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Home My WebLink About201-118 Ima~t; Project Well History File Covert dge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 L - L L B Well History File Identifier Organizing (dom~) RESCAN 0 Two-Sided I III" 1111 ""I ø'/ Rescan Needed II 11111111 11111 .þ Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: DI~ALDATA vr Diskettes, No. J Other, NofType OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 0 NOTES: OVERSIZED (Non-Scannable) / ~f various kinds 0 Other w¡p - I 111111111 BY: BEVERLY ROBIN VINCENT SHERY~WINDY DATS: Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~~i)WINDY Scanning Preparation z:; x 30 = Þ 0 ',,-, + -/-..d:=- = TOTAL PAGES I-t;;;--- BY: BEVERLY ROBIN VINCENT SHERYL~INDY I Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: _YES_NO /sl Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: _YES _NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) I 11111" II ReScanned (i/HI/ltidual P,3fjr] [!:./H)('.Ì/j/ ,'Ifrolltlon) ,t,cðllnl¡¡fj \;()mplo~(¡d) " 1111111111 RESCANNED Bt: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ General Notes or Comments about this file: Quality Checked (don(;\¡ I 111111111 12/10/02Rev3NOTScanned.wpd · omm'SSI 1 a. Well Status: D Oil DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: Anchora2e 20AAC 25.105 20AAC 25.110 ~ Development D xploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 12/18/2005 201-118 305-376 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 01/09/2002 50-029-23026-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/4/2002 NS14 1179' FSL, 644' FEL, SEC. 11, T13N, R13E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 2961' FSL, 512 FEL, SEC. 10, T13N, R13E, UM 55.8' Northstar Unit Total Depth: 9. Plug Back Depth (MD+ TVD) 2934' FSL, 640' FEL, SEC. 10, T13N, R13E, UM 12931 + 11159 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 659831 y- 6030952 Zone- ASP4 13020 + 11244 Ft ADL 312799 TPI: x- 654644 y- 6032624 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 654507 y- 6032596 Zone- ASP4 NIA MD LO-N96-006 DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 39' MSL 1545' (Approx.) 21. Logs Run: RES, AIT, DT 1 BHC, CNL, LDL, GR, CALIPER, SP, MRES , DEN, SONIC, GYRO, USIT 22. CASING, LINER AND CEMENTING RECORD ....,..." ". ......... .,.{~~~ 'MD · 1..]_ .............. I , .'.i.·'i/. V· ···'þ7~~C~···· 0sd~'v "...tn ""'.i.2.?i \^.,.b;'~FT: Top BOrrOM Top BOTTOM "SI;;' .......... ii .. '.. ·.i ........ ..... / .... 20" 169# X-56 Surface 202' Surface 202' 20" Driven 13-3/8" 68# L-80 44' 3296' 44' 3208' 16" 633 sx PF 'L' 166 sx Class 'G' 9-5/8" 47# L-80 43' 10908' 43' 9292' 12-114" 665 sx Econolite 487 sx Class 'G' 7" 26# L-80 10741' 12471' 9148' 10715' 8-1/2" 281 sx Class 'G' 4-1/2" 12.6# 13Cr 12319' 13018' 1059' 11236' 6-1/8" 106 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and !24. /·i ii ,..' ... 'i, .......i... i.. , .. ..... ..... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#,13Cr-80 11806' - 12330' 12283' MD TVD MD TVD 125:.. '. ·.··......i·· ·('ci.''''......·.....· ...... i.i ..,....... ..i·..·f·i.i.i. i.. ..¡.\CID;, .i ....... ..., DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ') 11 " . ".1"" (, 11881' P&A with 10 Bbls Class 'G' t··' " ..~- 10211' Set Bridge Plug 10202' Set Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production NIA Date of Test Hours Tested PRODUCTION FOR OIL -BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED OIL -BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE'" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFl ,JUl 1 3 2006 ____.a..AI Form 10-407 Revised 12/2003 U K IlJ 11\J Ac6iNUED ON REVERSE SIDE e STATE OF ALASKA e RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JU WELL COMPLETION OR RECOMPLETION REPORT AND LOG L 1 1 2006 Alaska Oil & Gas Cons C n &, 28. GEOLOGIC MARKER NAME MD Top of Kuparuk 10243' Kuparuk 'C' 10472' Top of Miluveach 1 0845' Top of Kingak 11430' Top of Sag River 12460' Top of Shublik 12471' Top of Ivishak 12563' Top of Kavik 12653' 29. FORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8729' None 8920' 9237' 9752' 10704' 10715' 1 0803' 10888' 30. List of Attachments: Summary of Daily Drilling Reports and a Pre Rig Summary for NS14A. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Son a Stewma Ttle Technical Assistant Date07-{u'Ò NS14 Well Number 201-118 305-376 Permit NO.1 A roval No. Prepared By NameINumber: Drilling Engineer: Sandra Stewman, 564-4750 Dave Johnson, 564-4171 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". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e BPEXPLORATION Page 1 Operations· Summary Report legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: REENTER+COMPlETE Start: 12/28/2005 End: Contractor Name: NABORS ALASKA DRilLING I Rig Release: 5/21/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 1/3/2006 03:00 - 06:00 3.00 MOB P PRE Prep rig for move to NS-14, Lay mats & herculite 06:00 - 12:00 6.00 MOB P PRE PJSM & ATP with all personnel involved with rig move Move rig from NS-10 to NS-14 12:00 - 13:00 1.00 MOB P PRE Clean area after rig move 13:00 - 16:00 3.00 KILL P DECOMP Accept rig @ 13:00 hrs on 1/3/2006 Place tree stand in cellar, clean cellar area 16:00 - 18:00 2.00 KILL P DECOMP RU lines to tubing & lA, prepare to circulate out FP 18:00 - 19:00 1.00 KILL P DECOMP Pull BPV 19:00 - 20:00 1.00 KILL P DECOMP PJSM, Review plans to circulate out FP Discuss hazards associated with above tasks 20:00 - 22:00 2.00 KILL P DECOMP Reverse circulate 45 bbls FP diesel from tubing @ 1 BPM 150 psi Trip tank full of diesel 22:00 - 00:00 2.00 KILL P DECOMP Connect & test injection line from G&I to ,NS-32 disposal well 1/4/2006 00:00 - 03:00 3.00 KILL P DECOMP Transfer diesel from trip tank to G&I for disposal Reverse circulate to trip tank 61 Bbls FP diesel from tubing w/ sea water @ 1.3 BPM (total FP from Tbg 106 bbls) 02:30 - 05:00 2.50 KILL P DECOMP Circulate 220 Bbls FP diesel from IA w/ sea Water @ 1.3 BPM 05:00 - 08:30 3.50 KILL P DECOMP Circulate well bore w/sea water @ 6 BPM 630 psia Circulate Surface to Surface 757 Bbls 08:30 - 09:30 1.00 BOPSUF P DECOMP Monitor well bore, well static Install BPV, test from below to 500 psia 09:30 - 15:00 5.50 BOPSUF P DECOMP Bleed control line, ND Tree Terminate control line & fiber optic line 15:00 - 22:30 7.50 BOPSUF P DECOMP NU BOPs, choke & kill lines, accumulator hoses, riser & turn buckles 22:30 - 23:00 0.50 BOPSUF P DECOMP Pull BPV, Install TWC 23:00 - 00:00 1.00 BOPSUF P DECOMP MU 5.5" test joint, safety valves & x-overs 1/5/2006 00:00 - 01 :00 1.00 BOPSUF P DECOMP MU 5.5" test joint, X-Os & BOP test equipment 01 :00 - 04:00 3.00 BOPSUF N RREP DECOMP Test BOPE per AOGCC regs & BP policy - 250 psi low, 5000 . psi high. BOPE test witnessed by Tool Pushers Mark Ashley & Chris Page, WSLs Mike Dinger & Richard Watkins. Witness of BOPE test waived by AOGCC Rep Chuck Sheve Test BOPE w/5.5" test joint 250/5000 psi (upper pipe rams), Test failed, Repaired leaks on drilling spool, packing gland nuts, #6 valve on choke manifold & test joint x-o sub, Move to testing lower pipe rams, Test failed 04:00 - 05:00 1.00 BOPSUF N RREP DECOMP RD test joint, change out TWC, RU test joint 05:00 - 12:00 7.00 BOPSUF P DECOMP Test BOPE w/5.5" & 4.5" test joints, Test annular to 250/3500 - test ok, Test all other equipment to 250/5000. RID lest jt 12:00 - 15:00 3.00 BOPSUF N RREP DECOMP RlU & test lower IBOP & blind shear rams. Cycled IBOP several times before attaining good high test. 15:00 - 16:00 1.00 BOPSUF P DECOMP B/D top drive & RID testing equip't. 16:00 - 19:00 3.00 PULL P DECOMP RU to LD 5.5" tubing, Change bails & elevators, Pull TWC, MU landing joint, Back out hanger lock down pins 19:00 - 20:30 1.50 PULL P DECOMP Pull hanger from wellhead, Tbg hanger pulled free @ 280K, String wt 235K, Blocks weigh 70K Work hanger through BOP stack Printed: 5/2212006 11 :56:32 AM e BP EXPLORATION Operations Summary Report Page 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS14 NS14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 12/28/2005 Rig Release: 5/21/2006 Rig Number: 33E Spud Date: 1/8/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/5/2006 20:30 - 00:00 3.50 PULL P DECOMP Circulate through choke @ 6 BPM 130 psi, surface to surface, shut down monitor well, well static Circulate down flowline @ 12 BPM 460 psi 1/6/2006 00:00 - 02:30 2.50 PULL P DECOMP Circulate down flowline @ 500 GPM 460 psi, Pump 2X surface to surface, Pump high vis pill at beginning of each surface to surface circulation, Monitor well, well static 02:30 - 03:30 1.00 PULL P DECOMP LD landing joint & tbg hanger 03:30 - 05:30 2.00 PULL P DECOMP Level rig, raise & shim VLE side 05:30 - 07:00 1.50 PULL P DECOMP RU equipment to LD 5.5" & 4.5" tubing & spool control lines & fiber optics cable. 07:00 - 07:30 0.50 PULL P DECOMP PJSM for UD tubing. 07:30 - 21 :30 14.00 PULL P DECOMP LD 144 jts of 5.5",17#, 13Cr-80 Fox tubing spooling up control lines & fiber optics cable. 21 :30 - 22:30 1.00 PULL P DECOMP Band & remove fiber optic line from spool 22:30 - 00:00 1.50 PULL P DECOMP LD 15 jts of 5.5", 17#, 13Cr-80 Fox tubing spooling up fiber optic cable. 1/7/2006 00:00 - 07:00 7.00 PULL P DECOMP LD 64 jts 5.5", 17#, 13Cr-80 Fox tubing spooling up fiber optics cable. 07:00 - 07:30 0.50 PULL P DECOMP RD 5.5" tubing handling equipment, RU 4.5" tubing handling equipment 07:30 - 12:00 4.50 PULL P DECOMP LD 40 jts 4.5", 12.6#, 13Cr-80 Vam Ace tubing spooling up fiber optics cable LD 4.5" cut joint, cut joint length 5.08, clean uniform cut, no tearing , Total Tubing Laid Down: 233 jts of 5.5", 17#, 13Cr-80 Fox tubing 40 jts of 4.5", 12.6#, 13Cr-80 Vam Ace tubing 1 cut joint 4.5", 12.6#, 13Cr-80 Vam Ace tubing Length 5.08' 12:00 - 14:30 2.50 PULL P DECOMP RD tubing handling equipment, change out bails & elevators, clear & clean rig floor Clear pipe shed of 5.5" & 4.5" tubing, NORM test tree, adaptor flange, hanger and tubing. 14:30 - 15:00 0.50 PULL P DECOMP Install wear bushing 15:00 - 16:30 1.50 STWHIP P WEXIT RU E-line equipment 16:30 - 20:00 3.50 STWHIP P WEXIT Run 8.525 Gauge ring, junk basket, CCL & GR to 10,414 No tight spots, no recovery in junk basket 20:00 - 23:30 3.50 STWHIP P WEXIT MU Halliburton BP, RIH, correlate GR & CCL, Set BP @ 10,211',9.625 casing collar @ 10,217' Btm of BP @ 10,214' 23:30 - 00:00 0.50 STWHIP P WEXIT RD E-line equipment 1 18/2006 00:00 - 01 :30 1.50 STWHIP P WEXIT Clear rig floor, move whipstock & BHA components to rig floor 01 :30 - 03:00 1.50 STWHIP P WEXIT MU BHA, mills, MWD, float sub & XOs & RIH 03:00 - 04:00 1.00 STWHIP P WEXIT PU 21 jts 5" HWDP, RIH 04:00 - 04:30 0.50 STWHIP P WEXIT Shallow test MWD @ 500 GPM 425 psi, Test OK 04:30 - 05:00 0.50 STWHIP P WEXIT POH w/HWDP 05:00 - 06:00 1.00 STWHIP P WEXIT PU whipstock & MU to mill assembly & RIH 06:00 - 06:30 0.50 STWHIP P WEXIT Service rig, lubricate top drive 06:30 - 08:30 2.00 STWHIP P WEXIT PU 9 - 6.5" spiral drill collars & RIH 08:30 - 20:00 11.50 STWHIP P WEXIT TIH wI whipstock, mill assembly, drill collars, HWDP & 5" DP. Running speed 2 minutes per stand. 20:00 - 22:30 2.50 STWHIP P WEXIT Orient & Set whipstock assembly on bridge plug @ 10,202' Printed: 512212006 11 :56:32 ¡w, e . , BP EXPLORATION Page 3 . Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: REENTER+COMPLETE Start: 12/28/2005 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/21/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT I Phase Description of Operations 1/8/2006 20:00 - 22:30 2.50 STWHIP P IWEXIT measured depth Bottom of whipstock anchor 10,202', Whipstock oriented @ 30 degrees right PU wt. 285K, SO wt. 235K Top of window @ 10,181', Middle of window @ 10,190', bottom of window @ 10,198'. Set anchor w/26K down, PU to verify anchor set w/1 Ok over Sheared running bolt w/50K down, PU attempt to rotate, torqued up, work free 22:30 - 23:30 1.00 STWHIP P WEXIT Displace sea water in well bore wi 11.5 ppg mud 23:30 - 00:00 0.50 STWHIP P WEXIT Mill window in 9.625" casing. 1/9/2006 00:00 - 05:30 5.50 STWHIP P LNR1 Mill window in 9.625" casing, top of window @10,181' to FIT depth at 10,210'. WOM 2-4K, 70 RPM, 500 GPM, 1750 psi, Tq 16-17K, P/U wt 285K, SIO wt 235K, Rot wt 255K. Work mill assembly upldown through window - no problems 05:30 - 09:00 3.50 STWHIP P LNR1 Pump sweeps & circulate hole to clean metal from well bore. 570 GPM 1940 psi Recovered 91 Ibs of metal 09:00 - 09:30 0.50 STWHIP P LNR1 Perform Formation Integrity Test to 14.5# EMW, 1360 psi @ 8701' TYD, Test OK 09:30 - 10:00 0.50 STWHIP N RREP I LNR1 Investigate dropped object incident & repair top drive 10:00 - 10:30 0.50 STWHIP P LNR1 Monitor well, well static, blow down kill line, pump dry job 10:30 - 17:00 6.50 STWHIP P LNR1 TOH from 10,160' Slow purnp rate @ 8656' TYD, MP#1 - 2 BPM 270 psi, 3 BPM 310 psi MP#2 - 2 BPM 280 psi, 3BPM 320 psi Finish TOH to BHA 17:00 - 19:00 2.00 STWHIP P LNR1 LD BHA#1 - Milling assembly Mill 1/16 under gauge, Watermellon mill full gauge 19:00 - 21 :00 2.00 STWHIP P LNR1 Pull wear bushing, install bushing basket, RU BOP jetting tool, wash metal cuttings from BOPs Function test pipe rams & blind rams, wash metal cuttings from BOPs Install wear bushing 21 :00 - 23:30 2.50 STWHIP P LNR1 PJSM, Cut drilling line 23:30 - 00:00 0.50 STWHIP P LNR1 Service rig, lubricate top drive 1 11 0/2006 00:00 - 02:30 2.50 DRILL P LNR1 MU BHA #2. Adj. mud mtr to 1.5. PU MWD, check orientation. RIH wi HWDP. /t~ 02:30 - 03:00 0.50 DRILL P LNR1 TIH, Shallow test MWD at 575 gpm and 1370 psi. Test OK í {It .K 03:00 - 09:30 6.50 DRILL P LNR1 RIH to 10150' filling every 25 stds. "0'<1" _ 10'00 0"0 DRILL P LNR1 Fill DP. Orient tool face to 30 deg. right turn. 10:00 - 18:30 8.50 DRILL P LNR1 Directional drill from 10,210' to 10,409'. Slide: 6.75 hrs; rotate: o hrs.. Slow Pmp Rate: at 10,250' MD (8734' TYD); #1 36 spm @ 460 psi; #2 36 spm @ 480 psi. 18:30 - 20:00 1.50 DRILL P LNR1 Circ mud and pmp sweep off bottom. 20:00 - 21 :00 1.00 DRILL P LNR1 Back ream from 10,409' to 10,210'. No tight spots, no excessive drag or torque 21 :00 - 21 :30 0.50 DRILL P LNR1 Pmp dry job and blow down top drive. Service top drive. 21:30 - 00:00 2.50 DRILL P LNR1 POH to change BHA. At 6464' @ 00:00 hrs. Proper hole fill Printed: 5/2212006 11 :56:32 AM . . e e NS14A Accept: 01/03/06 Northstar Unit Spud: 01/10/06 50-029-23026-01-00 Release: OS/21/06 205-202 Ri: Nabors 33E PRE-RIG WORK 12/18/05 PUMP 5 BBLS MEOH SPEAR FOLLOWED BY 287 BBLS COLD SEAWATER TO COOL WELLBORE AND ESTABLISH INJECTIVITY. INJECTIVITY RATE 3.0 BPM @ 3300 PSI. CONFER WITH DAVE JOHNSON. MIX AND PUMP 10 BBLS 15.8 PPG CLASS "G" CEMENT FOLLOWED BY 263 BBLS 9.0 PPG BRINE. SEE LRS PUMP REPORT. 263 BBLS 9.0 PPG BRINE AWAY CEMENT IS AT PERF- BEGIN TO SEE SQUEEZE PRESSURE. SWITCH TO DIESEL WHP 2350 PSI 5 BBLS DIESEL AWAY WHP 3600 PSI. SHUT DOWN PUMPING. RINSE LINES TO GNI. WHP UP TO 4200 PSI DUE TO THERMAL EFFECT FROM WELLBORE WARMING AND ADJACENT WELLS FLOWING HOT. BLED WHP TO 3000 PSI AND WATCH. WHP CAME UP TO 3300 PSI IN 2 HRS. CONTINUE TO MONITOR WHP. 12/20/05 DRIFT TUBING FOR CHEM CUT - TAG CEMENT TOP SAT DOWN WITH 3.70" CENTRALIZER AND 1.50" SAMPLE BAILER AT 11832' WLM. COULD NOT WORK ANY DEEPER. POOH. BAILER EMPTY. REMOVE 3.70" CENTRALIZER. MAKE UP 2.50" CENTRALIZER AND 1.50" SAMPLE BAILER. SAT DOWN AT 11866' WLM AND WORK DOWN TO 11880' WLM. COULD NOT GO ANY DEEPER. TOOLS STICKING - 200 LBS OVER PULL - POOH. BAILER FULL OF CEMENT. SUMMARY; TAG AT 11832' WLM WITH 3.70" PROPOSED CHEM CUT +/-12226' MD CALL TOWN ENGINEER DAVE JOHNSON, DECISION MADE TO MAKE CUT AT 11800'MD. RD SLlCKLlNE UNIT, MOVE IN E-LlNE UNIT FOR TUBING PUNCH - STRING SHOT - CHEM CUT @ +/- 11800'MD 12/22/05 TAG CEMENT TOP AT 11881' ELMD WITH 2.13" TOOL STRING. PUNCH HOLES IN TUBING AT 11762 - 11764' ELMD. RUN STRING SHOT FROM 11794' - 11806' ELMD. 12/23/05 SIDETRACK PREP. CUT TUBING WITH 3.625" CHEMICAL CUTTER AT 11806' ELMD, 3' BELOW TUBING COLLAR. CHEMICAL DISBURSED EVENLY THROUGH SEVERING HEAD INDICATING GOOD CUT. 12/27/05 BLEED ALL PRESSURES TO 0 PSI. VETCOGRAY SET BPV. REMOVE SCAFFOLDING. PREP FOR OPERATIONS TO REMOVE FLOWLINE FOR UPCOMING SIDETRACK. . . Date: 03-15-2006 Transmittal Number:92763 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 A{) H l ¥ SW Name Date Contractor Loq Run Top Depth Bottom Depth Log Type VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE NS14 01-07 -2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD NS24 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11500 11867 CHEMICAL CUTTER RECORD NS08 10-26-2005 SCH 1 11130 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07 -31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD ~ú , ....,\\'6 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ;JD¡~ }(8 Rtt¿ BPXA WELL DATA TRANSMITTAL I I I I I I íLl ðiLI Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center . Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug chromanski Ignacio Herrera Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . Date: 03-15-2006 Transmittal Number:92763 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc e e '~::::;¡ i'. ¡ ;? '., ~ ì..:=I FRANK H. MURKOWSKI, GOVERNOR AIIASIiA. OIL AND GAS CONSERVATION COMMISSION Pat Arçhey . Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 ' Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: North Star NS14 Sundry Number: 305-376 \ ' \\~ I~O\ Dear Mr. Archey: ;¡;;:f-:á....\Mq. \:'~no~-~ '!~;.,.. r !¡ iÎ" ~d IJ Ic;~ 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Chai DATED thisÞ day of December, 2005 Encl. Cf} ,2- - ,~...'OS' 1IJ4~ , Lt t 2-' 2.