIL Wells: 28 Components: 56 Failures: 10 Failure Rate: 17.8%171 oo Day Remarks: 12/13/00 Page 2 of 2 SVS PBU F Pad 12-7-00 JJ.xls WELL LOG TRANSMYITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs ~ 06~'~ F- 11 A, AK-MW-00048 J~y 18,2000 1 LDWG formatted Disc with verification listing. API#: 50-029-20424-01 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ynn Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: dOL. '1 8 2000 ~aska Oil & Gas cons. ~ommisslan fin0h0ra.[l, o. Signed: BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company 0 I:t I I...1_ I I~1 5 5EI:tL/IC E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas ConserVation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs: F-11A, July 1.8, 2000 AK.-~-00~8 F-11A: 2" x 5" MD ~a Ray Logs: 50-029-20424-01 2" x 5" TVD Cranuna Ray Logs: 50-029-20424-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING-AND RETURNING A COPY OF.THE TRANS~~ LETTER TO THE ATTENTION OF: Sperry, Sun.Drilling Services Atto: Jhn Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED ,JUl. Date: Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska). !nc. Petro-technical Data Center, MB3-3 900 E....Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 6/15/00 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 250 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) /'2~'- Well Job # Log Description Date Blueline Sepia Color CD Prints B-10 ~ c,~/~q~ 20194 iRST 000505 1 1 1 F-10A -~'~',~C~ 20247 MCNL 000605 1 1 1 F- 11A ~J. ~ C~ '?~"~ 20235 MCNL 000520 1 1 1 H- 14A ~ ~ Q '~ 20183 RST 000416 1 1 1 R-07A .J~.. ~j'~'~"" 20161 MCNL 000406 1 1 1 X-16 '1~ ~/4~ 20245 RST 000604 1 1 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 JUN 2 7 2000 Alaska Oil & Gas Cons. uomrllissJofl Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 AAnTT~~rhae?re, AK 9/9~3-5711_ Received "-"" STATE OF ALASKA ALASKA ~iL AND GAS CONSERVATION COMrw,oSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-062 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20424-01 4. Location of well at surface ['~.:i;?i~i:i':~'~i'~;:"~ :! ~. 9. Unit or Lease Name 2208' SNL, 2869' WEE, SEC. 02, TllN, R13E,UM i ;~,:¥ ....... Prudhoe Bay Unit At top of prod,uctive interval ! ~, ~ ~/-.~L) ! 603' SNL, 691 WEL, SEC. 02, T11N, R13E, UM I--~. :"~ ...... At Jotal dep!hj~ ~..~:,~~ 10. Well Number 541 SNL, 97 EWL, SEC. 01, T11N, R13E, UM ~ ..... ! ............... ~ F-11A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 66.76' AMSL ADL 028280 10875 9038 FTI 10813 9041 FTI [] Yes [] No 2008' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ReP, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-TING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" 7.5 cu yds concrete 13-3/8" 72# L-80 Surface 2655' 17-1/2" 3153 cuft Arcticset II 9-5/8" 47# L-80 Surface 8815' 12-1/4" 1193cu ft Class'G', 130cuftASI 7" 29# L-80 8307' 9289" 8-1/2" 401 cu ft Class 'G' 2-7/8" 6.16# L-80 8312' 10875' 3-3/4" 107 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 7", 26#, L-80 8256' 8256' MD TVD MD TVD 4-1/2" Tailpipe 8367' 10200' - 10300' 9028' - 9028' 10340' - 10600' 9030' - 9039' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10720' - 10800' 9043' - 9041' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1100' Freeze Protect with 35 Bbls of MeOH ORIGINAL 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) May 25, 2000I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Sub .r~c3i~core,;cbips. 2. 2 2000 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. 23N 9322' 8861' 23P 9330' 8868' 21N 9485' 8981' 21 P 9490' 8984' Top Zone lB / 14N 10028' 9014' 14P 10075' 9020' 13N / TDF 10612' 9040' 31. List of A~achments: Summa~ of Daily Drilling Repo~s, Su~eys 32. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~/ ~ Title Technical Assistant III Date >'~ ~-~ F- 1 lA 200-062 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. 