-00$ e STATE OF ALASKA e 'O,S 12/1¡J¿~ ALASKA OIL AND GAS CONSERVATION COMMISSlclNECEIVED APPLICATION FOR SUNDRY APPROVAk 0 92005 20 AAC 25,280 Alaska Oil & Gas Cons. Commi$siQfj _ n_~ 1. Type of Request: II Abandon // o Suspend o Operation Shutdown o Perforate o Other Anchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Developmen~D Exploratory 201-118 ,/ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23026-00-00 / 7. KB Elevation (ft): 55.8' 9. Well Name and Number: NS14 ./ 8. Property Designation: 10. Field / Pool(s): ADL 312799 Northstar Unit 11. PRESENT WELL CONDITION ,SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth UD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13020 11244 12931 11159 None None Cas in a Length Size i\t1D ;' TVD Burst Collapse Structural 202' 20" 202' 202' 4260 2590 3252' 13-3/8" 3296' 3208' 4930 2270 10865' 9-5/8" 10908 9292' 6870 4760 Prnrh It"tinn 1730' 7" 10741' - 12471' 9148' - 10715' 7240 5410 I inAr 699' 4-1/2" 12319' - 13018' 10569' - 11236' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 12860' - 12910' 11085' - 11133' 5-1/2', 17#X 4-1/2',12.6# 13Cr-80 10147', 10147' - 12330' Packers and SSSV Type: 7" x 4-1/2" Baker S-3 Packers and SSSV MD (ft): 12283' 12. Attachments: 13. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch o Exploratory 181 Development o Service o Detailed Operations Program 14. Estimated Date for Decembe4)005 15. Well Status after proposed work: Commencing Operations: o Oil o Gas o Plugged 181 Abandoned 16. Verbal Approval: Date~ o WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Johnson, 564-4171 Printed Name Pat Archey Title Senior Drilling Engineer fa;) (L.,.Q. - Prepared By NamelNumber: Signature Phone 5 (, <¡ - c;" g" ? Date';l/oCf 1,,("'_ Sondra Stewman, 564-4750 I' Commission Use Only . , Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 30::;--3'7 i: o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: l' e~ t ßoPE f-o , 5000 f~' RBDMS BFL DEC 1 4 2005 ,"~q~(Íja01. Approve~~ II ÞI / APPROVED BY Date /1-,,/3 .". t>"s COMMISSIONER THE COMMISSION Form 10-403 R~d o~ - v "--- Submit In Duplicate ORIGINAL e e bp ../ ~Ii Northstar NS14 Ivishak Producer Sundry Notice Abandon Well For Sidetrack Operation NS14 experienced high GOR in the Ivishak production from either gas coning or communication with nearby gas injectors, As a result, NS14 has been shut-in, It is planned to abandon the current wellbore in the Ivishak and sidetrack NS14 with a horizontal lateral at a /' new location, This will be achieved using a fullbore down-squeeze of -8 bbl of Class G, 15.8 ppg cement while displacing the tubing volume, The existing tubing will be chemically cut at approximately 12,266' MD and pulled, A bridge plug will be set in preparation to sidetrack the well through a window above the bridge plug as per drilling permit. Abandonment Procedure Pre-Ria ODerations 1, Test 9-5/8" pack-off to 5000 psi. 2, MIT inner annulus to 4200 psi. 3, Through tubing cement squeeze perforations with 15,8 ppg cement slurry, Final cement volume should be determined by injectivity test. Minim~m. nt volume should be sufficient to cover perforations and leave TOC at +/- 1 4 ' MD. This is 505' of cement above the PBTD of 12931' and requires a mini . volume of 7,7- BBLS to fill the liner, Desired minimum volume is 9,7 BBLS of cement slurry, (7.7 BBLS to fill pipe and 2 BBLS into perfs, WOC 4. Run wireline drift tubing and tag TOC. Pressure test tubing to 2000 psi. " 5, Chemically cut tubing at 12266' TMD above packer, 6, Install BPV, / Page 1 e e Drillina Ria ODeration: 8, MIRU, 9, Circulate well clean with sea water, 10, NU BOPE and test to 5000 psi. / 11, Pull 5-1/2" X 4-1/2" tubing string 12, PU DP, RI H w/ casing scraper to +/-10400', 13, RIH and set 9-5/8" bridge plug at - 10234' TMD in preparation to sidetrack well through window above bridge plug as per drilling permit. Final setting depth will be determined by CCL to space out bridge plug for whipstock, The desired top of window is 10214'. Pressure test bridge plug, -- Present Casing/Tubing Hole Casing WtlFt Grade Conn Burst Collapse Top Top Btm BTM Length Size Size TMD TVD TMD TVD 42 20 169 X-56 Weld 0 0 159 159 159 16 13-3/8 68 L-80 BTC 5020 2260 0 0 3296 3216 3296 12,25 9-5/8 47 L-80 BTC 6870 4750 0 0 10908 9296 10908 8.5 7 26 L-80 BTC-M 7240 5410 10741 9156 12471 10721 1730 6,125 4-1 /2 12.6 13CR Vam Ace 8430 7500 12319 10575 13018 11244 699 TBG 5-1 /2 4,6 13CR Vam Ace 7740 6290 0 0 10147 8653 10147 TBG 4-1 /2 12.6 13CR Vam Ace 8430 7500 10147 8653 12331 10586 2184 Present Perforations Formation TVD TVD Sqz/Open BHP Gradient EMW Pressure Psi/ft Ib/aal Ivishak 12766 -12916 11 001 - 11145 Squeezed Sqz Sqz Sqz Ivishak 12860 - 12910 11 090 - 11139 Open 5126 0.462 8,9 Bottom Hole Temp estimated at 254 degrees. BOP Test Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS,) ~ 5000 psi working pressure pipe rams (2) ./ ~ Blind/shear rams ~ Annular preventer Based upon the calculations below, BOP equipment will be tested to 5000 psi. Page 2 e e Maximum Surface Pressure - Full Column of Gas from TD - 0.12 Gradients - si/ft Formation Gas 8.9 0.12 TVD 11139 si/ft radient Pressures Surface 1.2 * Surface 3818 4582 Ivishak Production Interval BHP 5155 ./" Page 3 TREE = ABB-VGI5-118" 5K ~.NOTES:***4-1/2" & 5-112" CHROMETBG& WELLHEAD - ABB-VGI13-5/8" MUL TIBOWL 5 NS14 ACTUA TOR = KB. ELEV = 55.51' BF. ELEV = 39.61' (CB 15.9') KOP- : :---1 1638' 1-113-3/8" STAGE COLLAR 1 Max Angle = 39" @ 3700' Datum MD = . 1957' H 5-1/2" SSSV w / HRQ, ID = 4562" I Datum TVD = 113-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 1 3297' 1---4 ... GAS LIFT MANDRELS 1ST MD 1 TVD 1 DEV I TYPE 1 VLV 1 LATCHI PORT I DATE L 1 1 49441 45021 39 1 1 1 I Minimum ID = 3.725" @ 12318' 4-1/2" XN NIPPLE 5-1/2" TBG, 17#, 13CR FOX, 0.0232 bpf, ID = 4.892" 10147' 10147' ~ 5-1/2" X 4-1/2" XO I / 1 TOP OF 7" LNR I 10741' 8 9-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681" 10908' ~ .... I 12242' H 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" I 12255' ELM H4-1/2" FIBER OPTIC TRANSDUCER, ID - 3.958" I I I 12261' ~4-1/2" X NIP, ID - 3.813" I · ~ I 12283' -f7" X 4-1/2" BAKER S-3 PKR I ~ I I 12307' -14-1/2" X NIP, ID = 3.813" 1 · I - 12318' ~ 4-1/2" XN NIP, ID = 3.725"1 · TOPOF 4-1/2" LNR 1 12319' I 12330' 4-1/2" SELF ALIGNING WLEG I 1~-1/2"TBG, 12.6#, 13CRVAM-ACE, 12330' ~ >< I 0.0152 bpf, ID = 3.958" ID = 3.958" '--' l-f El 1,·1D TT ~'O' LO"'G¡::r? I .-. .. ", J ", ,," ;J~... vi, 7" LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" 12471' -µ .. PERFORA TION SUMMARY REF LOG: LWD on 02/04/02 TIE-IN LOG: SCMT/GRlCCL ANGLEATTOPPERF: 18 deg @ 12860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 12766 - 12916 S 04/27/05 2-7/8" 6 12860 - 12910 0 05/06/05 PBTD I 12931' I 4-1/2" LNR, 12.6#, 13CR-80 VAM-ACE, 13018' I .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 02/13/02 EMF FINAL COMPLETION WELL: NS14 02/25/02 EMF A DD PERF PERMIT No: '2011180 12/20/02 EMF UPDA TED KB INFO API No: 50-029-23026-00 05/06/05 RMHlTLH PERF SQZ & PERF 11/06/05 BJM NEW FORMAT BP Exploration (Alaska) 1 " 4.5" X 4.5" XN 4,5" BRIDGE PLUG @ 10214'MD 7" LINER TOP@ 10741' 7" PACKER, 13 Cr 4.5" LINER TOP Top of NORTHSTAR NS-14 100 50 I ) Cum 00 Prod ) Ratio (fikf/bb! ) (%) 10 5 ~ ~ 0.5 " " 0.1 0.05 0.01 2002 03 Date -" 04 05 ) ) Date: 08-01-2005 ~ Transmittal Number: #10202718306 ~()I-II'ð BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com SW Name Date Contractor NS14 3-29-2005 SCH NS14 3-29-2005 SCH NS14 3-29-2005 SCH Top Log Run Depth Bottom Depth Log Type 1 12914 12928 RST-SIGMA/POROSITY STATIC ()) 'IV¡ PRESSUREITEMPERATURE ...., ;., I" 12500 12925 PRODUCTION PROFILE P RESSITEM PIG RAD/SPI N/G HOST ICAL IPERS 12500 12888 PERFORATION RECORD WITH GAMMA RAY 2.88" HSD 6SPF 60 DEG PHASED PJ 2906 f'·/)¡I-J! ' I\'ï· '. (.'.! . " t, i . ¡ ì/ .' /ft. -. (~ ¿~. Plea~e Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center ~C:ANNED SEP 0 8 2005 Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) û I-I (Y F.'/ -t ) STATE OF ALASKA ) RE(~E:'\JrE' ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 REPORT OF SUNDRY WELL OPERATI<},~~,: i.. ~2005.. . 1. Operations Performed: 8 011 & GKiJ~ Cm¡~. ~..omniÎS,tw:m Abandon 0 Repair Well 0 PluQ Perforations[K] Stimulate 00 j~r~[~~~~þJ Alter CasingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate [K] Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 00 ExploratoryD 5. Permit to Drill Number: 201-1180 6. API Number 50-029-23026-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.51 8. Property Designation: ADl-312799 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: NS14 10. Field/Pool(s): Northstar Field / Northstar Oil Pool Total Depth measured 13020 feet true vertical 11237.8 feet Effective Depth measured 12931 feet true vertical 11152.8 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse LINER 1730 7" 26# l-80 10741 - 12471 9147.9 - 10715.1 7240 5410 Liner 699 4-1/2" 12.6# 13Cr80 12319 - 13018 10568.6 - 11235.9 8430 7500 Production 10865 9-5/8" 47# l-80 43 - 10908 43.0 - 9291.5 6870 4760 SURFACE 3252 13-3/8" 68# l-80 44 - 3296 44.0 - 3207.6 4930 2270 Perforation depth: Measured depth: 12860 - 12870, 12870 - 12886, 12886 - 12910 " '200¡::; SCj4,N~~EJ) JUN "!I 4 - J True vertical depth: 11085.17 -11094.67,11094.67 -11109.88,11109.88 -11132.74 Tubing ( size, grade, and measured depth): 5-1/2" 17# 13Cr80 4-1/2" 12.6# 13Cr80 @ 40 @ 10147 10147 12331 Packers & SSSV (type & measured depth): 7" Top Packer 4-1/2" Top Packer Baker S-3 Packer 5-1/2" HRQ SSV @ 10741 @ 12319 @ 12283 @ 1957 RBDMS BFl JUN 0 fj 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12766' -12916' Treatment descriptions including volumes used and final pressure: 25 Bbls 12% HCl, 43 Bbls Class G lARC Cement @ 3545 psig. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 11.6 16 0 3554 15.6 0 525 1810 13 Prior to well operation: Subsequent to operation: Oil-Bbl 1106 2910 14. Attachments: ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil]] GasD Development ŒJ Service 0 Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 305-040 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature }J~ ('¡¡:;;t{ ~ /-orm , U-4U4 Hevlsed' 4/:¿UU4 Title In n" ,~ \ r; \ N A Lphone t\... r\ C Production Technical Assistant 564-4657 Date 6/3/05 ) NS14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/25/05 CTU #5, CMT SQZ.; CONTINUED FROM WSR 4/24/05... RIH W/ 2.5" BDN. FOLLOW 2% KCL WITH 100 BBLS DIESEL DOWN WELL. TAG TD AND CORRECT DEPTH TO 129281 ELMD. PUH 101, FLAG PIPE. JET 25 BBLS OF 12% HCL ACROSS PERFS AND OVERFLUSH W/2% KCL. PUMP 3 BBLS OF 15.8 PPG CLASS IG1 LARC, 5 BBLS OF 14 PPG SQUEEZECRETE, FOLLOWED BY 16.5 BBLS OF 15.8 PPG CLASS IG1 LARC (FIELD API FLUID LOSS @ 50). LAY CEMENT ACROSS PERFS, ACHIEVE 1000 PSI BUMP FOR INITIAL SQUEEZE PRESSURE. LAY REMAINING CEMENT IN WELL AND PULL TO SAFE. RAMPED WHP UP IN 500 PSI INCREMENTS. COULD NOT HOLD FINAL TARGET WHP OF 3500 PSIG. WELL SLOWLY BUT REPEATEDLY BLED DOWN. COULD NOT ACHIEVE BREAKDOWN OF PERFS, LIMITED TO 3750 PSI WHP. CONTINUED TO HAVE SLOW LEAK-OFF RATE. RBIH CONTAMINATING CEMENT TO TD MAINTAINING 1000 PSIG WHP AT CHOKE. LAY IN 5 BBLS OF TEA ACROSS PERFS. CHASE CONTAMINATED CEMENT TO SURFACE AT 60%, GOOD 1 FOR 1 RETURNS AT 1000 PSIG WHP. FREEZE PROTECT WELL TO 20001 WITH 60/40 METHANOL. SIWHP::: 520 PSIG. SECURE WELL. WAIT ON FLUIDS FOR RE- SQUEEZE. CONI' ON WSR 4/26/05 ... 04/26/05 CTU #5, CMT. SQZ.; CONTINUED FROM WSR 4-25-05... STAND BY FOR FLUIDS. PRESSURE TEST ALL SURFACE EQUIPMENT. SURFACE EQUIPMENT TESTED GOOD. WAIT ON DOWELL CEMENTERS. OPEN WELL, SIWHP::: 365 PSIG 04/27/05 CTU #5, CMT. SQZ.; CONI' FROM WSR 4/26/05 ... CONTINUE WITH CLEAN OUT. RIH JETTING CONTAMINANT BACK TO TD. LAYED IN 5 BBLS OF TEA ACROSS PERFS. POOH AT 50% JETTING/CHASING CONTAMINANT. FP WELL FROM 28001 TO SURFACE WITH 60/40 METHANOL. TRAP 1000 PSIG WHP. WELL SECURED AND TO REMAIN SHUT IN A MINIMUM OF 72 HRS BEFORE DRAWDOWN TEST AND PERFORATING. RD DS CTU #5. *** JOB COMPLETE *** 04/29/05 *** WELL SHUT IN ON ARRIVAL *** DRIFT W/ 27/8" DUMMY GUN & SAMPLE BAILER TO 12, 8531 SLM, RUN XN LOCATOR, LOC XN NIPPLE @ 12,2731 SLM, ( XN ELM 12,3301 REF LOG, PRIMARY DEPTH CONTROL LOG 2/17/02 ) 05/05/05 PERFORATED WITH 2.88" HSD 6SPF 60 DEG PHASED PJ2906 CHARGES FROM 128701-129101. TAGGED TD AT 129121, CONFIRMED SHOOTING INTERVAL WITH TOWN ENGINEER. WHP ::: 0 PSO BEFORE SHOOTING AND 350 PSI AFTER SHOOT 05/06/05 FINSIHED PERFORATION JOB FROM PREVIOUS DAY. PERFORATED 128601-128701 WITH 2.88" HSD 6SPF 60 DEG PHASED PJ2906 CHARGES. USED GAMMA RAY FRO CORRELATION. FLUIDS PUMPED BBLS 142 60/40 Methanal 1273 2% KCL 100 Diesel 385 20/0 XS KCL 184 Biazan 25 12% HCL 43 Class G LARC Cement 5 Crete Cement Page 1 5 TEA 2162 TOTAL ) NS14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Page 2 ) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ') I 13 3/8" Stage Collar at +/-1638' MO 13 3/8", 68#/ft, L-80, BTC @ 3296.5' MO 5.5", 17#/ft, 13-Cr, Fox TUBING 10: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 10908' MD 4.5" X NIPPLE, @ 12261' MD 3.813" 10 4.5" X NIPPLE, @ 12307' MD 3.813" 10 4.5" XN NIPPLE, @ 12318' MD 3.725" 10 4.5" WLEG, @ 12330' MD 3.958" 10 7", 26#/ft L-80, BTC-M @ 12471' MO NS14 !B. ELEV = 55.51' I\.B-BF. ELEV = 39.61' BASE FLANGE ELEV = 15.9' 51/2" SSSV @ 1957' MD w/ HRQ SVLN nipple - 4.562" 10 ~ 5.5" GLM @ 4944' MD (4503' TVD) w/ 4.62" 10 ~ ~ ~ ) 51/2" x 41/2" XO @ 10147' MD ~ 7" LINER TOP @ 10741' MD H Jj- J ~ I 4.5" Rber Optic Transducer 3.958 "ID@12241.5' MD, 10502' TVD (Sensor ELM TVD = 10514? å M - 7" BAKER S-3 PACKER, 13 Cr @ ~ 12283' MD ~ 4.5" LINER TOP @ 12319' MO ~ .. ÆRFORA TION SUMMARY REF LOG: LWD (2/4/2002) [Tie-in Log:SCMT/GR/CCL] ANGLE AT TOP ÆRF: ?? @ 12860' SIZE SPF INTERVAL MD Opn/Sqz DA TE 2.88 6 12766 - 12916 S 04/27/05 2.88 6 12860 - 12910 0 05/06/05 PBTO @ 12931' MO TO @ 13018' MO DATE 01/03/02 02/13/02 02/25/02 12/20/02 05/06/05 REV BY JAS EMF EMF EMF RMH/TLH COMMENTS NS 14 PROPOSED DEPTH UPDATES A DDÆRF UPDA TED KB INFO ÆRF SQZ & ÆRF , ~ l 4.5",12.6#, 13Cr Vam Ace DA TE REV BY COMMENTS NORTHSTAR UNIT WELL: NS14 ÆRMIT No: ?? API No: 50-029-23026-00 SEe T N R E BP Exploration (Alaska) ) ) d,fJl- I/l rt¡:;\ ~~,. å··\ "-lJ f"? l ¡\~u ¡ f,.. . /. \ i' ¡ 1'---. i ,\ : i ! I ~ t I I? [ÙÙ li ,JM\~ ~¡ ~L ~ ....¡/" U U ~ w....-u r-¡::;-ì : 'F ¡ ~ ¡ i! If. ' ¡ l' ~" ' ~ , ~ :1 ! \' \\.~j [t li~!" n . f'i18t '.':,\\ ((fj nn ~/ßi '\'.. . I 1 ' I lAin, ~', ,rl, I. II,! ii] 'ff' ñJ~" ~i\' "",' " '\ ¡ ~ i ,', ~..,,",) l : \ ,', I , 1~ !Jlj L:=J ,. "...1 '~.::!J ' , \ ' , !r¡j / / 1 ;1 .l / / J FRANK H. MURKOW5KI, GOVERNOR A"tA~KA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: N orthstar # 14 Sundry Number: 305-080 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sin~CerelY ."'..'.~..-.. <." ~ ./" ..,', (/'); /'><.::':::< . YJr/~ .-' .<>~ Daniel T. Seamount, Jr. Commissioner DATED this 5- day of April, 2005 Encl. SCJ~NNE[) .~PR 1 4 Z005 bp ) ) ,\tAtl. ~~~ ~~. .--'- -.-. ..........~ ~...~ ·'.'·"1\- ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 1 ,2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS14 to do a Gas Shut-off Squeeze (Ivishak) ~/ BP Exploration Alaska, Inc. proposes to perform a gas shut-off squeeze in the NS 14 well. This well has experienced a steady increase in GOR. At its current r' GOR of 23,OOOSCF/STB, this well is shut-in most of the time due to facility gas / handling limitations. Production logging indicates a majority of the gas production is coming from the upper two-thirds of the perforations. The proposed procedure would isolate these perforations to reduce the GOR in this /' well so it can become a full-time producer again. The procedure includes the following major steps: · RU Coiled Tubing · Squeeze the perforations using cement · Clean out the well bore using coiled tubing · Reperforate the bottom 1/3 of the perforations · Return the well to production /" Sincerely, o/Y ~~. rh Michael J. F ., P.E. Senior Petro eum Engineer BPXA, ACT, Northstar fl R I (...... ~ 1\ '\ I l., ! "\' r -d j \1 L\ I -' ,.. \. "'......."" ~ ~ \ J ~ ~..~....... Cfl4./~./(/6 \¡J~A-- +1 4/ too$' ) .) brS ~~~ STATE OF ALASKA .VED ALASKA Oil AND GAS CONSERVATION COMMISSION R,ECEI ' APPLICATION FOR SUNDRY APPROVALÞ,?R ~-l 2005 20 AAC 25.280 CIS on A'8Sk~ L¡< ~ 61s ConI. 0_' i Operation Shutdown D /' PerforateD WAAå@!lGge Other D Plug Perforations ŒI StimulateD Time Extension D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. / 201-1180 /' Development Œ] Exploratory D StratigraphicD Service D 9. Well Name and Numg,er: NS14 ( 10. Field/Pool(s): Northstar Field 1 Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12931 11103.5 MD TVD 1. Type of Request: D D Abandon Suspend Alter Casing D Repai r Well D Change Approved Program D Pull Tubing D 2. Operator Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.51 DF 8. Property Designation: ADL-312799 11. Preser Total Depth MD (ft): 13020 Casing Total Depth TVD (ft): 11244.2 Length Size LINER Liner Production 1730 699 10865 3252 top 7" 26# L-80 ____) 10741 4-112" 12.6# 1é~ 12319 9-5/8" 47# L-80 43 13-3/8" 68# L-80 44 Perforation Depth TVD (ft): 11002 - 11030.6 11031 - 11059.1 11059 - 11087.5 11088 - 11116.1 11116 - 11144.7 bottom top 12471 13018 10908 3296 Tubing Size: 5-1/2 " 4-1/2 " SURFACE Perforation Depth ~D (ft): 12766 - 12796 12796 - 12826 12826 - 12856 12856 - 12886 12886 - 12916 / Packers and SSSV Type: 7" Top Packer 4-112" Top Packer Baker 5-3 Pa9ker 5-1/2" HRQ/S5Y; 12. Attachments: \_~ Description Summary of Proposal ŒJ Detailed Operations Proç¡ram 0 BOP Sketch 0 14. Estimated Date for April 15, 2005 / Commencing Operation: 6. API Number / 50-029-23026-00-00 Plugs (md): Junk (md): None None Burst Collapse bottom ~ 10721.0 1 ~o 493& \ £tjlt:> ,~ 11242.3 B4)o~ !'1 ç" 04T6ß- 9295.5 (,&"7o~ 41 S-o.S4H·rr 3207.6 ~d"1~· .