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: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28-' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: F-11A Accept: 05/16/00 Field: Prudhoe Bay Spud: 05/17/00 APl: 50-029-20424-01 Release: 05/21/00 Permit: 200-062 CTD Unit: Nordic #1 PRE-RIG WORK 05/06/00 MIRU Dowell CTU #2. PT lubricator and swab valve to 4000 psig. PT on top of master valve to 2500 psig. Both tests held good with very little bleed off. Loaded well down coil backside with seawater. RIH with Weatherford motor assembly and 3.5" Quiz Underreamer with (6.0") blades. Underream 3 passes from 9180' to 9320'. No returns. Well taking fluid at 2.6 bpm with no WHP. POOH and freeze protect tubing to 2000' with methanol. 05/08/00 Miru SWS #2158. RIH w/3 5/8" Baker Permanent Whipstock. Tie-in to Borehole Compensated Sonic Log (9-Jan-80). Set whipstock top at 9286', 6 degrees left of high side looking down. Tagged whipstock. POOH. RDMO. Contacted PC and Pad Operator to keep the well S/I. 05/10/00 Miru Dowell CTU #2. Rih w/cement combo nozzle, while killing well with seawater. Tagged whipstock tray and corrected +16' and set down to ensure whipstock is holding. Pre injection was 4.9 bpm at 420 whp. Mixed and pumped 23 bbls of 13.8 ppg of gel cement laden with aggregate. With nozzle above the whipstock and chokes closed pumped 11 bbls cement down, then opened chokes and laid cement in at 1:1 then picked up to safety while getting no returns. Shut down and let cement firm up for 30 rains then applied squeeze and obtained bbl/bbl returns while hold 1000 psi over a 30 minute period. Good squeeze. Dropped ball and jetted through to top of whipstock and cleaning tray good and chased to surface at 80%. At surface tested squeeze to 1000 psi, good test. Performed BOP test. PU window milling assembly (bha #2) and RIH. Mill out XN. Tag whipstock and start milling. Not making hole. Motor working but system not acting properly; suspect leak. 05/11/00 ~ POH. Found leak between CTC & back pressure valves. C/O and RIH. Tag whipstock at 9289 and start milling again. Cut window and made 8' of open hole to 9303 ctmd using 2 sweeps of biozan. Dress off window to ensure clean hole. Made 8-10 up down rotating passes over window and tray. 75% of the passes would quickly stall at 9282 but would not stall when motor was not turning. Pooh and confirmed with Nordic rig rep. Freeze protected coil and well with 6 bbls meoh (157'). Lwsi and plan to freeze protect flowline, bleed down, and have grease crew service well. .i,i.i .'~:.~'.~,; ~'~' i:~./i!: ";- COIL TUBING DRILLING 05/17/00 1 ' ¢'':. RU DS/N #1 on F-Pad. Remove tree cap. Spot rig over tree. Accept for operations at 1400 hrs 5/16/00. NU BOPE. Test BOPE. RU injector and new CT. Fill CT w/FW and pump dart. MU drilling BHA. RIH with BHA #1. F-1 lA, Coil Tubing Drilling Page 2 05/18/00 2 Finish RIH with drilling BHA #1. Tie-in at GR marker in 7" liner at 9205'. Work thru window with 2.5° short radius motor. Drill from 9303-9507' building angle from 13° to 70° and turning left. POOH for bit. Change bit. RIH with BHA #2. Drill from 9507-9675' finishing build and left turn. Drill from 9675-9989' (8942' TVD) with slight drop and right turn to head to polygon. Wiper to window. 05/19/00 3 Drill from 9990-10075'. POOH for motor bend. Change bit and motor. RIH with BHA #3 (1.1° motor). Drill at average 88.5° thru polygon from 10075-10710' with wiper trips when necessary. Swapped to new FIo Pro mud at 10324'. 05/20/00 4 Drill horizontal from 10710-10875' (TD). Wiper to window and back to TD, hole is clean. POOH for liner. LD drilling BHA. MU 85 its 2-7/8" 6.16# L-80 STL liner. MU Baker CTLRT. RIH on CT to TD. Release from liner. Displace mud to 2% KCI water. DS cementers load CT with 19 bbls 15.8 ppg G cement with latex. Load wiper dart. Displace with KCI water to latch collar at 10812' (PBD). POOH with CT while jetting to surface. LD CTLRT. WO SWS CNL. 05/21/00 5 MU SWS memory CNL. MU 86 jts 1-1/4 CSH workstring. RIH on CT. Log from 8900'-PBD. POOH and leave fresh FIo Pro mud in liner. Stand back 43 workstring doubles. LD logging tool. Pressure test liner lap at 2000 psi for 30 minutes. MU 23 2" SWS Powerjet perf guns. RIH on 32 workstring doubles. RIH on CT to PBD. Drop ball and perforate 10200-300', 10340-600', 10720-800' with 4 SPF. POOH with CT. LD 64 workstring singles. LD perf guns. 05122/00 6 Safety meeting for new crew on LD perf guns. Finish laying down guns. All shots fired. Load guns out of pipeshed. PU 1 1,4" CSH workstring from derrick & RIH. POH