~ TU~in ß.¡:ade:--" Tubing MD (ft): 2..~, 13Cr80 / 40 - 10147 ~ 10147 12331 9151.8 10574.5 43.0 44.0 17 # 12.6 # Packers and SSSV MD (ft): 13. Well Class after proposed work: 10741 12319 12283 1957 /' Exploratory 0 DevelopmentŒ] 15. Well Status after proposed work: Oil ŒJ / Gas D Plugged D 16. Verbal Approval: Date: WAG D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Michael Francis ~<Þv-~J-11 ~,,~ Jrfe C "" . Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP TestD Mechanciallntegrity Test D Other: Approved by W' RBDMS BFL APR 0 6~ 2005\ ~ ~:, ~ ~ i\ L_, Form 10-403 Revised 11/2004 GINJD Contact Title Phone Service 0 Abandoned D WINJD WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Petroleum Engineer 564-4240 4/1/05 Sundry Number: 30Ç~9'¿; Location Clearance D BY ORDER OF THE COMMISSION Date: 4/5/ S SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) NS14 13 3/8" Stage Collar at +1-1638' MD 133/8", 68#/ft, L-80, BTC @ 3296.5' MD ~ 5.5", 17#/ft, 13-Cr, Fox TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace ~ TUBING 10: 3.958" CAPACITY: 0.01522 BBL/FT , H 9-5/8" 47# ..- L-80 BTM-C @ 10908' MD 4.5" X NIPPLE, @ 12261' MD 3.813" 10 4.5" X NIPPLE, @ 12307' MD 3.813" 10 4.5" XN NIPPLE, @ 12318' MD 3.725" 10 4.5" WLEG, @ 12330' MD 3.958" ID B , E- 7", 26#/ft L-80, BTC-M @ 12471' MD ~ J=m=ŒA n::N s...rvM\Rý ÆFLffi LV\D(2/4I3XJ2) [fie-in l..q¡:s:JvII7ffi'm.,¡ AN3EATTCPFm=: !\tie: ~er to R'cd..K::tia'1 œ fer hsterica p::rl data \itia F€rf - Ga'ge: 29)3 FONer j:ì, t-M<; Rreraticn: Zi'; H)e: .:£'; Fhase: ro œg SIZE 31= Nlffi/AUvÐ Nlffi/AL lVD Q:rl&¡z D\lE 2.88 6 12765' -12916 11002' - 11148 Q:n 2/1a'2XJ2 PBTD @ 12931' MD TO @ 13018' MD ~ DATE 1/3/02 2/13/02 2/25/02 12/20/02 COMMENTS ~S14 Proposed Depth Updates Add Perf Updated KB Information REV. BY JAS EMF EMF EMF ~ /' -')B. ELEV = 55.51' "ß-BF. ELEV = 39.61' BASE FLANGE ELEV = 15.9' 5 1/2" SSSV @ 1957' MD wi HRQ (1956' TVD) ~ SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4210' TVD (4567' MD) 5.5" GLM @ 4944' MD (4503' TVD) wi 4.62" 10 ~ ~ ) /"··'···-··ì 5 1/2" x 41/~@ 10147' MD ~ 7" LINER TOP @ 10741' MD I. 4.5" Fiber Optic Transducer V' 3.958" 10 @ 12241.5' MD, I 10502' TVD (Sensor ELM TVD = 10514') -;;- - 7" BAKER S-3 PACKER,13 Cr@ ,,- 12283' MD E 4.5" LINER TOP @ 12319' MD ... ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WFI I : NS14 API NO: 50-029-23026-00 BP Exploration (Alaska) ~( .((L. . ~ ~'.~ffi' 'ß~ &l? Œ~." " , ill," ~\ I I, r I 1 . ~, "- ¡ ¡ I I' ,~I \ i ,,') ¡,..¡ " ,\ tJ ¡ ) riU¡)1 [1; fÆl' \ n fÆl' j (fù~I" .," ! ¡ ill if I d 1 r I Ü, ,'\', \~ [, I l.::::J " ' (lJ i ) :!tJl- Ir<¡ l& fro 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR A"fA~KA OILA5D GAS CONSERVATION COltDlISSION Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS14 Sundry Number: 305-040 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd d following the date of this letter, or the next working day if the 23rd day falls on a olidEY or weekend. A person may not appeal a Commission decision to Su erior 0 . nless rehearing has been requested. . DATED this 1Í day of February, 2005 Encl. SC,f.\NhJEC MAR 0 2 2D05 bp ) ') .,. ,\"'.',.1. ~~~ ~~. ~..- -..-. ......~ ~........ .'j'~i\. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 16, 2005 FEe 1 8 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS14 to do a Gas Shut-off Squeeze (Ivishak) BP Exploration Alaska, Inc. proposes to perform a gas shut-off squeeze in the NS 14 well. This well has experienced a steady increase in GOR. At its current /" GaR of 13,500 SCF/STB, this well is shut-in much of the time due to facility gas handling limitations. Production logging in offset wells indicates a majority of the gas production is coming from the upper two-thirds of the perforations. The proposed procedure would isolate these perforations to reduce the GaR in this well so it can become a full-time producer again. The procedure includes the following major steps: . RU Coiled Tubing . Isolate the lower one third of the perforations with a sand plug . Squeeze the upper two thirds of the perforations using gel and cement . Clean out the well bore using coiled tubing . Retu rn the well to production // Sincerely, ::1~r~~ Senior Petroleum Engineer BPXA, ACT, Northstar n.' F) I G-¡ Ï: ~\~ '-.' \\(tl~ ¡~. . ) WGl\ ,-/22.!UJO$ STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend D Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: Operation Shutdown D Plug Perforations Œ] Perforate New Pool D PerforateD WaiverD StimulateD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 201-1180 / bottom top bottom 12471 9151.8 10721.0 4930 2270 13018 10574.5 11242.3 6870 4760 10908 43.0 9295.5 7240 5410 3296 44.0 3207.6 8430 7500 Tubing Size: Tubing Grade: Tubing MD (ft): 5-1/2 " 17 # 13Cr80 40 10147 4-1/2 " 12.6 # 13Cr80 10147 12331 \;J4tr- Exploratory D Development~ Servicof!) 15. Well Statu~r proposed work: Oil ~ G:RA- Plugged D AbandonedD WAG D GINJD WI~ WDSPLD Prepared by Garry Catron 564-4657. Michael Francis 4. Current Well Class: BP Exploration (Alaska), Inc. /~' Development ŒJ Exploratory D StratigraphicD Service D 9. Well Name and Numbftr: NS14 ,/ 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12931 11103.5 MD TVD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.51 DF 8. Property Designation: ADL-312799 11. Present Total Depth MD (ft): 13020 Casing Total Depth TVD (ft): 11244.2 Length Size LINER Liner Production SURFACE Perforation Depth MD (ft): 12766 - 12796 12796 - 12826 12826 - 12856 12856 - 12886 12886 - 12916 Packers and SSSV Type: 7" Top Packer 4-112" Top Packer Baker S-3 Packer 5-112" HRQ SSV 12. Attachments: 1730 699 10865 3252 top 10741 12319 43 44 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 11002.1 - 11030.6 11030.62 - 11059.1 11059.07 - 11087.5 11087.53 - 11116.1 11116.06 - 11144.7 Packers and SSSV MD (ft): Description Summary of Proposal ŒI Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 13. Well Class after proposed work: April 1, 2005 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Conditions of approval: Michael Francis ~~Il f) ~:.o) f,é. Commission Use Only Notify Commission so that a representative may witness Title Phone Petroleum Engineer 564-4240 2/8/05 BOP TestD 1::'~:l[¡ 1J ~; 2005 iI ,,,,. ".) ..II. Iii ! 0\ s ~1 ~ ") 'S " . I' ~ '1"1 ',"', ~~, " ~,'~)I'i''r:.¡'," :"'I~~! ~t-~O( ,,1. ': t,:,~: ~: b "~('" \.'., ,:/jl.r !! I:. ~I,¡ '~ ~ II '.'j: 'ì',;V ~ ~ Other 0 6. API Number /' 50-029-23026-00-00 Plugs (md): Junk (md): None None Burst Collapse 10741 12319 12283 1957 Sundry Number: .":30 ~ - /J(j{) Mechanciallntegrity Test D Location Clearance D RBDMS 8Fl MAR 0 ~ 7005 Other: lo~4,o4. BY ORDER OF THE COMMISSION Date: rzJþ ( '~ () ~-) \ ~~\ I, r," ~ ~-~~ f -- ij l\ 1\ . 1\¡~~~ß~'~ú' Form 10-403 Revised 11/2004 SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/S" 5ksi WELLHEAD: ABB-VGI 13-5/S" Multibowl 5ksi ) NS14 .' 13 3/S" Stage Collar at +/-163S' MD 13 3/S", 6 S#/ft , L-SO, BTC @ 3296.5' MD ..4 5.5", 17#/ft, 13-Cr, Fox TUBING ID: 4.S92" CAPACITY: 0.0232 BBUFT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.95S" CAPACITY: 0.01522 BBUFT ~ 9-5/8" 47# L-80 BTM-C @ 10908' MD ¿. 4.5" X NIPPLE, @ 12261' MD 3.S13" ID 4.5" X NIPPLE, @ 12307' MD 3.S13" ID 4.5" XN NIPPLE, @ 1231S' MD 3.725" ID 4.5" WLEG, @ 12330' MD 3.95S" ID - J B 7", 26#/ft L-SO, BTC-M @ 12471' MD ~ Rffi:PAID\I s..MvAAY ÆFLœ LV\O(2I4I2XJ2) [fie-in Lq;¡:rov1I7CRcn] AN3..EATlCPFBT: N::te: RJfer to A'o1K:tia1 œfCf tistaic:a ¡:øf data htä Fèrf - Qage: 2!:Œ FONer.1:i, t-M<; Rn1raIicn: 'I]"; H:E .:E'; Fhase: 00 deg SIZE s:F NI1ßIAL M) NJm/AL 1VD Q:o'S:¡z rnlE 2.æ 6 12763' -12916 11002' -11148 Q:n 2I19'2lI2 PBTD @ 12931' MD TD @ 1301S' MD i DATE 1/3/02 2/13/02 2/25/02 12/20/02 REV. BY JAS EMF EMF EMF COMMENTS '"NS14l-'roposed Depth Updates Add Perf Updated KB Information .. ')<B. ELEV = 55.51' r<B-BF. ELEV = 39.61' BASE FLANGE ELEV = 15.9' 51/2" SSSV @ 1957' MD w/ HRQ (1956' TVD) SVLN nipple - 4.562" ID 6.SPPG DIESEL FREEZE PROTECTION AT +/- 4210' TVD (4567' MD) 5.5" GLM @ 4944' MD (4503' TVD) w/ 4.62" ID ~ .. j 51/2" x 41/2" XO @ 10147' MD ~ - 7" LINER TOP @ 10741' MD 4.5" Fiber Optic Transducer 3.95S" ID @ 12241.5' MD, 10502' TVD (Sensor ELM TVD = 10514') -;;- - 7" BAKER S-3 PACKER, 13 Cr @ ~- 12283' MD E 4.5" LINER TOP @ 12319' MD V I .... ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WF~ I : N~14 API NO: 50-0?9-?3026-00 BP ExplOrátion (Alaska) Permit to Drill 2011180 11 r-1ffVLrJJJ 6 ~( DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Well Name/No. NORTHSTAR UNIT NS-14 TVD 11244 r' Completion Date 2/17/2002 r- Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L ~ ~ J.., ~-t ~ MD 13020 --- API No. 50-029-23026-00-00 UIC N -- -------- --------- REQUIRED INFORMATION Mud Log No Samples No --------- -Nt7-Y~ Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Type ~ED ./lED I I ! ..JÆD I Keg I ..!Æ- 0 g I Mog I I ~D JtD Electr Digital Dataset Med/Frmt Number Name C ......10749 C v1 0680 C /10749 C C /10749 vf' 0679 Log Log Run Scale Media No 1 1 1 tV I> 2 8M 1 t4à 5 8M 1 Mb 2 BM 1 1 1 (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 305 13038 3151 6192 OH/ CH Received Open 3/20/2002 Open 3/27/2002 ,"""'~- Comments LDWG Formatted open hole Edit LDWG Formatted open hole Edit ------- j Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Ð Chips Received? Y I ÞI - Interval Start Stop Sent Received 305 13038 Open 3/20/2002 201 13020 Open 12/5/2002 201 13020 Open 12/5/2002 201 13020 Open 12/5/2002 305 13038 Open 3/20/2002 3151 6192 Open 3/27/2002 Sample Set Number Comments ÐN futN Analysis Received? ~ Daily History Received? Formation Tops --- -- - -- - -- -- -- - - -- Comments: 1.1"...;'" It 6 A M .¡ 13~¿4 W..U~. .)1""'"1 I'""- Permit to Drill 2011180 MD 13020 TVD 11244 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Well Name/No. NORTHSTAR UNIT NS-14 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23026-00-00 Completion Date 2/17/2002 Completion Status 1-01L Current Status 1-01L UIC N {h; =T~-=-~:=-==---=-~------ J::1- t1 ~ ~ Date: .--- ~. t STATE OF ALASKA ( ALAS1,J-\ OIL AND GAS CONSERVATION COM~,,_.310N REPORT OF SUNDRY WELL OPERATIONS 1. Ooerations Periormed: Abandon 0 Alter CasingD Change Approved Program D SuspendC] Repair WellD Pull TubingD Operation ShutdownD Plug PeriorationsD Periorate New PoolO PeriorateD VarianceD Stimulate~ Time ExtensionD Re-enter Suspended WellD Annular Disposal D OtherD 4. Current Well Class: Development Œ ExploratoryD 5. Permit to Drill Number: 201-1180 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.o. Box 196612 Anchorage, Ak 99519-6612 StratigraphicO ServiceD 9. Well Name and Number: NS-14 10. Field/Pool(s): Northstar 6. API Number 50-029-23026-00-00 7, KB Elevation (ft): 55.51 8. Property Designation: ADL-2799 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Suriace Intermediate Production Liner Perioration depth: / Northstar measured 13020 feet true vertical 11244 feet Plugs (measured) measured 12931 feet true vertical 11 048 feet Junk (measured) Length Size Burst Collapse TVD MD 3253 13-3/8" 68# L-80 44 - 3296 44 - 3207.6 4930 2270 10865 9-5/8" 47# L-80 43 - 10908 43 - 9295.5 6870 4760 699 4-1/2" 12.6# 13Cr80 12319 - 13018 10574.5 -11242.3 8430 7500 1730 7" 26# L-80 10741 - 12471 9151.8 -10721.0 7240 5410 Measured depth: 1276ß~_: 1279q~J279a' -12826', 12826' -12856', 12856' - 12886', 12886' - 12916' True vertical depth: 11002.1' -11030.62' ,11030.62' -11059.07' , 1.'LQ5Jt.Q7'--J1087.53' , 11087.53' -11116.06' 11116.06' -11144.65' 4-1/211 12.6# 13Cr80 @ 10147.3' -12331.211 MD 5-1/211 17# 13Cr80 @ 40' - 10147.3' MD 4-1/211 Liner Top Packer @ 123191 MD/711 Liner Top Pack~r,@ 10741' MD Baker S-3 Packer @ 12282.861 MD /5-1/211 HAQ SSV @ 1957.23i Nib'::" ': ' "I "',, "._(""""., Tubing: ( size, grade, and measured depth) Packers & SSSV (type & measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: 13 (See Attachment) :'" ~'i!I '" .,'~ "'" '" .. ~ r " Or' Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl I Casing Pressure 5,500 60,000 60 5,500 60,000 I 60 Tubing:'p'rêssure¡, ." 2600 2600 15. Well Class after proposed work: ExploratoryD Development]] Service D 16. Well Status after proposed work: Operational Shutdown D OilŒ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657, Sundry Number or NIA if C.O. Exempt: Copies of Logs and Surveys run - Daily Report of Well Operations - ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael J. Francis, P.E. Printed Name Michael J. Francis Signature Title Senior Petroleum Engineer "I Phone 564-4240 Date 9/26/03 Form 10-404 Revised 4/2003 nQ'f'-,'~,' ^ r R8DØ~ Øf- b CLoP' U ,! ~, ~ t} LÜ\.hl ( (' NS-14 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/21/03 Acid treatment, Well shut in with 3600 psi. Pump pickle per procedure, 4 bbls meth, 18 bbls 12% DAD Acid, 150 bbls SW, 100 bbls Diesel, flowback pickle to production. 08/22/03 Continue with main DAD Acid treatment per procedure, 2 bbls meth, 36 bbls 12% DAD Acid, 273 bbls SW, shut down for 30 min soak, 206 bbls SW, 100 bbls Diesel, leave well shut-in for 4 hours. Turn over to production. FLUIDS PUMPED BBLS 6 Methonal 54 12% DAD Acid 629 Sea Water 200 Diesel 889 TOTAL Page 1 bp .¡i' i .,' ~. .,. ,~t.'ll. ........ ~ ~....- ~..- ~..'" *~~ ~~. .'1'.'1\- ". BP Exploration (Alaska) lnG, 900 East Benson Boulevard P, 0, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 7, 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS14 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS14 well. This well has exhibited a high rate of decline and analysis of formation water indicates the formation of CaCO3 scale is likely. Additionally, CaCO3 scale was recovered from the offset NS 13 wellbore using slickline. The procedure includes the following major steps: . Pickle the tubing . Bullhead HCI based acid treatment (which includes scale inhibitor) . Flowback Sincerely, ~~ 11 ~y Michael J, Fra~s, P,E. Senior Petroleum Engineer BPXA, ACT, Northstar .' fdJ ("' 1 ¡- ,") n 0') H~, ] l!. ¿¡¡ /U"J n ,. ,', " :;" ORIGINAL w&Æ-. t Ii 'ß( z-oo3 ~~Iífp; (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Alter Casino 0 Chanqe Approved Proqram 0 2. Operator Name: Suspend 0 RepairWell 0 Pull Tubinq 0 Operation Shutdown D PerforateD VarianceD Pluq Perforations 0 StimulatelX] Time ExtensionO Perforate New Pool 0 Re-enter Suspended WellO BP Exploration (Alaska), Inc. P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): RKB 55.51 8. Property Designation: ADL-312799 3. Address: 11. Total Depth MD (ft): 13020 Casing 4. Current Well Class: Development ~ Exploratory D StratigraphicD ServiceD 9. Well Name and Number: NS14 / 10. Field/Pool(s): Annuar Disposal 0 OtherD 5. Permit to Drill N~er: 201-1180 6. API Number ~ 50-029-23026-00-00 Northstar I Northstar PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11244.19 12931 11047.95 Length I Size I MD I TVD Conductor Surface 3252 13-3/8" 68# L-80 Intermediate 10865 9-5/8" 47# L-80 Liner 1730 7" 26# L-80 Production Liner 699 4-1/2" 12.6# L-80 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12766' -12916' 11002.1' -11144.7' Packers and SSSV Type: 7." Liner Top Packer /7" Baker S-3 Packer 4-1/2" Liner Top Packer /5-112" WRDP-2 SSV 12. Attachments: Description Summary of Proposal D Detailed Operations Program Œ: BOP Sketch 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 8/20/2003 / Date: top bottom !top bottom 44 - 3296 44 - 3207.6 43 - 10908 43 - 9295.5 10741 - 12471 9151.8 -10721.0 12319 - 13018 10574.5 -11242.3 Plugs (measured): IJunk (measured): Burst 5020 6870 7240 8130 Tubing Size: 5-1/2" 4-1/2" Tubing Grade: 13Cr80 13Cr80 Packers and SSSV MD (ft): 10741/12283/12319/1957 Co lIapse 2270 4760 5410 7500 Tubing MD (ft): 40 - 10146 10146 -12331 13. Well Class after proposed work: Exploratory D Development IK] 15. Well Status after proposed work: Oil[!] GasD PluggedD AbandonedD WAGD GINJD ,WINJD WDSPLD Perpared by S. Copeland 564-4424 Printed Name 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Francis ServiceD Signature Michael Franci Title Production Engineer /y".'< ' ' Phone 564-4240 Date 8/14/03 Commission Use Only Plug Integrity D BOP TestD Conditions of approval: Notify Commission so that a representative may witness Location ClearanceD Other: RBDMS BFl Iw-4ot.j Subsequent Form Required: AUG 1 R Înn~ , '" Sundry Number: 303 -2.3Cf w".".~,r"'~\ ~J"""" 1" i,¡"\1':',' ~i , , P""i,"',""", "II, li '~\ "':::,./1 ::: "'An I~. AUG 1 5 '2.003 t;ì, Approved by: ~ BY ORDER OF ~ ' COMMISIONER THE COMMISSION 00"'" , ~, . ^ t, a'~t-:~~ (..\ '-..' , , ,- Mechanciallntegrity TestD Form 10-403 Revised 2/2003 I', ,'":,.",:.,, Date: 8(/ <é3( 0:3 SUBMIT IN DUPLICATE bp ... ,\It.,~. ........~ ~.~ ~~- ~..- *.~ ~..... .~,.~~\~ ", ( f To: Gary McBride/John Smart - Well Operations Supervisor August 8, 2003 From: Mike Francis and Patty Hill - Northstar Subject: NS14 DAD Acid/51 Treatments AFE NSZ832018 Est. Cost: $60 M lOR: Est 500 BOPD Please perform an acid stimulation/SIT with 12% DAD acid on the NS14: Type lOR PR N DSWL AFE Job Description Priority Comments/Other 0 500 NS14 NSZ832018 Pump Acid and SIT NS 14 has suffered significant decline since start-up. The water chemistry indicates CaCO3 scale formation is likely and the presence of scale has been confirmed in the offset NS13 well. This treatment will dissolve the scale and place scale inhibitor in the formation. The treatments are being combined to simplify logistics. Procedure 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and diesel to flush both the pickle and the acid job. See attached Volumes table. 3. RU pumping equipment. 4. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface when the pickle is produced back. 5. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 6. PT Dowell surface lines to 5000 psi 7. Pump the following fluids to pickle the production tubing at 3 bpm, 3500 psi max pressure. a) 18 Bbls 12% DAD acid b) 150 Bbls seawater c) 100 Bbls diesel 8. Produce pickle back to test separator and well clean up tank. The pickle volume to flowback is 268 Bbls. l ~ 9. Pump the following treatment at maximum rate or 3500 psi max pressure. a) 36 bbls 12% DAD Acid b) 273 bbls Seawater (To displace acid to perts) c) Shut down for 30 minutes and allow acid to soak d) 206 bbls Seawater (for over flush and displacement) e) 100 bbls Diesel (for displacement and under-balance) 10. Shut well in for 4 hours to allow scale inhibitor to precipitate. 11. AD Schlumberger. 12. Flow back Procedure: For flow back, line up into the test separator and well cleanup tank. Produce clean-up volume of 615 bbls. After clean-up, divert back to the plant and get 2 6-hour tests. 13. Two days after well is cleaned up and stabilized, pertorm a closure test on the SSSV. Fluid descriptions: 12% DAD Acid to contain: 10% Nalco Scale Inhibitor + 0.60/0 A261 + 4 ppt A 179 + 8 ppt A 153 + 0.2% F103 + 20 ppt L58 + 1 .5% U74 + 10% Xylene Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Results will be available on location. Procedure Contacts: Mike Francis WK: 564-4240 HM: 644-0534 Cell: 529-8678 Patty Hill WK: 564-4346 HM: 248-6262 Cell: 350-0742 TREE: ABB-VGI 5 1/8" 5ksi ( WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi NS14 13 3/8" Stage Collar at +1-1638' MD 13 3/8", 68#/ft, L-80, BTC @ 3296.5' MD 5.5", 17#/ft, 13-Cr, Fox TUBING ID: 4.892" CAPACITY: 0.0232 BBLIFT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLIFT 9-5/8" 47# L-80 BTM-C @ 10908' MD 4.5" X NIPPLE, @ 12261' MD 3.813" ID 4.5" X NIPPLE, @ 12307' MD 3.813" ID 4.5" XN NIPPLE, @ 12318' MD 3.725" ID 4.5" WLEG, @ 12330' MD 3.958" ID 7", 26#/ft L-80, BTC-M @ 12471' MD FEm:PA 1K]\J SJv\'vf>R( RTLæ LV\O(2/4IaxJ2) [T¡e.inLc:g:rovI17CROl] AN3..EA TRY ~ N:te: ~ er to A"cxiICtial œ f cr listcrica perf data hitia Fèrf - O'a'ge: 2OC6 FbNer..kí, f-M<; Fènetratia1: Z1"; . - .--.. -. -- SIZE Sff NfERV AL M) NfERV AL 1VD [)l\lE 2.00 6 127æ - 12916 11cæ -11146 Q:n 2/19'axJ2 PBTD @ 12931' MD TD @ 13018' MD DATE - 1/3/02 2/13/02 2/25/02 12/20/02 REV. BY JAS EMF EMF EMF I ( 'KB. ELEV = 55.51' . KB-BF. ELEV = 39.61' BASE FLANGE ELEV = 15.9' 5 1/2" SSSV @ 1957' MD wi HRQ (1956' TVD) SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4210' TVD (4567' MD) 5.5" GLM @ 4944' MD (4503' TVD) wi 4.62" ID 51/2" x 41/2" XO @ 10147' MD 7" LINER TOP @ 10741' MD 4.5" Fiber Optic Transducer 3.958" ID @ 12241.5' MD, 10502' TVD (Sensor ELM TVD = 10514') - 7" BAKER S-3 PACKER, 13 Cr @ 12283' MD 4.5" LINER TOP @ 12319' MD 4.5",12.6#, 13CrVam Ace Northstar WELL: NS14 . BP Exploration (Alaska) ( lil bp ÏIfIi'.'......~.,.,.,.~.,....-d.. "'~'" ". .~. ",;c. '." ... .L .L. --. - "" Date: 12-5-2002 Transmittal Number:9?602 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Lo Run De th 100,101, 201 200,300, 400 100,101,1 201 200,300, 400,401 100,101,1 201 200,300, 400,401 100,200,1 201 300,400, 500 100,200,1 201 300,400, 500 100,200,1 0 300,400, 500 1,2,3,4 I 201 SW Name Date Contractor NS06 06-07-2002 SPERRY --I SUN C) ~ INS06 rt 1NSO6 l06-07 -200~SPERRY SUN MUD LOG-2"-TVD LOG 13396.9 406-03-20~1 SPERRY SUN 13396.9 MUD LOG - 2" - MD LOG { l05-15-2002 rsPERRY SUN NS07 MUD LOG - 5" - MD LOG 13529 v' ';:INS07 0 ( I ~NS07 .crt- ,NS08 - ~'INS08 ~NSO8 I ,NS12 C --¡NS12 - , ~INS12 'l) , NS14 05-15-20021 SPERRY SUN 13529 MUD LOG-2"-TVD LOG ( l05-15-2002SPERRY SUN 13529 MUD LOG - 2" - MD LOG v -+- 03-10-20021 SPERRY SUN 03-10-20021 SPERRY 11,2,3,4 I 201 SUN 03-10-20021 SPERRY 11,2,3,4 I 201 SUN 06-27-2002 SPERRY ./' SUN 06-27-2002 SPERRY v" I SUN / 106-27-2002 SPERRY v SUN " """""'," ,.","- .,"" ~ O¿-ÐÈh2002 {, ERRY .. .n... '.. ", \" " " 0' / SUN 02-09-2002 ,'Sp:ERRY 11,2,3,4 I 201 ::: .¡" . SUN \ - r, .,"" .."" ".", a NS14)(h}'~!I..; 02.:.09;.2003': ¡)$PEHRY "11,2,3,4 1 201 /.,,~:fj"'"""/ SUN NS15 04-13-2002 SPERRY 100,200,1 201 -::::r SUN 300,400, 8 v 500 I I NS15 04-13-2002 SPERRY 100,200,1 201 ~ / SUN 300,400, 12030 MUD LOG - 5" - MD LOG 12030 MUD LOG-2"-TVD LOG MUD LOG - 2" - MD LOG 12030 100,200,1 201 300 100,200,1 201 300 100,200,1 201 300 1,2,3,4 I 201 13135 MUD LOG - 5" - MD LOG 13135 MUDLOG-2"-TVDLOG 13135 MUD LOG - 2" - MD LOG 13020 MUD LOG - 5" - MD LOG ÒOlNS14 13020 MUD LOG - 2" - TVD LOG 13020 MUD LOG - 2" - MD LOG 15370 MUD LOG - 5" - MD LOG 15370 MUD LOG - 2"- TVD LOG Cã Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ......",,',.,,~h:f,"', '", YIl!?~:'\ '"'YW """ '.. .". :>. .......- .. i~ Date: ] 2-5-2002 Transmitta] Number:92602 " 500 NS15 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 2" - MD LOG SUN 300,400, /' 500 NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 5" - MD LOG Ì' ./ SUN ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG-2"-TVD LOG t ,/ SUN ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 2" - MD LOG ~ I SUN NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 5" - MD LOG SUN 200,201, 300,301, vi 400,401 -- NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUDLOG-2"-TVDLOG ~ SUN 200,201, -- . 300,301, rcr ¡/ 400,401 0 NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 2" - MD LOG ra SUN 200,201, ./ ,I 300,301, " 400,401 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 5" - MD LOG ~ v SUN 300 -.9 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUDLOG-2"-TVDLOG - ~ v SUN 300 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - MD LOG rei ( SUN 300 B PXA WELL D A T A TRANS MITT AL ~~g~n one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ayherd (DNA) Attn: Doug Choromanski (MMS) REC:EIVED DEe 0 5 2002 AI_I Oü & Gal Cona. ComIni8Iton ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ~\,j~' .""""."",.'¡::{""!iC\:",\" V~!" /'" ;"""",",',:"",':'!', ' , ~'!r' { I" f Date: 03-27-2002 Transmittal Number:92434 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ðo ........ '" -L Ç) '6 Top SW Name Date Contractor LoQ Run Depth Bottom Depth LoQ Type NS14 01-23-2002 SCH 1 0 9533 DIPOLE SHEAR SONIC TOOL; NS14 01-23-2002 SCH 1 0 9533 MICROLOG; NS14 01-23-2002 SCH 1 0 9533 HIGH RESOLUTION LA TERLOG; NS14 01-23-2002 SCH 1 0 9533 NEUTRON DENSITY; NS14 01-23-2002 SCH 1 0 9533 TRIPLE COMBO PRESENTATION; (MD) NS14 01-23-2002 SCH 1 0 9533 TRIPLE COMBO PRESENTATION; (TVD) NS14 02-17-2002 SCH 1 0 12930 GAMMA RAY; CASING COLLAR LOG; INS08 02-26-2002 SCH 1 0 9891 REPEAT FORMATION TESTER; NS14 02-26-2002 SCH 1 6192 3151 LDWG FORMAT (CD) aoa..~1 ~m~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED r." ,'~ D 2 -;r ')002 :r-Il \ ¡ L AI8Ika Oil & Gas Cons. Conunilalon Andr0rB98 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ~' ...............................,.;¡." ,:,1 ,C:,' ,",r. ': ," ~...::., ( (: Date: 03-20-2002 Transmittal Number:92430 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Loq Run Depth Bottom Depth Loq Tvpe NS14 01-09-2002 SCH 1-5 282 12972 VISION DENSITY NEUTRON TRUE VERTICAL DEPTH LOG; NS14 01-09-2002 SCH 1-5 282 12972 VISION DENSITY NEUTRON MEASURED DEPTH LOG; NS14 01-09-2002 SCH 1-5 282 12972 VISION RESISTIVITY; TRUE VERTICAL DEPTH LOG; ;NS14 01-09-2002 SCH 1-5 282 12972 VISION RESISTIVITY; \ MEASURED DEPTH LOG; I NS14 02-17 -2002 SCH 1 11 980 12930 CEMENT BOND LOG; NS14 01-06-2002 SPERRY - - - END OF WELL REPORT; NS14 02-05-2002 SCH 1 305 13038 LWD GR, DEN, NEUT (CD) ~ Q ?j ('//~, 6 )4 l/u--J "~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVED Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski t'1i~R 2 C 2002 Alaska Oil & Gas COns. Commislton Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface '"..-;"~w,.,"".:.-...:..:~.."~ -......;. ".~ 1179' NSL, 644' ~E~, SEC. 11, T13N, R13E, UM: ~ .":, - ,:..;, : lv?^ì~, At top of productive Interval : ,.. "-, æ 2958'NSL,502'WEL,SEC.10,T13N,R13E,UM'i_2_~",/,], :...(.¿,~: S,U, . '. " 110 WellN mber At total depth " '-::;'" :,1': ~ " ,,',' . u 2934' NSL, 640' WEL, SEC. 10, T13N, R13E, UM'_-_:tP - -' .~~ .,~ ":""..':;", I 5 EI t' . f t (' d' t KB DF t) 6 L D.' t. d S ' I -N 111. Field and Pool . eva Ion In ee In Ica e , , e c. . ease eslgna Ion an ena o. Northstar Unit RKB = 55.8' ADL 312799 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/9/2002 2/4/2002 2/17/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 13020 11244 FT 12931 11159 FT IBI Yes 0 No 22. Type Electric or Other Logs Run RES, AIT, DT / BHC, CNL, LDL, GR, CALIPER, SP, MRES, DEN, SONIC, GYRO, US IT 123. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 169# X-56 Surface 202' 20" Driven 13-3/8" 68# L-80 44' 3296' 16" 633 sx PF 'L'. 466 sx Class 'G' 9-5/8" 47# L-80 43' 10908' 12-1/4" 665 sx Econolite. 487 sx Class 'G' 7" 26# L-80 10741' 12471' 8-1/2" 281 sx Class 'G' 4-1/2" 12.6# 13Cr 12319' 13018' 6-1/8" 106 sx Class 'G' Classification of Service Well 7. Permit Number 201-118 8. API Number 50- 029-23026-00 9. Unit or Lease Name Northstar Unit NS14 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1957' MD 1545' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD 25. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2" , 17#, 13Cr-80 10147' 4-1/2", 12.6#, 13Cr-80 10147' - 12330' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL ~ AMOUNT & KIND OF MATERIAL USED Freeze Protected with 302 Bbls Diesel PACKER SET (MD) 12283' 12766'-12916' 11002'-11145' 27. Date First Production February 26, 2002 Date of Test IHours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR !Oll-BBl TEST PERIOD GAs-McF WATER-Bel CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, g~~ìqr,w~t~~;~~s~~!i':(t~ê~rê:;.,chips. ~" '\",-:r""""!'."""",I'I\':;':",:"lm~..:, Oil-Bel GAs-MCF WATER-BBl Oil GRAVITY-API (CORR) No core samples were taken. ~) 'i [':, ¡,: / ',':, '"',' !~!aska CM ¿~ iI::;¡:¡nS, ,GommisBion !\\'~Ö:')l~t::IJe ~, Form 10-407 Rev. 07-01-80 RIGI~\lAL qeOMSBFL MAR 2 I 2oBubmit In Duplicate - 2 b ~ ( 29. Geologic Markers Measured True Vertical Depth Depth 10243' 8732' 10472' 8924' 10845' 9241' 11430' 9757' 12460' 10710' 12471' 10721' 12563' 10809' 12653' 10895' Marker Name Top of Kuparuk Kuparuk 'C' Top of Miluveach Top of Kingak Top of Sag River Top of Shublik Top of Ivishak Top of Kavik f 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. , I' r',;; .[:. ,~~, ,/ I'; I .rll"""',"' 'n,:r ~'" (". "1"' .n ,h)\;'J~~h¡;:\\"¡,,~,:». ':"¡>('¡".:':,,," , (:.~ 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post-Rig Summary and a Leak of Integrity Test. 32. I ~erebY certify that the for~oin; is true, and correct to the best of my knowledge Signed Terrie Hubble -"'ÍÓ^" 'A ['1/, ~ ð Title Technical Assistant Date ~ NS14 Well Number 201-118 Permit No. / A roval No. INSTRUCTIONS Prepared By Name/Number: Sandra Stewman, 564-4750 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 ORIGli~AL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/7/2002 1/8/2002 1/9/2002 1/10/2002 ( ( Page 1 of 14 BP EXPLORATION Operations Summary Report NS14 NS14 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours I Activity I Code I NPT Phase 16:00 - 16:30 16:30 - 17:30 17:30 - 19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 00:00 00:00 - 03:00 03:00 - 05:00 05:00 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 14:30 14:30 -19:30 19:30 - 21 :30 21 :30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 10:00 10:00 - 11 :00 11 :00 - 11 :30 11 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 04:30 04:30 - 05:00 05:00 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 -16:00 16:00 - 23:30 23:30 - 00:00 0.50 MOB 1.00 MOB 1.50 MOB 1.00 MOB 1.50 MOB 2.50 MOB 3.00 MOB 2.00 MOB 3.00 MOB 2.00 RIGU 2.00 I RIGU 0.50 I RIGU 2.00 I RIGU 5.00 RIGU 2.00 RIGU 1.50 RIGU 1.00 DRILL 0.50 DRILL 2.00 DRILL 0.50 DRILL 1.001 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 2.50 DRILL 1.00 DRILL 0.50 1 DRILL 10.50 DRILL 0.50 1 DRILL 1.50 DRILL 4.50 DRILL 0.50 DRILL 9.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 7.50 DRILL 0.50 I DRILL P P P P P P P P P P P P P P P P P P P P P P P P P N P P P P P P P PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE SURF SURF SURF SURF SURF SURF SURF SURF SURF RREP I SURF SURF SURF SURF SURF SURF SURF SURF P P P P SURF SURF SURF SURF P SURF Start: 1/7/2002 Rig Release: 2/12/2002 Rig Number: Spud Date: 1/8/2002 End: 2/12/2002 Description of Operations PJSM - Skid rig floor back to center of rams for rig move. PJSM - Pull service lines from piperack. Prepare rig to skid. Warm up moving hydraulics system. PJSM on moving rig. Continue preparing rig for move. Moving rig to NS-14 from NS-9. Move rig over the well NS-14. Install stairs around the rig and get heater going in cellar Hook Up service lines to pipe rack and secure lines at NS-09. Clean up rig and berm all areas. Load BHA into pipe shed. Rig accepted @ 0800 hrs on 8th January for NS-14 PJSM with AIC and APC to clear area around NS-09 to facilitate tie in of NS-09. - Excellent SIMOPS co-operation. Pre spud Meeting with all Rig Crews and service personnel. Well Objectives and HSE expectations outlined. Continue to clean and berm rig, help with APOC and AIC with well tie in NS-09. NU 20" Riser. Continue to berm rig. Install mouse hole. Lay plywood in cellar. PU BHA #1 tools to floor and pipeshed. Thaw connections. PU SWS sheaves for GYRO to floor. MU BHA #1. Conduct D-7 Drill. Continue to make up 16" Spud assembly BHA # 1. Rig Up Gyro survey equipment with Schlumberger wireline. Conduct a D7 Surface drill and discuss responsibiltiesl job assignments. Cleanout 20" conductor and drill from 66 ft to 242 ft. Gyro 20" surface conductor. 1.18 degs Inclination @ 7 degs Azimuth. Drill ahead 16" hole from 242 ft to 333 ft @ 450 GPMI 400 psi. Gyro Survey POOH and pick up MWD and BHA #2. Replace bolts in Break out Head in Top Drive. Inspect Derrick Climber. Pick up jars and prepare to drill ahead. Drill ahead from 333' to 1198'. Survey. Pumping high-vis sweeps as needed. Gyro Deviation survey. Drill ahead from 1198' to 1305', pumping high vis sweeps every other stand. Drill ahead from 1305' to 1767'. Run Gyro. Drill ahead from 1767' to 2720'. Hold planning meeting on surface cement job. Circulate out sweep in preparation for Gyro. Final Gyro Survey @ 2,720 ft. PJSM to rig down wireline. Rig down wireline sheaves and gyro tool. Drill ahead from 2720' to Surface Hole TD of 3316'. At 2758' flowrate was increased to 900 gpm. SPP on 2200 pisg I off 2100 psig. WOB is 25k. Total ROP 145 fph wi 27% time steering and 73% time rotating. No Drag. No Losses.Solids Control equipment coped. Circulate sweep and condition hole, while rotating and - f-- Printed: 2/20/2002 11 :24:39 AM (' (' BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/10/2002 23:30 - 00:00 0.50 DRILL P SURF reciprocating.900 GPM. Sweep cleaned up hole. 1/11/2002 00:00 - 01 :30 1.50 DRILL P SURF Circulate and condition hole @ 900 GPMI 2175 psi. Move all 13.3/8" handling equipment to rigfloor while circulating. 01 :30 - 03:30 2.00 DRILL P SURF POOH five stands- f1owcheck. Pump dry job and POOH to BHA. Hole slick- average drag 5- 10 klbs. 03:30 - 06:00 2.50 DRILL P SURF Lay down MWD, motor and bit- bit in reasonable shape. 06:00 - 06:30 0.50 DRILL P SURF Clear rigf1oor 06:30 - 08:30 2.00 CASE P SURF RIU to run 13.3/8" casing. RIU FRanks tool, spider elevators. 08:30 - 09:00 0.50 CASE P SURF P/U Tubing Hanger and M/U to runing tool. Drift Port Collar. 09:00 - 09:30 0.50 CASE P SURF PJSM for running 13.3/8" casing 09:30 - 10:30 1.00 CASE P SURF P/U 13.3/8" shoetrack and check floats- good. 10:30 -16:00 5.50 CASE P SURF Run 81 joints of 13.3/8" , L-80, BTC, 68 Ib/ft casing. Hole taking some weight @ 3,145'- work through. 16:00 - 16:30 0.50 CASE P SURF M/U Casing Hanger and Land 13.3/8" with shoe @ 3,296 ft @ 1620 hrs. 16:30 - 18:00 1.50 CASE P SURF RID Franks tool and RIU cement head and lines. 18:00 - 20:00 2.00 CEMT P SURF Stage up Pumps to 11 BPMI 400 psi. Attempt to reciprocate- some overpulls. Land casing. Hold PJSM while circulating. 20:00 - 23:30 3.50 CEMT P SURF Cementers PT to 3500 psig wi SW. Come on line wi 10.5 ppg Alpha Spacer. Pump 89 bbls Alpha Spacer(red dye added to spacer), drop btm plug and switch to lead cement. Pumped 100 bbls of lead cement (10.7 ppg) with 50 psig WHP @ 6.0 bpm and 24% flow - full returns. Pumped 485 bbls lead cmt, switch to 96 bbls, 15.8 ppg, tail cement. Drop top plug and kick out wi 24 bbls water. Switch to rig pumps and displace cement @ 100 spm. At 2800 stks, lead cmt to surface. At 4650 strokes, bump plugs to 3000 psig. Bleed off and check floats- Ok. Prep to NID riser. 186 bbls of excess cement. 23:30 - 00:00 0.50 CEMT P SURF Rig down CMT head. Drain riser. 1/12/2002 00:00 - 01 :00 1.00 CEMT P SURF Flush riser and RID Cement Head and lines. 01:00 - 01:30 0.50 CEMT P SURF Lay down Vetco Landing Joint 01 :30 - 02:30 1.00 CASE P SURF Clear rigfloor of all casing handlingl cementing equipment. 02:30 - 04:00 1.50 CASE P SURF Change out bails on Top drive. 04:00 - 06:00 2.00 CASE P SURF Prepare to Nipple down riser and Prepare cellar while resolving leak on Rotary Table Motor. Previous fix had not worked. 