LD same. Freeze protect well to 1100' with methanol. Blow down CT with nitrogen for rig move. PJSM. Unsting coil from injector. Remove gooseneck from injector. Stand injector back for rig move. PJSM. Nipple down BOP stack & hang same. Jack rig up and back away from well. Install and test xmas tree cap. Prep for rig move to H Pad. North Slope Alaska Alaska State Plane 4 PBU_ WOA F Pad F-11A Surveyed: 19 May, 2000 SURVEY'REPORT 5 June, 2000 Your Reft API-500292042401 Surface Coordinates: 5974592.00 N, 651958.00 E (70° 20' 15.3888" IV, Kelly Bushing: 66.76ft above Mean Sea Level 148° 46' 01.1309" W) Survey Ref: svy9802 North Slope Alaska Measured Depth (ft) Incl. 9200.00 9286.00 9317.69 9347.69 9381.89 9427.49 9462.29 9487.89 ' 9526.49 9550.69 9573.69 9601.67 9637.89 9668.69 9711.69 9738.69 9779.49 9813.69 9857.49 9886.29 9918.29 9953.89 9984,49 10016.69 10050.69 Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Vertical Depth (ft) Survey Report for F-1 lA Your Ref: AP1-$00292042401 Surveyed: 19 May, 2000 Local Coordinates Northings Eastings (ft) (ft) 15.270 71.190 8676.07 8742.83 1041.40 N 2019.49 E 13.520 69.880 8759.37 8826.13 1048,51 N 2039.65 E 19.250 60.580 8789,77 8856.53 1052.36 N 2047,69 E 28.320 51.580 8817.20 8883.96 1059.22 N 2057.60 E 34.590 40.960 8846.38 8913.14 1071.62 N 2070.34 E 45.730 26.930 8881.25 8948.01 1096.07 N 2086.30 E 56.430 17.600 8903.11 8969.87 1121.11 N 2096.37 E 63.460 18,120 8915.92 8982.68 1142,18 N 2103.16 E 75.760 9.160 8929.37 8996.13 1177.26 N 2111,56 E 81.740 1.600 8934,09 9000.85 1200.86 N 2113.76 E 86.970 354.690 8936.36 9003.12 1223.72 N 2113.02 E 85.730 347.700 8938.14 9004.90 1251.29 N 2108.75 E 85.260 334.780 8941.00 9007,76 1285.41 N 2097.16 E 83.930 325.390 8943,91 9010.67 1311.96 N 2081.89 E 88.490 335.840 8946.75 9013.51 1349.29 N 2060.88 E 93.340 343.850 8946,32 9013.08 1374.60 N 2051.59 E 94.750 357.210 8943.43 9010.19 1414.65 N 2044.90 E 93,780 5.470 8940.88 9007.64 1448.72 N 2045.70 E 89,470 22.340 8939.63 9006.39 1491,05 N 2056,19 E 91.930 29.200 8939.28 9006.04 1516.97 N 2068,70 E 90.350 39,040 8938.64 9005.40 1543.42 N 2086.62 E 88.330 50.120 8939.05 9005.81 1568.74 N 2111.57 E 82.090 58.550 8941.61 9008.37 1586.50 N 2136.30 E 82.350 68.050 8945.98 9012.74 1600.82 N 2164,77 E 82.180 78.590 8950,57 9017.33 1610.47 N 2197.00 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5975674.11N 653955.97 E 5975681.63 N 653975.99 E 2.070 5975685.64 N 653983.94 E 19.832 5975692.70 N 653993.71 E 32.483 5975705.35 N 654006.20 E 24.409 5975730.13 N 654021.66 E 31.352 5975755.36 N 654031.22 E 37.099 5975776.57 N 654037.59 E 27.517 5975811.81N 654045.27 E 38.550 5975835.45 N 654047.00 E 39.350 5975858.28 N 654045.79 E 37.554 5975885.77 N 654040.96 E 25.322 5975919.64 N 654028.68 E 35.584 5975945.88 N 654012.88 E 30.656 5975982.77 N 653991.11E 26.461 5976007.89 N 653981.31 E 34.670 5976047.80 N 653973.82 E 32.845 5976081.88 N 653973.92 E 24.251 5976124.41 N 653983.55 E 39.729 5976150.58 N 653995.54 E 25.301 5976177,39 N 654012.92 E 31.137 5976203.20 N 654037.35 E 31.633 5976221.46 N 654061.71 E 34.187 5976236.35 N 654089.89 E 29.242 5976246.66 N 654121.91 E 30.721 Alaska State Plane 4 PBU_WOA F Pad Vertical Section (ft) Comment 2271.45 2292.55 2301,45 2313.43 2330.57 2356.32 2377.19 2393.28 2417.51 2430.79 2441.12 2450.64 2456.88 2456.26 2455.79 2459.81 2473.21 2490.29 2519.84 2543.27 2571.71 2605.75 2635.98 2667.82 2700.72 Tie-on Survey Window Point MWD Magnetic Continued... 5 June, 2000 - 8:49 - 2 - DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. 10090.17 10122.57 10154.77 10185.97 10220.77 10251.97 lO286.17 10312.77 10346.77 10377.77 10412.97 10443.97 10482.37 10508.77 10539.17 10571.27 10603.67 10642.67 10673.27 10714.27 10757.27 10792.67 10821.67 10851.27 10875.00 83.580 86.480 87.450 88.940 89.820 90.530 89.120 87.450 87.190 88.240 90.610 89.210 89.210 87.100 85.170 85.520 89.820 87.450 86.920 89.560 91.050 93.160 93.250 91.670 91.670 Azim. 89.840 92.13o 96.17o lOl.62o lO7.O7O 111.46o 116.56o 113.4oo lO8.83o lO4.96o lOO.39o 97.580 91.78o 90.020 86.850 83.51o 78.770 75.960 70.680 62.600 56.970 50.640 47.300 43.790 43.790 Sub-Sea Depth (ft) 8955.48 8958.29 8959.99 8960.98 8961.35 8961.26 8961.36 8962.16 8963.75 8964.98 