06:00 - 08:00 2.00 CASE P SURF Nipple down Riser sections. 08:00 - 09:00 1.00 WHSUR P SURF Install Vetco Multi bowl wellhead and test to 5000 psi. Take RKB measurements. 09:00 - 10:00 1.00 BOPSUF P SURF Nipple up Single Gate and Mud Cross. 10:00 - 13:00 3.00 BOPSUF P SURF Install BOPE and connect Koomey Hoses. SIMOPS: Ensure NS-13 shut in prior to heavey lift. Total time well out of Production = 3 hours. 13:00 - 17:00 4.00 BOPSUF P SURF Tighten up spool and double gate. Tighten turn buckles. NU drilling nipple and install mouse hole. 17:00 - 00:00 7.00 BOPSUF P SURF Test BOPE stack to 300/4500 psig. AOGCC Representative Jeff Jones out to witness. Test in gas alarms in cellar and in shaker room. AOGCC left the island at midnight- out of hours escort arranged with 2 hours notice. 1/13/2002 00:00 - 00:30 0.50 BOPSUF P SURF Continue testing BOPE to 300/4500 psi. No test on shear rams. 00:30 - 05:30 5.00 BOPSUF N RREP SURF Open shear ram doors and inspect Rams. Some marks on Printed: 2/20/2002 11 :24:39 AM ( (' BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS 14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/13/2002 00:30 - 05:30 5.00 BOPSUR N RREP SURF Wear Plate. ( No spare rubber seals on Location for Hydril Shears). 05:30 - 09:00 3.50 BOPSUR N RREP SURF Replace wear plate, close doors and attempt to test- no go. 09:00 - 12:00 3.00 BOPSUR N RREP SURF Changeout Shear Rams to Blind Rams and test same to 4500 psi- good test. 12:00 - 14:00 2.00 BOPSUR P SURF RID BOP test equipment and install wear ring. 14:00 - 16:30 2.50 DRILL P SURF M/U BHA # 3- 12.1/4" Milled tooth assembly. Set Motor and surface test MWDI Motor- OK. 16:30 -17:30 1.00 DRILL P SURF TIH wi BHA #3 to cement stringer @ 3160'. 17:30 -19:00 1.50 DRILL P SURF Wash and ream from 3160' to 3213'. See some rubber on shakers. MWin = MW out = 8.8 ppg. 19:00 -19:30 0.50 DRILL P SURF PT casing to 3520 psig for 30 mins. Good. Hold PJSM for mud swop and and have D2-Drill while waiting holding PT. 19:30 - 22:00 2.50 DRILL P SURF Drill shoe track. Cement medium- hard. Taking 10 klbs WOB. 22:00 - 00:00 2.00 DRILL P SURF Drill rat- hole cement and new hole f/3316- 3332' and start mud swap to sea-water polymer based mud. 1/14/2002 00:00 - 00:30 0.50 DRILL P SURF Drill 12.1/4" Hole fro 3332 ft to 3336 ft ( 20 ft new hole) 00:30 - 01 :00 0.50 DRILL P SURF Circulate even weights 8.9 ppg = 8.9 ppg . BID lines 01 :00 - 01 :30 0.50 DRILL P SURF Conduct FIT to 12.6 ppg. 620 psi with 8.9 ppg. 1.8 bbls pump/return. 01:30 -10:30 9.00 DRILL P INT1 Directional Drill 12.1/4" Hole from 3,336 ft to 4,330 ft. P-rates 100-400 ftlhr. Raising flowrate to 850 GPM. No Drag. No Losses. 10:30 -11:00 0.50 DRILL P INT1 Sweep hole clean at 850 GPM/1850 psi. 11 :00 - 12:00 1.00 DRILL P INT1 POOH back to 3,730 ft- Hole swabbing, overpull25-30 klbs. Working pipe making no difference to swabbing tendency. 12:00 -13:00 1.00 DRILL N DPRB INT1 Pump back to 13.3/8" Shoe @ 3,296 ft. Some overpulls indicating balled up BHA pulling into shoe. 13:00 -14:00 1.00 DRILL P INT1 Service Top drive and grease crown. 14:00 -15:30 1.50 DRILL N DPRB INT1 Unable to work pipe into hole- Packed off. Rotate and find a "sweet spot" and circulate at 730 GPM/1600 psi bottoms up adding 10 ppb Walnut Medium plug to clean up BHA- Pump pressure dropped to 1350 psi. 15:30 - 16:30 1.00 DRILL P INT1 RIH. Hold up at 3,838 ft. Work through same. 16:30 - 00:00 7.50 DRILL P INT1 Drill ahead from 4330'-5140' md. Flowrates were increased to 950 gpm over the interval. Total ROP is 157 fph w/19 % sliding and 81 % rotating. 1/15/2002 00:00 - 11 :00 11.00 DRILL P INT1 Drill 12.1/4" hole from 5,140 ft to 6,044 ft. P-rates vary fl 100-350 ftlhr. Flowrate at 820 GPM until 5,600 ft because of Pulsation Dampener failure on Number 2 pump affecting real time LWD signal. Increase flowrate to 950 GPM 12400 psi. Some torque when backreaming on first 30 ft ( seen on other wells at this depth). 11 :00 - 12:00 1.00 DRILL P INT1 Sweep Hole clean @ 950 GPMI 2400 psi. 12:00 -16:30 4.50 DRILL P INT1 Make wiper trip back to old hole at 4,200 ft. Unable to dry wipe from 4,700 ft to 4,380 ft. Backreaml work thru and clean hole. Variables indicate balled BHA. Wiper trip picked on footage drilled. ( Could argue this particular wiper trip can be dropped on next well and go until bit trip) 16:30 - 17:00 0.50 DRILL P INT1 Drill and circulate out clay plug which plugged off possum belly. From Bottoms up- probably after reaming. 17:00 - 00:00 7.00 DRILL P INT1 Drill ahead from 6044' to 6426'. ROP varying from 50 fph to 250 fph. Flow rate 950 gpm. Torque on 10-11 k. woe 30k. Printed: 2/20/2002 11 :24:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/15/2002 1/16/2002 1/17/2002 1/18/2002 1/19/2002 ( (" BP EXPLORATION Operations Summary Report NS14 NS14 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours IActivity! Code I NPT 17:00 - 00:00 00:00 - 07:00 07:00 - 08:30 08:30 - 11 :00 11:00 -12:30 12:30 - 14:30 14:30 - 16:30 16:30 -19:30 19:30 - 22:30 22:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 19:00 19:00 - 21 :00 21 :00 - 00:00 00:00 - 12:00 12:00 - 00:00 7.00 1 DRILL 7.00 DRILL P P 1.501 DRILL 2.50 DRILL P P 1.501 DRILL P 2.001 DRILL N 2.001 DRILL P 3.001 DRILL P 3.00 I DRILL 1.50 DRILL P P 1.001 DRILL N 0.501 DRILL P 1.501 DRILL 0.50 DRILL P P 1.001 DRILL 7.50 DRILL P P 12.001 DRILL P 12.001 DRILL P 7.001 DRILL 2.00 DRILL P N 3.00 I DRILL 12.00 DRILL P P 12.001 DRILL P RREP IINT1 RREP IINT1 INT1 RREP IINT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Page 4 of14 Start: 1/7/2002 Rig Release: 2/12/2002 Rig Number: Spud Date: 1/8/2002 End: 2/12/2002 Phase Description of Operations RPM 100. Angle 38 deg. Drill from 6426' to 6899' md (6032' tvd). ROP sporadic (164-70 fph) after midnight. Average penetration down to 128.6 from 134+ fph before midnight. K revs on bit= 477k. Decide pull for PDC bit. Circulate hi-vis sweep surface to surface & monitor well. POOH (PUW = 240k I SOW= 200 k). No problems tripping out. Hole in good shape. Inside 13-3/8" shoe, monitor well. Service Top-Drive. Install new safety wires on IBOP bolts. Adjust Top-drive camera position. Grease crown sheaves. Repair Top Drive -- 3/8" x 1-114" bolt was missing from the IBOP actuator valve assembly. Second valve was found to be loose -- tightened remaining and replaced missing bolt. Inspected Top Drive thoroughly for any loose or missing bolts -- none found. TOH. Mechanic and crew start working on replacing leaky pulsation dampner on Mud Pump#2. Stand back and LD BHA #3. Directional driller graded out bit (12-1/4" Twist and Shout) 1-4-WT-M-E-2-NO-PR. PU BHA #4 (12 -1/4" Hycalog DS69, LWD, & MWD). TIH to 13-318" shoe wi BHA#4. Mechanic and crew still installing new pulsation dampner on Mud Pump #2. Continue to replace dampner on MP #2. Clean suction screens. Make connection and shallow test MWD. Good signal- no noise from dampner. RIH from 3297'-6732'. Wash and ream from 6732 - 6899' (60 rpm, 180 spm, 1850 psig). CBU. Perfom bench mark survey and establish PWD baseline. Drill ahead f/6899' to 7718'. Total ROP= 99.8 fph wi 75% rotating and 25% sliding. Total Flow= 950 gpm, WOB= 10k, SPP on= 2900 psigl SPP off= 2600 psig. Torque on 12,000 ft-Ibs. Inclination =37.56 deg I Azimth= 296.96 deg. MW= 9.25 ppg. Crew change. Drill ahead f/7718' to 8550'. Total ROP= 121 fph wI 85% 15 sliding. Drilling wi Total Flow = 940 gpm and WOB= 14k. Drill ahead f/8550'-9292'. ART= 4.0 hrsl AST= 5.3 hrs. At 9292'- Torque on is 15k ft-Ibsl Torque off 10 k ft-Ibs. ROT 70 rpm, WOB= 15k Ibs, Flow rate= 888 gpm and SPP= 3300 psig. PUW= 265k, SLW= 230 k, RWT= 245k. Note: At 0700 hrs, Island Muster Drill. Drill and slide ahead in Colville fl 9292-9574'. Pump #1 rod oiler not working. Shut-down pumps and reciprocate stand. Drill ahead in Colville f/9574'-9602'. Drill ahead f/9602' to 9890'. Sliding has been difficult, waiting on lubrication re-stock from shore. Slide from azimuth of 277.37 deg to 273.42 deg. ROP is good when rotating. Drill ahead from 9890' to 10207'. Slide from azimuth of 273.42 Printed: 2/20/2002 11 :24:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/19/2002 1/20/2002 1/21/2002 1/22/2002 ( ( Page 5 of 14 BP EXPLORATION Operations Summary Report NS14 NS14 DRILL +COMPLETE NABORS NABORS 33E 12:00 - 00:00 From - To I Hours I Activity I Code I NPT P 00:00 - 08:00 08:00 - 08:15 08:15 - 08:30 08:30 - 09:15 09: 15 - 11 :00 11 :00 - 17:30 17:30 -19:00 19:00 - 00:00 00:00 - 02:00 02:00 - 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 10:30 10:30 - 14:00 14:00 - 16:30 16:30 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 04:30 04:30 - 07:00 12.00 I DRILL 8.00 I DRILL 0.251 DRILL 0.251 DRILL 0.751 DRILL 1.751 DRILL 6.50 I DRILL 1.50 DRILL 5.00 DRILL 2.00 DRILL 3.00 DRILL 2.00 I DRILL 1.00 DRILL 2.50 DRILL 3.50 DRILL 2.50 DRILL 2.50 DRILL 1.00 DRILL 1.001 DRILL 1.001 DRILL 2.00 DRILL 4.50 I DRILL 2.501 DRILL P N DPRB IINT1 N DPRB IINT1 N DPRB IINT1 N DPRB IINT1 P P P P N INT1 INT1 INT1 DPRB IINT1 N P RREP IINT1 INT1 N P N P N RREP IINT1 INT1 RREP IINT1 INT1 DPRB IINT1 N FLUD IINT1 P P P P INT1 INT1 INT1 INT1 INT1 INT1 INT1 Start: 1/7/2002 Rig Release: 2/12/2002 Rig Number: Spud Date: 1/8/2002 End: 2/12/2002 Phase Description of Operations deg to 267.91 deg. Steering has improved with baronex spike and added lubrication. MW up to 9.6 ppg for HRZ and continue to wt up to 9.8 ppg for Kuparuk. Top HRZ came in -300' md high @ 10038 md. Drill f/1 0207-10566' md. Reach final inclination and azimuth @ 10500'. Rotating ahead to casing point TD. ECD Spike to 12.5 ppg. Reduce rate and work pipe. PU Wt increased fl 305k to 335k. Est rotation. Circulate and condition mud. Lost full returns. Shut down pumps and monitor well-- well is static. Move pipe while observing backside -- no swabbing. Condition mud and circulate-- monitor returns. Slowly regain returns while pumping 1 bpm and gradually increase to 4 bpm. Pump LCM 25 bbls, barofiber and walnut. Condition mud and circulate-- monitor returns. Increasde pump rate from 4 bpm to 12 bpm. Shut down pumps. Monitor-- ok. Condition mud & circulate-- increase rate to 19 bpm. Drill ahead from 10556 to 10930' md--casing point TD. No losses. Circulate sweep. Pull 5 stands. Pump dry job. Pull next 10 stands. Continue Wiper trip to 6282' (Stand 55). Stand #55 wet. Broke out stand, mud continued to flow. Stab TIW Valve & Shut-in annular preventer. SIDPP= 180 psig. No pressure on backside. Bleed DP to zero through bleed line. Open choke and verify zero pressure. Monitor. Open annular preventer. Drop dart valve. Thaw frozen mud pump out side line (-34 below ambient). Fill DP and annulus-well taking fluid--suspect seepage into Schrader and Top of Ugnu after wiper trip. Rih wi 3 stands to 6575' md. Bell nipple air boot leaking. Install TIW -- Replace arir boot in scoping bell nipple. RIH. Fill DP every 12- stds to 9486' md. Change out top drive oiler motor. Continue RIH to 10838' md. Backside burping gas. SI annular preventer-- no pressure. Circulate through choke to remove gas bubble. Note: Mud returns dehydrated--11.5-12.2 ppg, non-pressured scale. SD pumps-- no pressure, no flow. Open annular preventer. Circulate and condition mud. RIH to TD @ 10930 md. Circulate and condition mud. Note: Background gas ranging from 700 units to 3400 units through-out 2 bottoms-up circulations. Final background gas ranging approximately 3000 units. Wiper trip - pumped out 11 stands to top of HRZ. Note: Necessary to pump and ream to get past HRZ and necessary to pump and ream to get last stand in to TD. Circulate & condition mud I hole. Rotate & reciprocate. Pump 25 bbl barofiber sweep. Note: Background gas decreased from -1500 - 2500 units to Printed: 2/20/2002 11 :24:39 AM f ( BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/22/2002 04:30 - 07:00 2.50 DRILL P INT1 -200 units. 07:00 - 15:00 8.00 DRILL P INT1 POH 13 stands. Pump dry job & blow down mud lines. Continue POH from 6540' - 3240'. Overpull was 50 to 75K over in places. Note: Decision to make a circ and cond run to 6200' md to enhance logging run. 15:00 -15:30 0.50 DRILL P INT1 Clean floor & monitor well. 15:30 -18:00 2.50 DRILL P INT1 RIH to 6259'. 18:00 -19:30 1.50 DRILL N FLUD INT1 Circulate 2 x BU. Note: Max. gas 2100 units final background gas between zero and 50 units. 19:30 - 22:00 2.50 DRILL P INT1 POH to 13 3/8" casing shoe. Monitor well. 22:00 - 00:00 2.00 DRILL P INT1 PJSM - Slip & cut drilling line. 1/23/2002 00:00 - 02:00 2.00 DRILL P INT1 POH wi DP & HWDP. 02:00 - 06:00 4.00 DRILL P INT1 Clean out Anadrill tools with mud pumps & fresh water, blow down mud pump line, & LID BHA. 06:00 - 07:30 1.50 DRILL P INT1 Clear & clean rig floor. 07:30 - 14:30 7.00 DRILL P INT1 P/U test jt, pull wear bushing, set test plug, tie in trip tank to annulus, test BOP's, & set wear bushing. 14:30 -15:30 1.00 DRILL P INT1 Clean floor & PJSM for logging. 15:30 - 17:00 1.50 DRILL N DFAL INT1 RIU wireline loggers. 17:00 - 18:00 1.00 DRILL N DFAL INT1 Load source to run logs. 18:00 - 21 :00 3.00 DRILL N DFAL INT1 RIH with platform express & dipole sonic log. Work through obstruction at 6271'. Could not work through obstruction at 6485'. POH to remove bow type centralizer and rerun. 21 :00 - 00:00 3.00 DRILL N DFAL INT1 RIH with log. Tight spots at 6485',6962',7249',9286',9487', & 10200'. Did not get past 10200' and lost signal at 9487'. Note: Cable failure due to tough hole conditions for logging. 1/24/2002 00:00 - 02:00 2.00 DRILL N DFAL INT1 RiH with PEX and Dipole Sonic -- lost communication with tool and POOH. Note: This failure was not the fault of Schlumberger; instead it was the result of tough logging conditions presented by this wellbore. Wireline crew should be commended for their efforts and determination to log this interval. The wireline cable was damaged in 2 places above the wireline socket. Communication with tool was lost while trying to work through a tight spot at 9487' md. Were able to get thru this spot and attempted to get to TO prior to POOH eventhough there was no communiction with tool. Stacked up at 10200. Stuck tool at 9350' md while POOH -- the distance between the wireline tool to the damaged cable was equal to the distance between the trouble at 9487' md where tool quit and the tight spot at 9350' md. Suspect there is a ledge at 9350' md and the wireline was slapping against this while working the tool thru the trouble spot at 9487' md. 02:00 - 04:30 2.50 DRILL N DFAL INT1 Cut wireline, reconnect and test tools -- all systems working. 04:30 - 06:00 1.50 DRILL N DFAL INT1 RD Schlumberger Wireline and tools. 06:00 - 09:30 3.50 DRILL P INT1 PU Casing Tools to Rig Floor and LD 12-1/4" BHA out of derrick. 09:30 - 10:00 0.50 DRILL P INT1 Pull Wear Ring 10:00 - 11 :00 1.00 DRILL P INT1 LD elevators and bails and pull floor plate. 11 :00 - 11 :30 0.50 DRILL P INT1 PJSM for RU Franks Casing Fillup Tool -- Developed Printed: 2/20/2002 11 :24:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/24/2002 1/25/2002 1/26/2002 (' If ( BP EXPLORATION Operations Summary Report NS14 NS14 DRILL +COMPLETE NABORS NABORS 33E 11 :00 - 11 :30 From - To I Hours I Activity I Code I NPT P 11 :30 - 12:00 12:00 -13:00 13:00 - 00:00 00:00 - 14:30 14:30 -15:00 15:00 -15:30 15:30 -16:00 16:00 - 21:00 21 :00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 03:00 03:00 - 06:00 0.501 DRILL 0.50 I DRILL 1.00 DRILL P P 11.001 DRILL P 14.50 I DRILL P 0.50 DRILL 0.50 DRILL 0.50 DRILL 5.00 DRILL P P P P 2.00 I DRILL P 1.001 DRILL 0.50 DRILL P P 0.50 I DRILL 2.00 DRILL P P 3.00 I DRILL P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Phase Page 7 of 14 Start: 1/7/2002 Rig Release: 2/12/2002 Rig Number: Spud Date: 1/8/2002 End: 2/12/2002 Description of Operations procedure with Franks Rep, NAD Casing Operator, Rig Crew, Tool Pusher, NAD Drlg Supt and Drilling Rep -- Perfromed Hazard Analysis Checklist. Rig Up Franks Casing Fill Up Tool. Make up long bails, RU spider and elevator. Function test 9-518" casing rams in lower set of pipe rams -- Witnessed by Drlg Rep. RIH with 110 joints of 9-5/8" 47# L80 ModBtrc Casing. Notes: 1. Circ thru float equipment with Franks tool to check floats after MU joint 3. 2. Running speed predicated by trip tank results. 3. Hole taking -1.5 bbls per hour prior to running casing. RIH wi 9 5/8" casing. Notes: 1. Lost 42 bbls. of mud while running casing. 2. Slack off weight decreased from 225K to 175K for a partial joint @ 6,580'. At 10,722' casing stacked out to 100k. Pulled 550K & could not pull casing. Slacded off in preparation to pull to 600K & casing fell through tight spot. No other difficulties running casing to TD. P/U landing jt. & hangar. Land casing @ 10908'. RID & UD Frank's fill up tool. R/U cement head. Condition mud and circulate one casing volume -- 1.25 times bottoms up. Notes: 1. Start circulation at 1/2 bbl. per minute, increasing incrementally until 1 0 bpm was achieved. 2. PJSM for cement job was held while circulating. 3. Background Gas throughout circulation peaking at 2850 units. Reduced 500 units when circulating was complete. 3. Lost 50 bbls. while circulating. Pressure test cement lines to 3500 psi, pump 75 bbls. of spacer, drop bottom plug, pump lead & tail cement. See cement report for details. Displace cement with rig pumps @ 10 bpm. Displace cement. Bumped plug with 9284 stks. (94% pump efficiency + 1/2 shoe track volume - calculated) Halliburton flow meter & Epoch stroke counter in synchronization with each other barrel for barrel. UD cement head & landing jt. CIO elevators. P/U 1 stand HWDP & install 9 5/8" packeff. Test to 5,000 psi & bled off. Left 5,000 psi on plastic packing. Stood back HWDP stand. PI U test joint and set bowl protector. Began bullheading mud down 13 3/8" x 9 5/8" annulus at 1/2 bpm once packoff was landed & tested. UD casing tools, change bails, & clear rig floor of tools. Printed: 2/20/2002 11:24:39 AM BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/26/2002 06:00 - 12:00 6.00 DRILL N RREP INT1 Remove floor mats & plates around rotary table and clean. Pull rotary table and change seal on motor. Replace table, floorplates, clean & replace mats. 12:00 - 13:00 1.00 DRILL P INT1 Change sweep from lower to upper annulus. 13:00 -17:00 4.00 DRILL N INT1 Warm up, drain, flush and replace gear oil in top drive gear box. Service top drive, crown, block, and sheaves. 17:00 -18:00 1.00 DRILL N HMAN INT1 P/U mud motor - UD same. Break sleeve off of motor - sleeve too big. 8.625 18:00 - 21:30 3.50 DRILL P INT1 M/U BHA # 5. 21 :30 - 22:00 0.50 DRILL P INT1 Test MWD @ 1016.83'. 22:00 - 00:00 2.00 DRILL P INT1 RIH wi 5" DP filling every 25 stands. 1/27/2002 00:00 - 05:30 5.50 DRILL P LNR1 RIH from 3400' to 10770'. Fill pipe every 25 stands. Tag cement stringers @ 10770'. 05:30 - 09:30 4.00 DRILL N FLUD LNR1 Clean out cement to top of plugs @ 10,818'. Notes: Plugging off suction screens on mud pumps due to additives in mud not shearing properly. Both hoppers were being utilized simultaneously to mix 17.0 spike fluid & new 9.8 mud. The hopper being utilized to mix the 9.8 mud is not a shear hopper. The polymer created "fish eyes" and the Desco created clumps and plugged off screens. Problem solved by stopping the mixing of spike fluid and lining up #1 pit on Vortrex Hopper and sheared. Highly recommend this hopper be replaced with another Vortex hopper. 09:30 - 10:00 0.50 DRILL P LNR1 Pump up & hook up sensors for casing test. 10:00 -11:00 1.00 DRILL P LNR1 Test casing to 4,300 psi & hold for 30 minutes. Discuss well control while waiting on casing test. 11 :00 - 12:00 1.00 DRILL N WAIT LNR1 Process leak occured when drain plugged in pipe set back and 30 gallons of drilling fluid spilled over lip into cellar area -- Had Spill Drill to assemble crews and clean up. Notes: Called ACS technician immediately to visually inspect the incident. 12:00 -13:00 1.00 DRILL N WAIT LNR1 Safety stand down. 13:00 -16:00 3.00 DRILL N SFAL LNR1 Clean cellar area. Blow down all mud lines & kill line. Thaw bleed off line. 16:00 - 16:30 0.50 DRILL N SFAL LNR1 Calibrate mud pump gauges. 16:30 - 19:30 3.00 DRILL P LNR1 Drill out shoe track from 10,818' to 10930'. 19:30 - 20:30 1.00 DRILL P LNR1 Circulating hole clean. Packing off & high torque while drilling rathole -- picked up and circulated. This occurred in during NS09 also. 20:30 - 22:00 1.50 DRILL P LNR1 Drill from 10,930' to 10950'. 22:00 - 22:30 0.50 DRILL P LNR1 Perform FIT to 13.5 EMW. 22:30 - 00:00 1.50 DRILL P LNR1 Drill from 10,950' to 11,000' 1/28/2002 00:00 - 00:00 24.00 DRILL P LNR1 Drill & slide from 11,000' to 11,891' MD. AST 8.2 hrs. ART 11.7 hrs. 1/29/2002 00:00 - 10:00 10.00 DRILL P LNR1 Drlg f/11891' to 12423' md. Note: Sliding less than optimal -- unable to access total lubricants. Zoom Boom was not working -- rented one from Deadhorse but did not arrive island until late. Working with AIC and NAD loaders to coordinate unloding of mud product for easier access. ( (' Printed: 2/20/2002 11 :24:39 AM BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/29/2002 10:00 - 11 :00 1.00 DRILL N FLUD LNR1 Circulate and Condition Mud while wieghting up -- attempting to circ and rotate at 120 rpm to determine if barite falling out -- not the case. 11 :00 - 12:00 1.00 DRILL N FLUD LNR1 Clean out suction screen. 12:00 - 13:30 1.50 DRILL P LNR1 Drlg f/12423' - 12480' md. 13:30 -15:00 1.50 DRILL P LNR1 Pump Sweep while Circ and Cond Mud. 15:00 -18:30 3.50 DRILL P LNR1 Wiper Trip to 9-5/8" csg shoe @ 10908' md. Notes: Tight on bottom across Sag and Pulled 40K over at various points which wiped clean. Rathole under 9-5/8" casing was ratty. 18:30 - 21:30 3.00 DRILL P LNR1 Pump Hi Vis Weighted Sweep and Circ and Cond for running liner. Notes: 1. Signs of splintered shale in BU and more signs of splintered shale in wieghted fiber sweep. Splintered shale in returns after sweep. 2. Discussion with Core Rig Team and Anchorage team -- Decision to Weight up 0.5 ppg to 12.3 ppg. 21 :30 - 22:30 1.00 DRILL N DPRB LNR1 Trip to shoe for weight up to prevent washing out hole while circ and weighting up. 21 :30 - 00:00 2.50 DRILL N DPRB LNR1 Circ while weighting up from f/11.8 to 12.3 ppg. 1/30/2002 00:00 - 03:30 3.50 DRILL P LNR1 Circulate just below the shoe while increasing MW from 11.8 ppg to 12.3 ppg. 550 GPM/2100 psi 03:30 - 04:30 1.00 DRILL P LNR1 RIH from 10911' to 12423'. 04:30 - 05:30 1.00 DRILL P LNR1 Ream tight hole from 12423' to 12458'. Tag fill at 12458' & clean out to 12480'. First tagged fill @ 12,430 ft. 05:30 - 08:30 3.00 DRILL P LNR1 Circulate & reciprocate 60'. Pump barafiber sweep. Splintered shales coming across shakers throughout 2.5 x BU. 08:30 - 10:30 2.00 DRILL P LNR1 Circulate, rotate @ 60 RPM, & reciprocate 60'. Spot Barotrol pill. 10:30 - 12:00 1.50 DRILL P LNR1 Blow down top drive mud lines & start to POH. 12:00 -13:00 1.00 DRILL P LNR1 Continue POH to shoe @ 10,908'. Work thru tigt spot @ 12,400 ft. Wipe out. 13:00 -14:30 1.50 DRILL P LNR1 Service top drive and monitor well. 14:30 -15:30 1.00 DRILL P LNR1 RIH to 12,463' & tag fill 17 ft off bottom. 15:30 -16:00 0.50 DRILL P LNR1 Wash down & ream from 12,463' to 12,480'. 550 GPM - 60 RPM - 2000 PSI 16:00 - 16:30 0.50 DRILL P LNR1 Drill from 12,480' to 12,490' 16:30 -19:30 3.00 DRILL P LNR1 Circulate sweep & clean hole. Spot Baratrol pill. 19:30 - 21:30 2.00 DRILL P LNR1 POH to 9.5/8" shoe @ 10,950 ft. Tight spot at 12,405' to 12,395 ft. ( Same as previous trip). Work thru and wipe out. Overpulls up to 50 klbs. 21 :30 - 22:30 1.00 DRILL P LNR1 Monitor well @ shoe, pump dry job, & blow down top drive & mud line. 22:30 - 00:00 1.50 DRILL P LNR1 Drop 2.375" rabbit & continue POH. 1/31/2002 OO:Oð - 04:30 4.50 DRILL P LNR1 POOH 5" drillpipe to 1017 ft ( top of HWDP) 04:30 - 06:00 1.50 DRILL P LNR1 POOH 5" HWDP 06:00 - 07:30 1.50 DRILL P LNR1 Lay down 8.1/2" BHA. Bit in good shape. 07:30 - 09:00 1.50 CASE P LNR1 Clear rigfloor and RIU to run 7" Liner. 09:00 - 09:30 0.50 CASE P LNR1 Conduct PJSM for running 7" liner. ( ( Printed: 2/20/2002 11 :24:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/31/2002 2/112002 2/2/2002 Date (' ( BP EXPLORATION Operations Summary Report NS14 NS14 DRILL +COMPLETE NABORS NABORS 33E 09:30 - 13:00 From - To I Hours I Activity I Code I NPT LNR1 13:00 -14:00 14:00 - 16:00 16:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 04:30 04:30 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 10:30 10:30 - 12:00 12:00 -13:30 13:30 -14:00 14:00 -15:00 15:00 - 17:00 17:00 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 10:00 3.501 CASE 1.001 CASE 2.00 I CASE 7.001 CASE 1.00 CASE 2.00 CASE 2.50 CASE 1.001 CASE 1.001 CASE 0.501 CASE 3.501 CEMT 1.501 CEMT 1.501 CEMT 0.50 I CEMT 1.00 CEMT 2.00 I CASE 5.00 CASE 0.50 CASE 1.50 CASE 3.50 CASE 1.00 CASE 0.50 CASE 5.00 CASE Phase P P LNR1 N RREP I LNR 1 P LNR1 P P P LNR1 LNR1 LNR1 P LNR1 P LNR1 P LNR1 P LNR1 P LNR1 P LNR1 P P LNR1 LNR1 P P LNR1 LNR1 P P P P P P LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 Page 10 of 14 Start: 1/7/2002 Rig Release: 2/12/2002 Rig Number: Spud Date: 1/8/2002 End: 2/12/2002 Description of Operations Make up 7" shoetrack and check floats- good. Run 42 joints of 7",26 I b/ft , BTC Mod. Make up Liner Hanger. Upl Down weight 103 klbs. Clear rigfloor. Attempt to circulate- no go. Pumps unable to generate pressure despite confirmation of charge. Strking , but not pumping. Double check all surface lines. No obvious problems detected. Conduct PJSM with Halliburton and elect to fill pipe with HOWCO while troubleshooting pumps. RIH on 5" drillpipe filling every 11 stands with halliburton to 9,000 ft while stripping down pumps- establish solidsl contaminates throughout circulating system and in particular at fluid end of pumps. Halliburton finding drilling solids at their end when sucking mud from rig causing problems at his end. Continue to RIH on 5" drillpipe filling pipe with mud pumps. Run in hole with 7" liner to 10,845 ft.- Just above 9.5/8" shoe. Circulate 1.5 times Liner and string volume @ 6 BPMI 700 psi. Up weight 280 klbs, down weight 225 klbs. Ensure Mud pumps clear of debris before Running into open hole. Make up Liner cement head to stand of drillpipe and stand back in derrick. Run into open hole. Start stacking weight @ 11 700 ft ( Top Kingak @ 11,460 ft). Taking 30 - 125 klbs but making forward progress. Make up Cement Head and hook up circulating lines with shoe @ 12,420 ft. Attempt to circulate- no go. Pipe free between 12,460 ft and 12,475 ft. Work fluid path and gradually raise rate to 5 BPMI 840 psi circulating bottoms up. Fill @ 10,475 ft- unable to wash out. Could not take rate higher than 5 BPM- pack-off. Up weights sometime @ 425 klbs. No shale splinters on BU. Pump 50 bbls Alpha spacer. 75 bbls of 15.9 ppg G Slurry(281 sacks) @ 5 BPM/11 00 psi. Observe dart released. Displace with rig pumps. At final stroke count for plug bump ( 2950 strokes for 251 bbls @ 96% effieciency) observe Plug latch- Go by Howco flowmeter and continue pumping ignoring pump strokes. Observe cement climbing. 13 bbls from bump packed off and stuck liner. Squeezed fluid away and osberve plug bump to 3500 psi. Check floats. ( Mud Pump efficiency works out at 70%!) Set Packer and back out of liner- good indication. Circulate bottoms up @ 18 BPM/3500 psi. Observe cement contaminated mud on bottoms up for approximately 90 bbls. Lay down cement head and break all service connections. POH wI DP & liner I hangar running tool. Tested choke manifold while POH. Make service breaks on Baker running tool & LID. PJSM. Change out blind rams for shear rams. Pull blind rams & replace with shear rams. Install 5 1/2" rams. Pull bowl protector & install test plug. RIU test equip't & fill stack. Test BOP's 250 psi 14500 psi 5 110 minutes. Printed: 2/20/2002 11 :24:39 AM ( ( BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/212002 10:00 - 11 :00 1.00 CASE P LNR1 Blow down lines, pull test plug, & install bowl protector. 11 :00 - 11 :30 0.50 CASE P LNR1 Test 7" liner to 3200 psi & hold for 30 minutes. okay 11 :30 - 14:30 3.00 CASE P LNR1 PJSM - cut & slip drilling line. 14:30 - 15:00 0.50 CASE P LNR1 Adjust brakes & inspect all lines in drum. 15:00 -18:00 3.00 CASE P LNR1 M/U BHA #6. (PJSM -load source 1/2 hour) 18:00 -18:30 0.50 CASE P LNR1 P/U 430' HT HWDP. 18:30 -19:00 0.50 CASE P LNR1 P/U 4" HT 40 from pipeshed. 19:00 -19:30 0.50 CASE P LNR1 Move 5" HWDP out of way in derrick to access 4" HT 40. 19:30 - 20:00 0.50 CASE P LNR1 Reinstall crown saver. 20:00 - 21 :00 1.00 CASE P LNR1 RIH wi 4" HT 40. 21 :00 - 21 :30 0.50 CASE P LNR1 cia to 5" elevators, M/U x-over & dart sub, & RIH with 1 stand of 5" DP. 21 :30 - 22:00 0.50 CASE P LNR1 PJSM on freeze protecting 13 3/8" x 9 5/8" annulus. 22:00 - 22:30 0.50 CASE P LNR1 Surface test MWD @ 2924'. okay 22:30 - 00:00 1.50 CASE P LNR1 Freeze protect 13 3/8" x 9 5/8" annulus. 2/3/2002 00:00 - 01 :30 1.50 CASE P LNR1 Freeze protect 13 3/8" x 9 5/8" annulus. Pumped 117 bbls @ 1 BPM. Final pressure 830 psi. 01 :30 - 02:00 0.50 CASE P LNR1 BID & test kill line. 02:00 - 08:30 6.50 CASE P LNR1 RIH to 12,338' - fill every 40 stands. 08:30 - 09:00 0.50 CASE P LNR1 Fill DP & wash down to 12,382" 09:00 - 11 :00 2.00 CASE P LNR1 Drill out shoe track & clean out rat hole to 12490' @ 340 GPMI 3000 psi. Cement reasonably hard. 11 :00 - 14:00 3.00 CASE P LNR1 PJSM - Displace 12.3 mud wi new 9.1 ppg mud. 14:00 - 16:00 2.00 CASE P LNR1 Clean L pits. Thaw out frozen lines on trip tank. ( -70degs windchill) 16:00 -17:00 1.00 DRILL P LNR1 Drill from 12,490' to 12,515' MD. 17:00 -17:30 0.50 DRILL P LNR1 Circulate 15 minutes & POH with 1 stand and rack back. 17:30 -18:00 0.50 DRILL P LNR1 Perform FIT test to 11.3 EMW with 9.2 ppg mud. (1170 psi) 18:00 - 18:30 0.50 DRILL P LNR1 Blow down kill line. 18:30 - 00:00 5.50 DRILL P LNR1 Drill from 12,515' to 12,610'. 340 GPM 11700 psi. RPM @ 80. 2/4/2002 00:00 - 12:30 12.50 DRILL P PROD1 Drill from 12610' to 13,020 MD. TD 340 GPM/1900 psi. 80 RPM/13 kftlbs ART 8.0 hrs. AST 1.0 hrs. 12:30 - 14:30 2.00 DRILL P PROD1 Condition mud & circulate for short trip. 14:30 - 15:00 0.50 DRILL P PROD1 POH to 7" shoe. Hole slick. 15:00 - 23:00 8.00 DRILL N WAIT PROD1 PJSM. Shut down Operations and discuss hazards. Monitor well & wait on weather. Phase 3 conditions slope wide. Winds ranging from 30 - 50 mph with gusts up to 65 mph. Took advantage of the opportunity by cleaning rig, relocating BOP test pump to trip tank area from rig floor, and updating a few procedures. 23:00 - 00:00 1.00 DRILL N WAIT PROD1 Condition & circulate mud @ 40 SPM 140 RPM while reciprocating pipe inside shoe. 2/5/2002 00:00 - 04:00 4.00 DRILL N WAIT PROD1 Monitor well while observing wind conditions and weather trends. Return to operations when wind speeds drop below 25 knots and accounting for estimated timing of ice road opening. Weather pattern following forecast. Hold PJSM to discuss return to operations. 04:00 - 05:00 1.00 DRILL P PROD1 RIH washing down last stand- hole slick. Printed: 2/20/2002 11 :24:39 AM BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/512002 05:00 - 07:00 2.00 DRILL P PROD1 Pump sweep surface to surface at 340 GPM/2100 psi while rotating pipe at 80 RPM. 07:00 - 08:00 1.00 DRILL P PROD1 Flowcheck. POOH to 7" shoe @ 12,741 ft. Hole slick. 08:00 - 08:30 0.50 DRILL P PROD1 Flowcheck at 7" shoe and pump dry job. 08:30 - 14:00 5.50 DRILL P PROD1 POOH 5" drillpipe to 4" crossover. 14:00 - 15:30 1.50 DRILL P PROD1 POOH 4" drillpipe. 15:30 -17:00 1.50 DRILL P PROD1 POOH laying down 4" HWDP and BHA to LWD. 17:00 -17:30 0.50 DRILL P PROD1 PJSM. Remove Source 17:30 -18:30 1.00 DRILL P PROD1 Lay Down remainder of LWD/MWD and motor tools. Bit graded: 3-3-WT-A. E-1-BT-TD. 18:30 -19:30 1.00 CASE P CaMP PU casing tools from Haggland to rig floor. 19:30 - 20:00 0.50 CASE P CaMP Clear and clean rig floor. 20:00 - 21 :30 1.50 CASE P CaMP Rig up casing running tools. 21 :30 - 23:30 2.00 CASE P CaMP PJSM. Run 16 jts of 4-1/2" Vam-Ace liner, float shoe, float collar, and landing collar. Filling up every jt. Check floats. 23:30 - 00:00 0.50 CASE P COMP MU FLEX-LOCK Liner Hanger(8 pinsl 2850 psig to shear) and ZXP packer wi C2 profile (5 pinsl 25000# shear-down). 2/6/2002 00:00 - 10:00 10.00 CASE P CaMP Continue to RIH with 4.1/2" Liner on 5" x 4" drillpipe to 12,386 ft. One stand above the 7" shoe @ 12,471 ft. 10:00 - 11 :30 1.50 CASE P CaMP Circulate string contents @ 8 BPMI 900 psi. Up weight 285 klbs, down weight 245 klbs. No Losses. 11 :30 - 12:30 1.00 CASE P CaMP Make up cement head to double of 5" drillpipe, install valves and stand back in derrick. 12:30 - 13:30 1.00 CASE P CaMP Run 4.1/2" Liner to bottom- hole good in sandstone. I 13:30 - 14:00 0.50 CASE P CaMP M/U cement head and run to bottom tagging TD on depth @ 13,020 ft. Some drag in Kavik. 14:00 - 16:30 2.50 CEMT P CaMP Gradually increase rate to 7.5 BPM/950 psi. Up weight 295 klbs, down weight 250 klbs. No Losses. Hold PJSM while conditioning hole. Circulate bottoms up- no gas, no excessive cuttings. 16:30 -17:00 0.50 CEMT P CaMP Test Lines to 4000 psi. Pump 30 bbls Spacer and 25 bbls/1 05 sacks of 15.9 ppg G Slurry @ 4 BPM/300 psi. 17:00 -18:00 1.00 CEMT P CaMP Switch to rig pumps. Observe dart release and Pump 208 bbls of Mud @ 7.5 BPMI 500 psi. Observe spacer and cement climbing on backside. No Losses. Observe latch and bump plug- Pump efficiency 97%. 18:00 -18:30 0.50 CEMT P CaMP Pressure to 4000 psi. Check floats -good. Set Packer and observe shear. Rotate and slack off 50 klbs- good. Sting out and commence circulating any cement from top of 4.1/2" Liner @ 12,318 ft. 18:30 -19:30 1.00 CEMT P COMP CBU @ 15-17 bpm. Cement to surface, bypass shakers and take returns to G & I. Circulate hole clean- dispose of 80 bbls. Estimate 5-8 bbls returned to surface. 19:30 - 20:00 0.50 CEMT P CaMP Break down cmt head and manifold. 20:00 - 00:00 4.00 CEMT P CaMP Pump dry- job. Blow down all lines. POOH wi running tool. 2/7/2002 00:00 - 02:30 2.50 CEMT P CaMP POOH wi liner setting tool. 02:30 - 03:00 0.50 CEMT P CaMP Clean and clear rig floor. 03:00 - 07:30 4.50 CEMT P CaMP Slip & Cut 663' of drilling liner. Service drawworks- inspect brakes. 07:30 - 08:00 0.50 CLEAN P CaMP Rig up 2-3/8" equipment for making up tapered clean-out string. 08:00 - 08:30 0.50 CLEAN P CaMP PU 2-3/8" DP and RIH wi BHA#7 (3-3/4" mill). 08:30 - 10:00 1.50 CLEAN N RREP CaMP Work on power tongs. Rig Down - Rig Up manual tongs. ( (: Printed: 2/20/2002 11:24:39AM. (' ( BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: NS14 Common Well Name: NS14 Spud Date: 1/8/2002 Event Name: DRILL +COMPLETE Start: 1/7/2002 End: 2/12/2002 Contractor Name: NABORS Rig Release: 2/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/712002 10:00 - 12:30 2.50 CLEAN P CaMP Continue P/U 2-3/8" DP & RIH. Change out handling equipment. MU 7" casing scraper & RIH 4" DP. 12:30 - 14:00 1.50 CLEAN N RREP CaMP Work on Iron Roughneck. 