8965.34 8965.39 8965.92 8966.77 8968.82 8971.42 8972.74 8973.67 8975.17 8976.43 8976.20 8974.90 8973.28 8972.01 8971.32 Sperry-Sun Drilling Services Your Ref: API-50029204240 Surveyed: 19 May, 2000 Vertical Depth (ft) Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (°/lOOff) 9022.24 9025.05 9026.75 9027.74 9028.11 9028.02 9028.12 9028.92 9030.51 9031.74 9032.10 9032.15 9032.68 9033.53 9035.58 9038.18 9039.50 9040.43 9041.93 9043.19 9042.96 9041.66 9040.04 9038.77 9038.08 1614.41N 2235.91 E 5976251.39 N 654160.73 E 28.496 1613.85 N 2268.18 E 5976251.48 N 654193.01 E 11.388 1611.53 N 2300.24 E 5976249.81N 654225.11E 12.886 1606.70 N 2331.04 E 5976245.61N 654256.00 E 18.100 1598.09 N 2364.74 E 5976237.68 N 654289.87 E 15.863 1587.79 N 2394.18 E 5976227.99 N 654319.51 E 14.253 1573.88 N 2425.41 E 5976214.71 N 654351.02 E 15.471 1562.66 N 2449.51 E 5976203.97 N 654375.34 E 13.432 1550.43 N 2481.18 E 5976192.39 N 654407.25 E 13.448 1541.43 N 2510.81 E 5976183.99 N 654437.06 E 12.925 1533.71N 2545.14 E 5976176.97 N 654471.54 E 14.624 1528.86 N 2575.76 E 5976172.75 N 654502.25 E 10.127 1525.73 N 2614.01 E 5976170.39 N 654540.56 E 15.103 1525.32 N 2640.39 E 5976170.51N 654566.94 E 10.405 1526.15 N 2670.71 E 5976171.95 N 654597.23 E 12.188 1528.83 N 2702.58 E 5976175.29 N 654629.05 E 10.428 1533.82 N 2734.55 E 5976180.92 N 654660.91 E 19.741 1542.35 N 2772.59 E 5976190.21 N 654698.77 E 9.424 1551.12 N 2801.86 E 5976199.57 N 654727.85 E 17.321 1567.35 N 2839.44 E 5976216.57 N 654765.10 E 20.722 1588.98 N 2876.59 E 5976238.95 N 654801.79 E 13.543 1609.86 N 2905.12 E 5976260.40 N 654829.90 E 18.836 1628.86 N 2926.96 E 5976279.84 N 654851.35 E 11.503 1649.57 N 2948.06 E 5976300.97 N 654872.03 E 12.994 1666.69 N 2964.48 E 5976318.43 N 654888.09 E 0.000 Alaska State Plane 4 PBU_WOA F Pad Vertical Section (ft) Comment 2736.73 2764.76 2791.75 2816.44 2841.84 2862.71 2883.41 2899.14 2921.o3 2942.68 2969.07 2993.59 3025.62 3048.55 3075.53 31o4.77 3135.2o 3172.65 3202.53 3243.29 3286.26 3321.32 3349.60 3378.o7 3400.69 Projected Survey Continued... 5 June, 2000 - 8:49 - 3 - DrillQuest 1,05,05 Sperry-Sun Drilling Services Survey Report for F-11A Your Ref:' API-500292042401 Surveyed: 19 May, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA F Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.090° (16-May-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 61.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10875.00ft., The Bottom Hole Displacement is 3400.88ft., in the Direction of 60.654° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9200.00 8742.83 1041.40 N 2019.49 E Tie-on Survey 9286.00 8826.13 1048.51 N 2039.65 E Window Point 10875.00 9038.08 1666.69 N 2964.48 E Projected Survey Continued... 5 June, 2000 - 8:49 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for F-1 lA Your Reh AP1-500292042401 Surveyed: 19 May, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA F Pad Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 9286.00 8826.13 To Measured Depth (ft) 9286.00 10875.00 Vertical Depth (ft) 8826.13 9038.08 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic 5 June, 2000 - 8:49 - 5 - DrillQuest 1.05.05 ALASi~A OIL AND GAS CONSERVATION CO~IPllSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit F~ 11A BP Exploration (Alaska) Inc. Permit No: 200-062 Sur Loc: 2208'SNL, 2869'WEL, Sec. 02, TI IN, R13E, UM Btmhole Loc. 662'SNL, 84'EWL, Sec. 01, T1 IN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF TH,~ COMMISSION DATED this O')-w-" day of May, 2000 dlf/Enclosurcs cc~ Department of Fish &Gamc. Habitat Section v,'/o encl. Department of Environmental Conservation v~'/o cncl. f'--- STATE OF ALASKA ALASKA _ .,_ AND GAS CONSERVATION COMM,_ JION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska).lnc. KBE = 66.76' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028280 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2208' SNL, 2869' WEL, SEC. 02, T11N, R13E,UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1178' SNL, 887' WEL, SEC. 02, T11N, R13E, UM F-1 lA Number 2S100302630-277 At total depth 9. Approximate spud date 662' SNL, 84' EWL, SEC. 01, T11N, R13E, UM 05/13/00 Amount $200,000.00 42. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028277, 662' MDI No Close Approach 2560 10791' MD/8973' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9297' MD Maximum Hole Angle 94 o Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Weiqht Grade Coupling Lenqth MD TVD MD TVD (include stare data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2473' 8318' 7838' 10791' 8973' 101 cuft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9680 feet Plugs (measured) Plug at 9582', CTU Squeeze Operation (05/89) true vertical 9213 feet Effective depth: measured 9582 feet Junk (measured) 19' of Perf Gun fish left in well (02/81) true vertical 9116 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 7.5 cu yds Concrete 110' 110' Su trace 2626' 13-3/8" 3153 cu ft Arcticset II 2655' 2655' Intermediate 8786' 9-5/8" 1193 cuft Class 'G', 130 cu ft AS I 8815' 8375' Production Liner 1366' 7" 401 cu ft Class 'G' 8307'- 9673' 7894'- 9206' RECEIVED Perforation depth: measured Open: 9466'- 9516'0 RIG IN A L Sqzd: 9420' - 9454' (two intervals) true vertical Open: 9002' - 9051' AJaska 0il & Gas Cons. L;ommissio~ Sqzd: 8957'- 8990' (two intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoi,~g is true and correct to the best of my knowledge Signed TedStagg-¢'~ Title CT Drilling Engineer Date : .:~. ::::::::::::::::::::: :, ~.~.,., ~::: ~:,:: :.~:~ :: ~ :,::::,,. ' :: . :, . :, ~ ;~ , , . 'P~rn~ii'N~mi~'~r'' """ ' I' APi N;mber " ,. F/'F ii i l-~ 1 i F iii' .,, .. ,,. I "Al::)P.~Val Date'' '1 See Cover letter .,,~.;~.,c:~-- 0 ~"~_. .I. 50-.029'20424~01 I (~'~ -/~ ~--~ I for other requirements Conditions of Approval: Samples Required [] Yes .~] No Mud Log Requireci [] Yes ,~] No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required ,~ Yes [] No Required Working Pressure for BOPE r-I 2K; r'l 3K; I~ 4K; ~ 5K; [] 10K; [] 15K Other: ORIGINAL SIGNED BY by order of Approved By Robert N. ChrJstenson Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX F-1 la Sidetrack Summary of Operations: F-11 is being sidetracked to target lower Zone 1 reserves. This sidetrack will be conducted in two phases. Phase 1: Underream liner, set whipstock, cement perfs, mill window: Planned for May 8-11, 2000. A Mechanical Integrity Test was successfully performed on 4/21/00. · A whipstock drift was run on 4/12/00. · A PDS caliper was run on 4/14/00. · Service coil will underream the liner prior to setting the whipstock. · E-Line will be used to set the whipstock at approx. 9286' MD. · Service coil will be used to cement perfs and mill the window. Phase 2: Drill and Complete sidetrack: Planned for May 13, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Seawater · Phase 2: FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,318' MD and cemented with approx. 18 bbls. cement to bring cement 200 ft above the window. The liner will be pressure tested to 2200 psi and perforated with coiled 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 attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray Icg will be run over all of the open hole section. Memory CNL will be run inside the 2 7/8" liner. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is approx. 3300 @ 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2244 psi. RECEIVED MAY 03 2000 Ataska Oil & Gas '"' ' ...... ~' TREE: 6" ClW WELLHEAD: McEVOY ACTUATOR: OTIS ~....,-'-11 a Pro 13-3/8,,,72#/ft, i 2,655, I L-80, BTRS FOC-- KOP: 3100' MAX ANGLE: 27° @ 6100' 7", 26/f/fi, L-80, AB-IJ-4S TUBING TUBING ID: 6.276" CAPACITY: 0.0382 BBL/FT Top of 2 7/8" liner to be approx. 8318'. TOP OF 7" I 8,307' I LINER 9-5/8", 47#/ft, I 8,815' I L-80, BTRS Top of whipstock approx. 9286' MD Cement to be downsqueezed past whipstock to abandon existing perfs PERFORATION SUMMARY REF. LOG: SWS - 01-09-80 S!ZF SPF INTERVAL OPEN/SQZ'D 3-1/8" 4 9420 - 9448' SQZD/5-14-89 3-1/8" 4 9448 - 9454' OPEN/5-19-90 3-1/8" 4 9466 - 9516' OPEN/5-18-89 INITIAL PBTD 7", 29/f/fi, L-80, BTRS 19,620' I 19,673' ~ed Com KB. ELEV = 66.76' BF. ELEV = 38.16' SSSV LANDING NIPPLE (OTIS) (3.813" ID) I 2,008' RECEIVED MAY 03 2000 Alaska Oil & Gas Cons. Commi~on 9-5/8" SAB PACKER I (BAKER) (4.000"ID) . 8,256' 4-1/2", 12.75/f/ft, L-80 TAILPIPE 4-1/2" "X" NIPPLE (OTIS) (3.813" ID) I8,302' 4-1/2" "XN" NIPPLE I (OTIS) (3.725" ID) 8,334' 4-1/2" TBG 18,367, TAIL (BAKER SOS) I8,361' (ELMD) 2 7/8" liner to be cemented to approx. 