14:00 - 19:00 5.00 CLEAN P CaMP Iron Roughneck will require more time to repair. Continue RIH wi 4" DP using chain tongs. MU 9-5/8" casing scrapper and continue RIH wi 5" DP to 5745' md. 19:00 - 20:00 1.00 CLEAN P CaMP Pressure testing casing to 3400 psig fl 30 min wi 9.3 ppg MW. 20:00 - 00:00 4.00 CLEAN P CaMP Continue RIH wi 5" DP using chain tongs T/12023' md. 2/8/2002 00:00 - 00:30 0.50 CLEAN P CaMP RIH to 12308'. PU WT = 285, SOW= 240 K, ROW= 260 K Ibs. 00:30 - 03:00 2.50 CLEAN P CaMP Wash down to 4-1/2" Landing Collar @ 12931' md. 03:00 - 03:30 0.50 CLEAN P CaMP PJSM on pumping Caustic wash and Baraclean sweeps. 03:30 - 04:00 0.50 CLEAN P CaMP Clean Pit and build sweep. 04:00 - 06:30 2.50 CLEAN P CaMP Pump caustic and Baraclean. Displace well over to Sea Water. Pump 1-1/2 surface to surface volume @ 11 bpm. Have 56 NTU SW quality. 06:30 - 07:00 0.50 CLEAN P CaMP Monitor well for negative test. Blow down lines. 07:00 - 19:00 12.00 CLEAN P CaMP POOH. Have some drag @ Mill depth's of 12178, 12088', 12007',11927',10246',10156',10036',9996'. Rotate slowly to get through the first four depths listed. No problem going down- smooth. No drag after 9996'. Two small slivers of metal on 9-5/8" casing scraper. Change to 4-1/2" handling equipment. POOH standing back 4". No debris or problem wi 7" scraper. Hang-ups possibly down to casing collars in 9.5/8". LD 2-3/8" DP. 19:00 - 20:30 1.50 CLEAN P CaMP Clear and clean rig floor. Change bails. 20:30 - 22:30 2.00 CLEAN N RREP CaMP Pull rotary motor. 22:30 - 00:00 1.50 CLEAN P CaMP Rig up to run completion. 2/9/2002 00:00 - 03:30 3.50 RUNCO~ ~ CaMP RU to run completion. 03:30 - 04:00 0.50 RUNCO~ ~ CaMP PJSM wi Nabors crew, Weathorford crew, Tuboscope hand, and Baker hand for running completion. 04:00 - 05:00 1.00 RUNCO~ ~ CaMP MU 4.5" WLEG, 'XN' nipple, and 'X' nipple assembly- Baker lock. MU Baker Permanent Pkr and 'X' nipple assembly. MU Cidra Mandrel. 05:00 - 06:00 1.00 RUNCO~ ~ CaMP Tie in fiber optic cable to Cidra Mandrel and PT to 8000 psig. 06:00 - 10:00 4.00 RUNCO~ (P CaMP Run 50 joints 4.5" 12.6# chrome Vam-Ace tubing. 10:00 - 12:00 2.00 RUNCO~ ~ CaMP Attempt MU 5-1/2" x 4-1/2" XC. Can't torque turn- too short. MU backup 5-1 12 "x 4-1 12"x4-1 12" XC. Change Spiders over to 5-1/2" dies. Change over Koomey lines. MU floor Safety Valve for 5-1/2" 17# Fox thread. 12:00 - 00:00 12.00 RUNCO~ ~ CaMP Run 5-1/2, 17# chrome Fox tubing 123 Jts. Tuboscope inspecting each joint. 2/10/2002 00:00 - 07:00 7.00 RUNCO~ ~ CaMP Continue to run 5.5"x4.5" chrome completion string. 07:00 - 08:00 1.00 RUNCO~ ~ CaMP MU SSSV. MU control and balance lines to SSSV landing nipple. PT to 5000 psig. Good. 08:00 - 12:00 4.00 RUNCOr (P CaMP Continue to run 5.5" Fox pipe jts. Set down on 7" liner top @ 10744' md. PU and slide through- no boobies. Average 10-11 jts per hour. See some resistance when wireline guide entering tie-back sleeve. Tag down 26' down on jt #236 of 5.5". 12:00 - 14:00 2.00 RUNCOr (P CaMP Space out and run 10.05',2.06',4.10', and 8.06' pup jts below JT #234 of 5.5" 17# Fox tubing. MU hanger and 4.5" landing jt. 14:00 - 16:00 2.00 RUNCor (P CaMP Splice and run Cidra & control lines through hanger. Printed: 2/20/2002 11 :24:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/10/2002 2/11/2002 2/12/2002 ( (' BP EXPLORATION Operations Summary Report NS14 NS14 DRILL +COMPLETE NABORS NABORS 33E 16:00 - 18:00 From - To I Hours IActivity! Code I NPT CaMP 18:00 -19:00 19:00 - 21:00 21 :00 - 22:00 22:00 - 00:00 00:00 - 06:00 06:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11 :00 - 20:30 20:30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 06:30 06:30 - 08:00 Phase 2.00 I RUNCOt 1.00 I RUNCO 2.00 RUNCO CaMP CaMP 1.00 I RUNCO~ 2.00 I RUNCO 6.00 RUNCO CaMP CaMP CaMP 3.50 I RUNCOf\/P CaMP 1.00 I RUNCOt 0.50 RUNCO 9.50 I WHSUR P CaMP CaMP CaMP 3.501 WHSURIP CaMP 2.00 WHSUR P 1.00 WHSUR P 3.50 WHSUR P CaMP CaMP CaMP 1.501 DEMOB IP CaMP Page 14 of 14 Start: 1/7/2002 Rig Release: 2/12/2002 Rig Number: Spud Date: 1/8/2002 End: 2/12/2002 Description of Operations Land and RILDS. PUW= 255K, SOW= 200K. Test Tbg hanger to 5000 psig. Reverse circulate Sea Water until returns are clean. Rig up and test surface lines. Prepare to pump corrosion inhibitor pill. Pump 25 bbls Corrosion Inhibitor and follow wI 4 bbls Escade mineral oil. Reverse circulate Diesel @ 1 bpm. Reverse circulate 302 bbls diesel for FP @ 1 bpm. Follow wi 4 bbls Escade mineral oil. Flush wi SW. Break out TIW valve. Drop 1-718" ball and rod. MU TIW valve. Pressure up to 4200 psig and set pkr and hold tubing test, record on chart and also record Cidra pressure gauge data for 30 mins. Bleed off pressure to 2600 psig. Pressure up on IA to 4200 psig for MIT. Rock solid test recorded on chart and Cidra gauge. Bleed off tubing and shear RP valve. Open tubing side to IA side and U-tube. Halliburton flow meter indicating 3.5 bpm U-tube. U-tube 93 bbls. Bleed down all lines to bleed tank. Back out landing jt and lay down. Set TWC. Change out 5-1/2" rams to 9-5/8" rams. Drain Stack. ND and rack back BOPE stack. ND mud cross and single gate. Wrap and terminate Cidra FO cable and SSSV control and balance line to WHo Change liners on Pump 1 and 2 over to 6". Change paddles & seats on 4" discharge valves off each pump. Layout herculite. Use 60 ton crane to spot matting boards in between flowlines. Operations pumping down gray and black water. G & I has kill wt mud prepared for NS 10. Remove drilling sweeps from wellhead and preparefor rigmove. Remove mud cross and move tree to cellar. Install tree and est same to 5000 psi- good. APC had pre-installed some instrumentation while in workshop- part of Technical Limit POP iniiative. Pull TWC and secure tree Release rig from NS-14 @ 0800 hrs on 12th February 2002. Printed: 2/20/::002 11:24:39AM ( ( Well: NS14 Rig Accept: 01/08/02 Field: Northstar Unit Rig Spud: 01/09/02 API: 50-029-23026-00 Rig Release: 02/12/02 Permit: 201-118 Drilling.£!!.g: Nabors 33E POST - RIG WORK 02117/02 - 02119/02 MIRU SWS E-LiNE UNIT. RUN PRIMARY DEPTH CONTROL LOG / GR FROM SURFACE TO PBTD OF12945', LOG SCMT INTERVAL FROM 12000' - 12945', JEWELRY LOG. PU MU GR/CCL, 30' OF 2 7/8" HSD/2906PJHMx/6SPF/.36" DIA/27" PEN. TIE IN WI SCMT PERFORATE INTERVAL: 12886' - 12916', PERFORATING WI 27/8" 12906 PJ HMX I 6 SPF I .36" DIA I 27" PEN. LAY DOWN RUN #1. PERFORATE INTERVAL: 12856' - 12886', 12826' - 12856', MIS-RUN FOR INTERVAL 12796' - 12826' (O-RING FAILURE IN BOTTOM BULLNOSE). PERFORATE WI 27/8" HSD I 2906 PJ HMX 16 SPF I .36" DIA I 27" PEN. FINAL PERF INTERVAL OF 12766' - 12796', NOTE: TOTAL PERF INTERVAL OF 12766' - 12916' TIED INTO SCMT. RIG DOWN E-LlNE, RIG UP SLlCKLINE. RUN 51/2" DBD SSSV ATTEMPT TO SET AT 1916' SLM. UNABLE TO GET ISOLATION OF CONTROL AND BALANCE LINE. PULL VALVE. STAND BACK FOR COMPLETION OF TIE IN AND POP, - Legal Name: Common Name: NS14 NS14 1/14/2002 1/27/2002 2/312002 m~$.f.'.E)êptfílmMQ} 3,336.0 (ft) 10,950.0 (ft) 12,471.0 (ft) FIT FIT FIT JT~.faøptl1lTIlP} 3,226.0 (ft) 9,331.0 (ft) 10,740.0 (ft) 8.90 (ppg) 11.50 (ppg) 9.20 (ppg) 620 (psi) 970 (psi) 1,170 (psi) Leak Off Pressure (BHP) 2,112 (psi) 6,544 (psi) 6,303 (psi) Page 1 of 1 EMW 12.60 (ppg) 13.50 (ppg) 11.30 (ppg) .......-~, "". Printed: 2/20/2002 11 :24:32 AM I: In ()o W - J - U \ - « C) ..c~ ~ I- In - r\S :::J (/J ~ ~ « 0 I[ ... :r. ..J Q. I W « w (/J z a:: z In O ..J ~ l - ....I « ~ « w ~ I!I ~ (/J l 0:: J: 2 0 LL ~ ..J 0 0:: OJ - Q. 0 .J >< c z D. J w z a.. w - 0: m '._~ In [] ¡~ r- - - -- -........ --- - - - - - - - - - - - - I I I I I ( I I r I ( ( I I I I I I I ( TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Daily Operations 4. Show Reports 5. Morni ng Reports 6. BHA's 7. Bit Record 8. Mud Reports 9. Survey Record 10. Formation Tops 11. Formation Evaluation Logs spen""v- sun !:I R .'-'-. N t5 5 Ii! fit \J . c: (! !i ~. I I I I I I I I I I I I I I I I I I I (' GENERAL WELL INFORMATION Company: Rig: Well : Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS 14 Northstar North Slope Alaska United States 50-029-23026-00 AK-AM-22002 January 06, 2002 February 04,2002 True 26.574 deg 80.928 deg 57511.700 nT January 07, 2002 North 70 deg 29 min 27.977 sec East 148 deg 41 min 35.865 sec 285.810 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Joe Polya Mike Dinger Ken Lemley Northstar 107 Alaska North Slope sparar"y- sun C R 1 LLI N IS !i EFt V 1 c: E S I I ~ ( \ . BP Exploration - Northstar NS 14 Daily Well Summary [ v 1/07/2002 Perfonned P ISM to prep to move rig to N S-14, Skidded rig floor back to center oframs for rig move. PJSM to pull service lines trom pipe rack. Pulled service lines trom pipe-rack..Prepared rig to skid. Warmed up [ t1oving hydraulics system Performed PJSM on moving rig. Finished preparing rig for move. Moved rig to NS-14 ITom NS-9. 111/08/02 Continued to move rig over the well NS-14. Installed the stairs around the rig and got the heater going in the cellar. Hooked up the service lines to pipe rack and secured lines at NS-09. Cleaned up the rig and bermed all areas. T..oaded the BHA into the pipe shed. Rig accepted at 0800 hrs on 8th January for NS-14 1 )erformed PJSM with AlC and APC to clear area around NS-09 to facilitate tie in ofNS-09 with Excellent SIMOPS co-operation. Pre spud Meeting with all Rig Crews and service personnel. Discussed well Objectives and HSE ~xpectations outline. Continued to clean and berm the rig and helped with APOC and AlC with well tie in NS-09. [ ~ippled up the 20" Riser. While continuing to berm rig. Installed the mouse hole. Laid plywood in the cellar. Picked up BHA #1 tools to floor and pipeshed. Thawed connections. Picked up SW sheaves for GYRO to the floor. Made up r~HA #1 and conducted D-7 Drill. . 01/09102 Continued to make up 16" Spud assembly BHA # 1. Rigged up Gyro survey equipment with Schlumberger r"vireline. Conducted a D7 Surface drill and discussed the responsibiltiesl job assignments. ~leaned out 20" conductor and drilled from 66 ft to 242 ft. Gyroed 20" surface conductor. 1.18 degs Inclination @ 7 degrees Azimuth. Drilled ahead 16" hole trom 242 ft to 333 ft @ 450 GPM! 400 psi. Gyro Surveyed. ("OOOR and picked up MWD and BHA #2. Replaced bolts in Break out Head in Top Drive. Inspected the Derrick . ~limber. Picked the up jars and prepared to drill ahead. Drilled ahead trom 333' to 1198'. Surveying and pumping high-vis sweeps as needed. Performed Gyro Deviation survey. Drilled ahead trom 1198' to 1305', pumping high vis ,-,weeps every other stand. 01/10102 Drilled ahead trom 1305' to 1767', ran a Gyro survey. Drilled ahead from 1767' to 2720'. ReId a planning [ t1eeting on surface cement job. Circulated out sweep in preparation for Gyro. Ran the final Gyro Survey @ 2,720 ft. leld PJSM to rig down wire line. Rigged down wireline sheaves and gyro tool. Drilled ahead trom 2720' to Surface Hole TD of3316'. At 2758' flowrate was increased to 900 gpm. SPP on 2200 pisg I off2100 psig. WOB is 25k. Total ["lOP 145 fph wi 27% time steering and 73% time rotating. No Drag. No Losses.Solids Control equipment coped. ;wept and condition hole, while rotating and reciprocating @900 GPM. Sweep cleaned up the hole. I- 11/11/02 Circulated and conditioned hole @ 900 GPM! 2175 psi. Moved all 13.3/8" handling equipment to rigfloor vhile circulating. POOH five stands. flowcheck. Pump dry job and POOH to BRA. Hole slick- average drag 5- 10 klbs. Laid down MWD, motor and bit- bit in reasonable shape. Cleared rigfloor Rigged up to run 13.3/8" casing. I. tigged up Franks tool and spider elevators. Picked up Tubing Hanger and made up to running tool. Drift Port Collar. _.lad a PJSM for running 13.3/8" casing 13.3/8" shoetrack and check floats- good. Ran 81 joints of 13.3/8" , L-80, BTC, 681b/ft casing. Hole taking some weight @ 3,145'. worked through. [ ~ade up Casing Hanger and Land 13.3/8" with shoe @ 3,296 ft @ 1620 hrs. Rigged down Franks tool and rigged up ..:erhent head and lines. Staged up Pumps to 11 BPM! 400 psi. Attempted to reciprocate- some Overpulls, landed casing. Held PJSM while circulating. Cementers pressure tested to 3500 psig wi SW. Came on line r v/ 10.5 ppg Alpha Spacer. Pump 89 bbls Alpha Spacer(red dye added to spacer), dropped bottom plug and switched ,,0 lead cement. Pumped 100 bbls of lead cement (10.7 ppg) with 50 psig WHP @ 6.0 bpm and 24% flow - full returns. Pumped 485 bbls lead cement, switched to 96 bbls, 15.8 ppg, tail cement. Dropped top plug and kicked out wi r :4 bbls water. Switched to rig pumps and displaced cement @ 100 spm. At 2800 stks, lead cmt to surface. At 4650 ~trokes, bumped plugs to 3000 psig. Bleed off and checked floats- Ok. Prep to N/D riser. 186 bbls of excess cement. Rigged down CMT head and drained riser. I I ! { ( BP Exploration - Northstar NS14 Daily Well Sulnmary 01/13/01 Flushed riser and Rigged down Cement Head and lines. Laid down Vetco Landing Joint. Cleared rigfloor of III casing handling! cementing equipment. Changed out bails on Top drive. Prepared to Nipple down riser and J!repared cellar while resolving leak on Rotary Table Motor. Previous fix had not worked. . (NiPPled down Riser sections. Installed Vetco Multi bowl wellhead and tested to 5000 psi. Took RKB measurements. ~ippled up Single Gate and Mud Cross. Installed BOPE and connected Koomey Hoses. sw~ps: Ensured NS-13 shut in prior to heavey lift. Total time well out of Production = 3 hours. [Tightened up spool and double gate. Tightened turn buckles. Nippled up drilling nipple and installed mouse hole. ~ested BOPE stack to 300/ 4500 psig. AOGCC Representative Jeff Jones out to witness. Tested gas alarms in cellar and in shaker room. AOGCC left the island at midnight- out of hours escort atTanged with 2 hours notice. 1 n/14/02 Continued testing BOPE to 300/4500 psi. No test on shear rams, opened shear ram doors and inspected Karns. Some marks on Wear Plate were noted. (No spare rubber seals on Location for Hydril Shears). Replaced wear olate, closed doors and attempted to test- no go. Changed out Shear Rams to Blind Rams and tested the same to 4500 1 ~si-good test. Tested equipment and installed wear ring. Made up BRA # 3- 12.1/4" Milled tooth assembly. Set Motor and surface test MWDI Motor- OK. TIH wI BHA #3 to cement stringer @ 3160'. Wash and reamed ftorn 3160' to 1213'. Saw some rubber on shakers. MWin = MW out = 8.8 ppg. Pressure tested casing to 3520 psig for 30 mins. [ Jood. Held PJSM for mud swop and had a D2-Drill while waiting holding pressure test. Cement medium- hard. 'faking 10 klbs WOB. Drilled rat- hole cement and new hole f/ 3316- 3332' and started mud swap to sea-water I ")olymer based mud. 01/15/02 Drilled 12.1/4" Hole from 3332 ft to 3336 ft (20 ft new hole) Circulated to even mud weights [.~.9 ppg = 8.9 ppg. Blew down lines. Conducted FIT to 12.6 ppg. 620 psi with 8.9 ppg. 1.8 bbls pump/return. . )irectional Drilled 12.1/4" Hole ftom 3,336 ft to 4,330 ft. Penetration-rates 100-400 ft/hr. Raising flowrate to 850 GPM. No Drag. No Losses. Sweep hole clean at 850 GPMl1850 psi. POOH back to 3,730 ft- Hole swabbing, over (,Ulled 25-30 klbs. Working pipe making no difference to swabbing tendency. Pumped back to 13.3/8" Shoe @ 3,296 . ì. Some over pulls indicating balled up BHA pulling into shoe. Serviced Top drive and greased crown. Unable to work pipe into hole- Packed off. Rotated and found a "sweet spot" and circulated at 730 GPMl1600 psi bottoms up 11dding 10 ppb Walnut Medium plug to clean up BHA- Pump pressured dropped to 1350 psi. RIH. Held up at 3,838 ft. Worked through same. Drilled ahead ftom 4330'-5140' md. Flowrates were increased to 950 gpm over the interval. Total ROP is 157 fph wI 19 % sliding and 81% rotating. I H/16/02 Drilled 12.1/4" hole from 5,140 ft to 6,044 ft. Penetration rates vary fl 100-350 ft/hr. Flowrate at 820 GPM until 5,600 ft because of Pulsation Dampener failure on Number 2 pump affecting real time LWD signal. ( ~.ncreased flowrate to 950 GPM 12400 psi. Some torque was experienced when backreaming on the first 30 ft ( seen )n other wells at this depth). Sweep Hole clean @ 950 GPMl2400 psi. Made wiper trip back to old hole at 4,200 ft. Unable to dry wipe from 4,700 ft to 4,380 ft. Backreamedl worked thru and cleaned hole. Variables 1- ndicated balled BHA. Wiper trip picked on footage drilled. ( Could argue this particular wiper trip can be dropped on lext well and go until bit trip) Drilled and circulated out clay plug which plugged off possum belly. From Bottoms up- probably after reaming. Drilled ahead ftom 6044' to 6426'. ROP varying from 50 fph to 250 fph. I <low rate 950 gpm. Torque on 10-11k. WOB 30k. RPM 100. Angle 38 deg ,. H/16/02_Drilled ftom 6426' to 6899' md (6032' tvd). ROP sporadic (164-70 fph) after midnight. Average penetration lown to 128.6 ftom 134+ fph before midnight. K revs on bit= 477k. Decided pull for PDC bit. Circulated hi-vis sweep surface to surface & monitored the well. POOH (pUW = 240k I SOW= 200 k). No problems tripping out. Hole in I ~ood shape. Inside 13-3/8" shoe, monitored well. Serviced Top-Drive. Installed new safety wires on IBOP bolts. Adjust, fop-drive camera position. Greased crown sheaves. Repaired Top Drive -- 3/8" x 1-1/4" bolt was missing ITom the mo: I I' ¡ I .