200' above window. AS OF 05-18-89 )LLOWING GSO CTU UEEZE OPERATIONS F-11 Vertical Section 0 8500 ~ ,-TSAD 8550 8600 8650 8700 875O ~-... 8800 8850 8900 8950 9000 9050 9100 Path Distance(Feet) 500 1,000 1,500 I I 2,000 I Angle ~ K.O.= 13 deg MD:9297 Tot Drld: 1494 ft 10791 TD Marker Depths ~Orit] Wellbore TZ3 I 8,6671f TVD Z2C I 8,7281ffTVD 8,9451 8,9451ff TVD s^o I 8,s361. vo IKick Off 8,770 Ift TVD 9,297Jff MD IDeprtr ~KO 2,311 ff I MD KO Pt g,2g7J MD New Hole 1494 Total MD 10,791 TVD TD 8,973 Curve 1 DLS de~lll00 Tool Face Length 6' 0 30 Curve 2 31 -20 250 Curve 3 31 ~90 199 Curve 4 31 90 499 Curve 5 12 -90 519 , 1,4971 Drown: 5/3/2000 9:20 Plan Name: Case 103 2,500 F-11 2,000 E ,.~ 1,500 500 1,500 I 2,000 2,500 X distance from Sfc Loc 1,000 I 3.000 JWell Name F-11 I CLOSURE IDistanceAz 3,333 ff6t de~l I NEW HOLE E/W (X) NIS (Y) Kick Off 2,020 1,091 TD 2,921 ~ 1,605 State Plane 654,879 5.976,197 Surface Loc 651.958 5.974.592 DLS de~lll00 Tool Face Length Curve I '6 0 ~0 ,Curve 2 31 -20 250 Curve 3 3t -90 t99 Curve 4 31 90 499 Curve 5 12 -90 5t9 1,497 Drawn: 5/3/2000 9:20 Plan Name: Case 103 12" 36" __Z 22.5" 18" 38"I 2 3/8" CT 10,000 psi Pack-Off Lubricator ~,I F-11a CT Drilling & Completion BOP 7 1/16" Annular 7 1/16" Pipe/Slip 2 3/8" 1/16' x 5,000 psi Slips ~ ~ 2 718" 7 1/16" Pipe ,~ ~ 2 3/8" I I SWAB OR MASTER VALVE / DATE [ CHECK NO, H 162400 VE.OOR ALASKAST 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 320300 CK020300I 100. O0 100. O0 HANDLINC INST' S/H TERRIE HUBBLE "lE A1TACHED CHECK ~ Bt PAYMENT FOR II~ DECRIED ABOVE. ~l[e]~l~-~l~ ~ 1 oeo OO 1 OO. OO ::BP.EXPLORATION :' 'P'o:B0X 196612 ... 'ANCHO~AGE;:ALAS~: 99519.6612 FiRST'NATIONAL :BANK OF ASNI~I~ND NATIONAL CITY BANK CLEVELAND, OHIO ~: ~-~89 .. ' 4'12 No. H · 1 62400 CONSOLIDATED COMMERCIAL ACCOUNT :00162400 PAY ONE 'HUNDREDi ~i& 00/1.**************************************** US DOLLAR "..'..;~?' ':~::i:';" ~:;:'::'i'i::i~ i~i:~.ii:' i".:.:::i:::: .'.'.':{ . :~i:: 'ii .:~:-I:I:: ! .i::.i! ' DATE AMOUNT : : . .......... : ALASI'[A STATE ..DEPT 13F. R-EV~E · i!::::, .i:'::; :: .;:;"'::;!::~:~!:: :i ;: · ::::: i. :" i':":?::: ":;:i:T° ::: The.i.:,:. NOT:VALID AFTER 120 DAYS ..... STATE OF ALASKA ~ ALASK/-, .iL AND GAS CONSERVATION COMi, .,SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon r'l Suspend [] Plugging [] Time Extension ri Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I [] Development KBE = 66.76' AMSL [] Exploratory 7. Unit or Property Name 3. Address Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2208' SNL, 2869' WEL, SEC. 02, T11 N, R13E,UM At top of productive interval 1178' SNL, 887' WEL, SEC. 02, T11N, R13E, UM At effective depth 1135' SNL, 775' WEL, SEC. 02, T11 N, R13E, UM At total depth 1126' SNL, 760' WEL, SEC. 02, T11N, R13E, UM [] Stratigraphic [] Service MAY 05 200O Alaska 0ii & Gas Cons. Commission Anchorage 8. Well Number F-11 9. Permit Number 179-106 10. APl Number 50- 029-20424-00 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 9680 feet 9213 feet 9582 feet 9116 feet Length Size Structural Conductor 110' 20" x 30" Surface 2626' 13-3/8" Intermediate 8786' 9-5/8" Production Liner 1366' 7" Plugs (measured) Plug at 9582', CTU Squeeze Operation (05/89) Junk (measured) 19' of Perf Gun fish left in well (02/81) Cemented MD TVD 7.5 cu yds Concrete 110' 110' 3153 cu ft Arcticset II 2655' 2655' 1193 cu ft Class 'G', 130 cu ft AS I 8815' 8375' 401 cu ft Class 'G' 8307' - 9673' 7894' - 9206' Perforation depth: measured Open: 9466'- 9516' Sqzd: 9420' - 9454' (two intervals) ORIGINAL true vertical Open: 9002' - 9051' Sqzd: 8957' - 8990' (two intervals) Tubing (size, grade, and measured depth) 7", 26#, L-80 to 8256', with 4-1/2" tailpipe to 8367' Packers and SSSV (type and measured depth) 9-5/8" Baker 'SAB' packer at 8256'; 7" SSSV Nipple at 2008' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation May 8, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Ted Stagg, 564-4694 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Numbec TerrJe Hubble, 564-4628 17. I hereby certify that the fore,long is true and correct to the best of my knowledge Signed Ted Stagg ~ Title CT Ddlling Engineer ·: . '::-.'.i, :':: ~- ~:- ..::'i .~"m~t~ion ~0nly 7.:-:.: Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission J Approval NO.~.~'~_//~.... / / ¢ Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate WELL PERMIT CHECKLIST COMPANY ,,,'~ WELL NAM~,,'"':/',/,,~ PROGRAM: exp~dev _,,,~ redrll ~'/ serv wellbore seg ann. disposal para req ~ FIELD & POOL ~/---'"~/'~__S';"~ INIT CLASS ,~ /"'~-' 7 GFF.,OL AREA ~ ~ UNIT# /'/'~".¢'<:~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to I(OOC,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~U (~N N C~u GEOLOGY 30. 31. 32. _ ..._~ .... 34. .,,'2 Permit can be issued w/o hydrogen sulfide measures ..... Y N .,,/',,./' Data presented on potential overpressure zones ....... ~>~.~K ~ Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [explorato~nly] Y N ANNULAR DISPOSAL35. With proper cementi~ records, this plan .... (A) will contai~e i~ a suitable receiving zone; ....... Y N APPR DATE (B) will not..edntamina/e freshwater; or~ drilling waste... Y N t)/~t no~;n~;p ~r e etl~sed~or-" (C air m ity of th disposal; Y N will not damage producing formation or impair recovery from a Y N / pool; and - (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N '~ oo -('¢ '~' GEOLOGY: ENGINEERING: UIC/Allnular.,.-~ COMMISSION: I ° Comments/Instructions: O z O rtl z c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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 APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Jul 17 12:30:59 2000 Reel Header Service name ............. LISTPE Date ..................... 00/07/17 Origin STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. eTS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ...................... 00/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-00048 S. LATZ C. SEVCIK/C. RECEIVED dUI... 1 8 000 Alaska Oil & Gas Cons. commis, sion OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9286.0 3.750 3.750 MWD RUN 2 AK-MW-00048 S. LATZ C. SEVCIK/C. MWD RUN 3 AK-MW-00048 S. LATZ C. SEVCIK/C. 2 lin 13E 2208 2869 66.76 .00 .00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING F-11A 500292042401 BP Exploration (Alaska), Inc. Sperry Sun 17-JUL-00 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2 . MWD RUNS 1 - 3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3 . DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG (MCNL GR OF 5/20/00). KICKOFF POINT FOR THIS WELLBORE IS AT 9286' MD, 8759' SSTVD (TOP OF WHIPSTOCK). 4 . MWD RUNS 1 - 3 REPRESENT WELL F-11A WITH API # 50-029-20424-01. THIS WELL REACHED A TOTAL DEPTH OF 10875'MD, 8971' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9271.5 10841.0 ROP 9301.5 10871.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 9271.5 9270.0 9310.0 9308.5 9324.0 9323.5 9329.0 9328.5 9335.0 9334.0 9344.5 9344.0 9367.5 9366.5 9372.5 9371.5 9379.0 9376.0 9389.5 9388.5 9393.5 9391.0 9400.5 9401.0 9415 . 5 9418 . 0 9445.5 9449.0 9450 . 5 9454 . 5 9464.~ 94~.0 9479.0 9479.5 9484 . 5 9485 . 5 9491 . 5 9492 . 0 9506.0 9509.5 EQUIVALENT UNSHIFTED DEPTH 9525.0 9537.5 9543.5 9608.5 9633.0 9640.5 9654.0 9657.0 9659.5 9662 0 9686 0 9704 0 9717 0 9735 0 9737 5 9742.0 9749.0 9754.5 9756.0 9758 5 9762 0 9771 5 9777 5 9782 0 9786 0 9794 5 9808 0 9810 5 9813.0 9831.0 9841.5 9845.0 9853.0 9865.5 9871.0 9877.5 9888.0 9897.5 9912.0 9916.5 9921.5 9979.0 9983.5 9988.0 10034.5 10042.0 10046.5 10054.5 10057.0 10063.5 10069.0 10075.5 10080.5 10097.0 10102.5 10126.0 10137.5 10163.0 10168.5 10172 0 10175 5 10188 0 10196 0 10204 5 10213 0 10232.5 10245.0 10268.5 9526.5 9537.5 9544.5 9609.0 9634.5 9641.0 9652.0 9656.5 9658.5 9661.5 9685.5 9704.0 9718.0 9735.5 9739.0 9743.5 9749.5 9754.5 9755.5 9758.0 9761.0 9769.0 9777.0 9781.0 9786.5 9793.0 9808.0 9810.0 9814.0 9829.0 9839.0 9843.0 9850.0 9863.0 9869.0 9874.0 9882.5 9892.0 9906.5 9910.0 9915.0 9974.0 9979.0 9985.0 10032.0 10039.0 10045.0 10055.0 10057.5 10063.5 10073.5 10080.0 10085.5 10099.0 10104.5 10130 0 10143 5 10170 5 10177 0 10179 0 10182 0 10193.5 10201.0 10209.5 10219.5 10237.5 10249.5 10271.5 10274.0 10285.0 10289.5 10292.5 10298.5 10307.5 10313.5 10317.0 10330.5 10333.5 10345.5 10348.5 10354.0 10358.5 10365.5 10369.5 10380.5 10385.5 10394.5 10406.5 10425.0 10434.5 10446.0 10460 0 10464 0 10479 5 10487 5 10495 0 10510 5 10514 0 10521 0 10523.5 10540.5 10544.0 10551.5 10557.5 10567.5 10571.0 10575.0 10581.5 10590.5 10609.0 10614.5 10621.5 10623.5 10627.0 10632 5 10647 5 10653 0 10654 0 10661 0 10668 0 10673 0 10676.5 10681.5 10684.0 10691.0 10712 0 10717 5 10724 0 10733 0 10736 5 10749 0 107~1 0 10777.5 10871.0 $ 10276.5 10287.5 10291.5 10295.5 10303.0 10310.5 10315.5 10318.0 10331.5 10334.0 10346.0 10349.5 10354.0 10359.5 10366 5 10372 5 10384 0 10387 5 10396 0 10408 5 10427 0 10435 5 10448 5 10461 5 10465 5 10481 5 10489 0 10497 0 10510 5 10514.0 10519.5 10524.0 10541.0 10545.5 10553.5 10558.0 10568.0 10573.0 10577.0 10583.5 10594.0 10614.5 10619.5 10624.0 10627.5 10630.5 10637.0 10649.0 10655.0 10657.0 10664.0 10672.0 10677.0 10681.0 10685.5 10688.0 10694.0 10717.5 10723.0 10727.5 10737.5 10740.5 10754.0 10755.5 10781.0 10874.5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 9270.0 9507.5 2 9508.0 10075.0 3 10075.5 10874.5 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 DEFT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9271.5 10871 10071.3 3200 ROP MWD FT/H 2.87 2246.5 116.044 3140 GR MWD API 14.8 166.53 35.7167 3140 First Reading 9271.5 9301.5 9271.5 Last Reading 10871 10871 10841 First Reading For Entire File .......... 9271.5 Last Reading For Entire File ........... 10871 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HE~/DER 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 GR 9270.0 ROP 9300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERS ION: 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 9477.5 9507.5 TOOL STRING (TOP TO BOTTOM) ~VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Loggin9 Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined ~bsent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 17-MAY-00 Insite 7.75 Memory 9507.0 19.3 56.4 TOOL NUMBER 2 3.750 Flo Pro 8.70 65.0 9.3 24000 6.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel .0 142.0 .0 .0 ~EPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 Name Service Unit Min Max DEPT FT 9270 9507.5 ROP MWD010 FT/H 2.87 185.29 GR MWD010 API 14.8 134.84 Mean Nsam 9388.75 476 58.3393 416 24.1056 416 First Reading 9270 9300 9270 Last Reading 9507.5 9507.5 9477.5 First Reading For Entire File .......... 9270 Last Reading For Entire File ........... 9507.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3%W 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 9478.0 10045.0 ROP 9508.0 10075.0 $ LOG HEADER DATA DATE LOGGED: 18-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10075.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : MOLE INCLINATION (DEG MINIMUM ANGLE: 81.7 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE NGP $ TOOL TYPE 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 (OHM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 2 3.750 Flo Pro 8.70 65.0 9.5 24000 6.0 .000 .000 .000 .000 .0 154.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9478 10075 9776.5 1195 ROP MWD020 FT/H 6.51 250.23 111.715 1135 GR MWD020 API 16.72 108.67 27.4774 1135 First Reading 9478 9508 9478 Last Reading 10075 10075 10045 First Reading For Entire File .......... 9478 Last Reading For Entire File ........... 10075 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10045.5 ROP 10075.5 $ 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 10844.5 10874.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MI/D 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: NUJI) PILTR3kTE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 19-MAY-00 Insite 7.75 Memory 10875.0 85.2 93.3 TOOL NUMBER 2 3.750 Flo Pro 8.65 65.0 9.0 24000 6.8 .000 .000 .000 .000 .0 159.0 .0 .0 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 Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10045.5 10874.5 10460 1659 ROP MWD030 FT/H 12.06 2246.5 134.888 1599 GR MWD030 API 19.08 166.53 44.3049 1599 First Last Reading Reading 10045.5 10874.5 10075.5 10874.5 10045.5 10844.5 First Reading For Entire File .......... 10045.5 Last Reading For Entire File ........... 10874.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Scientific Technical Services Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File