( -,- ( I BP Exploration - N orthstar NS 14 Daily Well Summary actuator valve assembly. Second valve was found to be loose -tightened remaining and replaced missing bolt. Inspected ( )rive thoroughly for any loose or missing bolts -- none found. TOH. Mechanic and crew started working on replacing Ie }Julsation dampner on Mud Pump#2. Stood back and LD BHA #3. Directional driller graded out bit (12-1/4" Twist and Shout) 1-4-WT-M-E-2-NO-PR. PU BRA #4 (12 -1/4" Hycalog DS69, LWD, & MWD). TIH to 13-3/8" I hoe wi BHA#4. Mechanic while crew was still installing new pulsation dampner on Mud Pump #2. ( ) 1/17/02.. Continued to replace the dampener on MP #2 and cleaned the suction screens. Made connection and shallow tested MWD. Good signal- no noise trom dampener. RIH trom 3297'-6732'. Washed and reamed trom 6732- (6899' (60 rpm, 180 spm, 1850 psig). Perfom bench mark survey and establish PWD baseline. Drill ahead f/ 6899' to '718'. Total ROP= 99.8 fph wi 75% rotating and 25% sliding. Total Flow= 950 gpm, WOB= 10k, SPP on= 2900 deg I Azimth= 296.96 deg. MW= 9.25 ppg change. Drilled ahead f/ 7718' to 8550'. Total ROP= 121 fph wi 85% 15 (liding- Drilled wI Total Flow = 940 gpm and WOB= 14k. 01/18/02 Drilled ahead f/ 8550'-9292'. ART= 4.0 hrsl AST= 5.3 hrs. At 9292'-Torque on is 15k ft-Ibsl Torque off 10 1: ft-lbs. ROT 70 rpm, WOB=15k Ibs, Flow rate= 888 gpm and SPP= 3300 psig. PUW= 265k, SLW= 230 k, RWT= I A5k. Note: At 0700 hrs, Island Muster Drill. Drilled and slid ahead in Colville f/ 9292-9574'. Pump #1 rod oiler not working. Shut-down the pumps and reciprocated stand. Drilled ahead in Colville f/ 9574'-9602'. [01l19/02_Drilled ahead fJ 9602' to 9890', Sliding was difficult. Waited on lubrication re-stock from shore. Slid from I'\zimuth of277.37 deg to 273.42 deg. ROP's were good while rotating. Drilled ahead trom 9890' to 10207'. Slid trom a:imuth of 273.42 deg to 267.91 deg. Steering was improved with baronex spike and added lubrication. MW up to 9.6 ppg for HRZ and continued to wt up to 9.8 ppg for Kuparuk. Top HRZ came in -300' md high @ 10048 md. I n/20102 Continued drilling f/ 10169' to 10565'. Drilled through Kuparuk sands with maximum gas of 2248 units. Kuparuk "C" top was at 10476' MD. At 10565' MD, lost circulation. Perftomed lost circulation procedures with pills I-:omposed ofBarafiber and Walnut Hulls. Slowly started pumps, established circula.tion and received returns. vlonitored well, then drilled ahead to TD at 10930' MD. Circulated Bottoms up with maximum bottoms up gas of 143 units. Began short trip out of hole. I n/21/02 Short trip to 6283', pressure inside drill pipe blew mud all over rig floor. Well was shut in, with no pressure recorded on the annulus. Tripped pipe back to bottom and circulated bottoms up. At 7500 strokes maximum gas was I ecorded at 4019 units, and mud weight increased to 11.9 ppg trom a circulating density of 10.2 ppg. Continued to :irculate a second circulation, with no pit volume gains. On bottoms up trom the second circulation mud weights out were 10.2 ppg and maximum gases were in the 3000 units range. Continued to circulate a third bottoms up. I 11/22/02 Short trip 11 stands to HRZ. Circulate and condition mud system. Pump 25 bbl sweep and pull 13 stands. Pump dry job. Pulled out of hole to 3240' MD. ran in hole to 6259' MD. Circulate bottoms up and condition mud I ~ith maximum gas of 2169 units and mud cut from 10 ppg to 9.3 ppg on nonpressurized scale while reading 11 ppg >n pressurized scales with extremely high funnel viscosity. PH dropped trom 9.2 to 7.8 . After bottoms up from circulating at 6259' MD, gas dropped to a backround of 58 units, while funnel viscosity, pH and mud weight returned I 0 normal readings. Pumped dry job and pulled to 13 3/8" casing shoe. Slipped and cut drilling line. 01/23/02 Finished slipping and cutting drill line. Trip out of hole to surface-OK. Test BOP'S while monitoring well I >n trip tank. Rig up wireline to run e-logs. Run e-logs. I I I i '\ r \ BP Exploration - Northstar NS 14 Daily Well Summary 01/24/02 Conitnue to run in hole with wireline tools to 10200' :MD. Logs would not go down. Lost communications I "ith tools. Rig down wireline. Run in hole with 9 5/8" casing to 13 3/8" shoe to 3300'. Circulate and condition mud . '~ne circulation. Maximum gas seen on circulation 196 units. Continue running 9 5/8" casing into open hole below 13 3/8" shoe. tV25/02 Continie to run in hole with 9 5/8" casing. Max gas of675 units while running casing on returns from (displacement. Tight spot near bottom took 100K weight. Picked up landing joint at 10908'. Circulate and condition 1ud. Started circulating at Y2 BPM and staged up to 10 BPM with maximum gas of 2917 units. Circulated a total of ~500 strokes. Began pumping cement. [ 11/26/02 Pump cement .Displace cement. Bump plug. Rig down and laydown cement head. Change elevators. Install ~ 5/8" packoffand test same to 5000 psi. Hook up kill line and test to 3000 psi. Inject 260 bbls of mud between 13 I 1/8" and 9 5/8". Service top drive, rotary table crown block and sheaves. Pickup BRA #5 and trip in hole, 01/27/02 Trip in hole and tag cement at 10770' :MD. Clean out cement to 10818' :MD. Clean mud pump screens. (Perform casing test to 4300 pso for 30 minutes. Build mud volume. Drill out shoe track from 10818 to 10930' Drill mead to 10950. Perform Formation Integrity Test to 13/5 ppg equivalent. Drill from 10950'. (1/28/02 Drill ahead to 11985' MD. Kingak Top at 11435' MD, 9761' TVD. 01/29/02 Drilled and slid to 10215' :MD. Weighted up mud from 11.4 ppg to 11.8 ppg. Resume drilling to 12480' :MD {+o, tal depth for 7' liner. Pump high viscosity weighted walnut sweep. Short trip to 9 5/8" casing shoe, with some tight opts. Run to bottom, ream through top Sag river. Pump high viscosity weighted walnut sweep. Short trip gas maximum 325 units. Sloughing Kingak shale ( appeared pressured) noticed at bottoms up and increased through ['.eturn of sweep. Decision to trip to 9 5/8" casing shoe and increase mud weight to 12.3 ppg. Top of Sag River at .2459' :MD 10710' TVD. 111/30/02 Circulate and Condition and weight mud up at 95/8" casing shoe to 12.3 ppg. Trip in hole, ream :!Tom 12423 0 12480' :MD. Bottoms up circulation from reaming yielded a maximum short trip gas of86 units. Pump BAROFffiRE sweep. Kingak shales (appeared pressured) still sloughing with increased mud weight. Spot BARO- (l'ROL pill and short trip to 9 5/8" casing shoe. Trip in hole, washing through 17' of fill on bottom. Maximum short rip gas on bottoms up 206 units. Drilled an additional 10' of new rathole to 12490' :MD. Pump wseep. Still seen abundant sloughing Kingak shale on bottoms up. Spot BARO-TROL pill and trip out of hole to run 7" liner. I n/31/02 Trip out of hole to surface. Prepare to run 7" liner. Rig up casing tools. Trip in hole with 7"liner. Work on mud pumps. Continue to trip in hole with 7" liner. I )2/01/02 Trip in hole with 7" liner on 5" drill pipe to 9 5/8" casing shoe. Circulate liner and drill pipe volume. Work on mud pumps. Trip in hole to last stand, wash down last joint. Down to 12475' :MD, staging pumps up tram Y2 BPM I 055 spm. Circulate bottoms up with maximum gas of350 units. No problems with sloughing Kingak shale. Pump .;ement and bump plug as per cementing procedures. Release 5" drill pipe trom liner and circulate bottoms up. Trip out of hole with 5" drill pipe. Change out BOP rams. I )2/02102 Change out BOP rams, Test BOP's. Test 7" liner. Cut and slip drilling line. Make up BHA #6. Pickup 18 stands of 4" drill pipe. Shallow test MWD at 2921' :MD. Freeze protect 9 5/8" x 13 3/8" annulus. I J2/03/02Compiete fteeze protecting 9 5/8" x 13 3/8" annulus. Test killline. Trip in hole. Drill out shoe track and clean out rathole to 12491' :MD. Pump weighted high viscosity spacer. Displace to new 9.1 ppg Drill-In fluid mud. I I I i , BP Exploration -N orthstar NS 14 Daily Well Summary Drill to 12515' Md and perform Formation Integrity Test to 11.3 ppg EMW. Drill from 12515' to 12606' ÑID. Top of r ~hublik at 12563' MD, 10809' TVD. Top of Ivishak at 12653' MD, 10892' TYD. 02/04/02 Drill and slide from 12606' MD to 13020' MD TD. Circulate and raise Mud weight to 9.3 ppg. Short Trip to I "liner shoe. Periodically circulate and monitor well on trip tank while waiting weather (Phase 3 conditions ). I I I I I I I I I ( I ( ( I I I I I Time (hrs) I 01/07/02 1600-1630 I 1730-1900 1900-2000 2000-2130 1 2130-0000 01/08/02 I 0000-0300 0300-0500 0500-0800 I 0800-1000 1000-1200 I 1200-1230 I 1230-1430 1930-2130 I 2130-2300 2300-0000 I ~ 00:00-00:30 I 00:30-02:30 02:30-03 :00 03 :00-04:00 I 04:00-06:00 06:00-07:00 1 07:00-07:30 07:30-10:00 10:00-11:00 1 11:00-11:30 11 :30-22:00 'I 22:00-22:30 22:30-00:00 1 1 ( l BP Exploration - N orthstar NS 14 Daily Operations (I.A.D.C) Elapsed Code Time Operations Breakdown 0.5 1.5 1.0 1.5 2.5 PJSM - Pull service lines from pipe-rack. Prepare rig to skid. Warmup moving hydraulics system PJSM on moving rig. Continue preparing rig for move. Moving rig to NS-14 from NS-9. 3.0 2.0 3.0 2.0 Move rig over the well NS-14. Install stairs around the rig and get heater going in cellar Hook Up service lines to pipe rack and secure lines at NS-09. Clean up rig and berm all areas. Load BHA into pipe shed. Rig accepted @ 0800 hrs on 8th January for NS-14 PJSM with AlC and APC to clear area around NS-09 to facilitate tie in ofNS-09. .. Excellent SIMOPS co-operation. Pre spud Meeting with all Rig Crews and service personnel. Well Objectives and HSE expectations outlined. Continue to clean and berm rig, help with APOC and AlC with well tie NU 20" Riser. Continue to berm rig. Install mouse hole. Lay plywood in cellar. PU BRA # 1 tools to floor and pipeshed. Thaw connections. PU SWS sheaves for GYRO to floor. MU BHA # 1. Conduct D.. 7 Drill. 2.0 0.5 2.0 2.0 1.5 1.0 0.50 2.00 0.50 1.00 2.00 Continue to make up 16" Spud assembly BHA # 1. Rig Up Gyro survey equipment with Schlumberger wireline. Conduct a D7 Surface drill, discuss responsibiltiesl job assignments. Cleanout 20" conductor and drill from 66 ft to 242 ft. Gyro 20" surface conductor. 1.18 degs Inclination @ 7 degs Azimuth. Drill ahead 16'. hole from 242 ft to 333 ft @ 450 GPM/ 400 psi. Gyro Survey POOH and pick up MWD and BHA #2. Replace bolts in Break out Head in Top Drive. Inspect Detrick climber Pick up jars and prepare to drill ahead. Drill ahead from 333' to 1198'. Survey. Pumping high-vis sweeps as needed. Gyro Deviation survey. Drill ahead from 1198' to 1305', pumping high vis sweeps every other stand. 1.00 0.50 2.50 1.00 0.50 10.50 0.50 1.50 I (" ( ( BP Exploration - N orthstar NS 14 I Daily Operations (I.A.D.C) I Time Elapsed Code Operations Breakdown (hrs) Time I 01/10/02 00:00-04:30 4.50 Drill ahead from 1305' to 1767'. I 04:30-05:00 0.50 Run Gyro. 05:00-14:00 9.00 Drill ahead from 1767' to 2720'. Hold planning meeting on surface cement job. I 14:00-14:30 0.50 Circulate out sweep in preparation for Gyro. 14:30-15:30 1.00 Final Gyro Survey @ 2,720 ft. PJSM to rig down wireline. 15:30-16:00 0.50 Rig down wireline sheaves and gyro tool. I 16:00-23 :30 7.50 Drill ahead from 2720' to Surface Hole TD of3316'. At 2758' flowrate was increased to 900 gpm. SPP on 2200 pisS I off 21 00 psig. WOB is 25k. Total ROP 145 fph wi 27% time steering and 73% r time rotating. No Drag. No Losses. Solids Control equipment coped. 23:30-00:00 0.50 sweep and condition hole, while rotating ~d reciprocating.900 GPM. Sweep cleaned up hole. I 01/11/02 00:00-01 :30 1.50 Circulate and condition hole @ 900 GPMl 2175 psi. Move all 13.3/8" I handling equipment to rigtloor while circulating. 01 :30-03:30 2.00 POOH five stands- flowcheck. Pump dry job and POOH to BRA. Hole slick- average drag 5- 10 klbs. [ 03 :30-06:00 2.50 Lay down MWD, motor and bit- bit in reasonable shape. 06:00-06:30 0.50 Clear rigfloor 06:30-08:30 2.00 RID to run 13.3/8" casing. RIU FRanks tool, spider elevators. I 08:30-09:00 0.50 PIU Tubing Hanger and M!U to runing tool. Drift Port Collar. 09:00..09:30 0.50 PJSM for running 13.3/8" casing 09:30-10:30 1.00 13.3/8" shoetrack and check floats- good. I 10:30-16:00 5.50 Run 81 joints of 13.3/8t! , L..80, BTC, 68lb/ft casing. Hole taking some weight @ 3,145'- work through. 16:00-16:30 0.50 MIU Casing Hanger and Land 13.3/8t! with shoe @ 3,296 ft @ 1620 hrs. I 16:30-18:00 1.50 RID Franks tool and R/U cement head and lines. 18:00-20:00 2.00 Stage up Pumps to 11 BPMl 400 psi. Attempt to reciprocate- some overpulls. Land casing. Hold PJSM while circulating. I 20:00-23 :30 3.50 Cementers PT to 3500 psiS wI SW. Come on line wI 10.5 ppg Alpha Spacer. Pump 89 bbls Alpha Spacer(red dye added to spacer), drop btm plug and switch to lead cement. Pumped 100 bbls of lead I cement (10.7 ppg) with 50 psiS WHP @ 6.0 bpm and 24% flow - full returns. Pumped 485 bbls lead cmt, switch to 96 bbls, 15.8 ppg, tail cement. Drop top plug and kick out wI 24 bbls water. Switch to rig I pumps and displace cement @ 100 spm. At 2800 stks, lead emt to surface. At 4650 strokes, bump plugs to 3000 psiS. Bleed off and I check floats- Ok. Prep to NID riser. 186 bbls of excess cement. 23 :30-00:00 0.50 Rig down CMT head. Drain riser. I I I r r r r I [ I I [ I I [ I I I I I ( f BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 01/12/02 00:00-01 :00 01 :00-01 :30 01 :30-02:30 02:30-04:00 04:00...06:00 06:00-08:00 08:00...09:00 09:00-10:00 .10:00-13:00 13:00-17:00 17:00-00:00 1.00 0.50 1.00 1.50 2.00 Flush riser and RID Cement Head and lines. Lay down Vetco Landing Joint Clear rigfloor of all casing handling! cementing equipment. Change out bails on Top drive. Prepare to Nipple down riser and Prepare cellar while resolving leak on Rotary Table Motor. Previous fix had not worked. Nipple down Riser sections. Install Vetco Multi bowl wellhead and test to 5000 psi. Take RKB measurements. Nipple up Single Gate and Mud Cross. Install BOPE and connect Koomey Hoses. SIMOPS: Ensure NS-13 shut in prior to heavey lift. Total time well out of Production = 3 hours. Tighten up spool and double gate. Tighten turn buckles. NO drilling nipple and install mouse hole. Test BOPE stack to 300/4500 psig. AOGCC Representative Jeff Jones out to witness. Test in gas alarms in cellar and in shaker room. AOGCC left the island at midnight- out of hours escort arranged with 2 hours notice. 2.00 1.00 1.00 3.00 4.00 7.00 ~ 00:00-00:30 0.50 00:30-05 :30 5.00 05:30-09:00 3.50 09:00-12:00 3.00 12:00...14:00 2.00 14:00-16:30 2.50 16:30...17:30 1.00 17:30-19:00 1.50 19:00-19:30 0.50 19:30-22:00 2.50 22:00-00:00 2.00 Continue testing BOPE to 300/4500 psi. No test on shear rams. Open shear ram doors and inspect Rams. Some marks on Wear Plate. (No spare rubber seals on Location for Hydril Shears). Replace wear plate ~ close doors and attempt to test- no go. Changeout Shear Rams to Blind Rams and test same to 4500 psi-good test. test equipment and install wear ring. M/U BRA # 3- 12.1/4" Milled tooth assembly. Set Motor and surface test MWD/ Motor- OK. TIH wI BHA #3 to cement stringer @ 3160'. Wash and ream from 3160' to 3213'. See some rubber on shakers. MWin=MW out = 8.8 ppg. PT casing to 3520 psig for 30 mins. Good. Hold PJSM for mud swop and and have D2-Drill while waiting holding PT. Cement medium.. hard. Taking 10 klbs WOB. Drill rat- hole cement and new hole f/ 3316- 3332' ~d start mud swap to sea-water polymer based mud. I I I I I I ( I I I I I I I I I I I I ( ( BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 01/14/02 00:00-00:30 00:30-01 :00 01 :00-01 :30 01 :30-10:30 10:30-11 :00 11 :00-12:00 12:00-13:00 13:00-14:00 14:00-15:30 15:30-16:30 16:30-00:00 01/15/02 00:00-11:00 11 ;00-12:00 12:00-16:30 16:30-17:00 17:00-00:00 0.50 0.50 0.50 9.00 Drill 12.1/4" Hole fto 3332 ft to 3336 ft ( 20 ft new hole) Circulate even weights 8.9 ppg = 8.9 ppg. BID lines Conduct FIT to 12.6 ppg. 620 psi with 8.9 ppg. 1.8 bbls pump/return. Directional Drill 12.1/4" Hole ftom 3,336 ft to 4,330 ft. P-rates 100-400 ft/hr. Raising flowrate to 850 GPM. No Drag. No Losses. Sweep hole clean at 850 GPM/ 1850 psi. POOH back to 3,730 ft- Hole swabbing, overpull 25-30 klbs. Working pipe making no difference to swabbing tendency. Pump back to 13.3/8" Shoe @ 3,296 ft. Some overpulls indicating balled up BHA pulling into shoe. Service Top drive and grease crown. Unable to work pipe into hole- Packed off. Rotate and find a "sweet spot" and circulate at 730 GPMI 1600 psi bottoms up adding 10 ppb Walnut Medium plug to clean up BHA- Pump pressure dropped to 1350 psi. RIH. Hold up at 3,838 ft. Work through same. Drill ahead ftom 4330'-5140' md. Flowrates were increased to 950 gpm over the interval. Total ROP is 157 fph w/ 19 % sliding and 81% rotating. 0.50 1.00 1.00 1.00 1.50 1.00 7.50 11. 00 Drill 12.1/4" hole from 5,140 ft to 6,044 ft. P-rates vary f/ 100-350 ft/hr. Flowrate at 820 GPM unti15,600 ft because of Pulsation Dampener failure on Number 2 pump affecting real time LWD signal. Increase flowrate to 950 GPM /2400 psi. Some torque when backreaming on first 30 ft ( seen on other wells at this depth). Sweep Hole clean @ 950 GPMI 2400 psi. Make wiper trip back to old hole at 4,200 ft. Unable to dry wipe from 4,700 ft to 4,380 ft. Backream/ work thru and clean hole. Variables indicate balled BHA. Wiper trip picked on footage drilled. ( Could argue this particular wiper trip can be dropped on next well and go until bit trip) Drill and circulate out clay plug which plugged off possum belly. From Bottoms up- probably after reaming. Drill ahead from 6044' to 6426'. ROP varying from 50 fph to 250 fph. Flow rate 950 gpm. Torque on 10-11k. WOB 30k. RPM 100. Angle 38 des 1.00 04.5 0.5 7.00 I r r r I I r I I I r I I I I r I I I (' (' BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 01/16/02 00:00~07:00 07:00~08:30 08:30~11 :00 11 :oo~ 12:30 12:30~14:30 7.00 Drill from 6426' to 6899' md (6032' tvd). ROP sporadic (164-70 fph) after midnight. Average penetration down to 128.6 from 134+ fph before midnight. K revs on bit= 477k. Decide pull for PDC bit. Circulate hi-vis sweep surface to surface & monitor well. POOH (pUW = 240k I SOW= 200 k). No problems tripping out. Hole in good shape. Inside 13-3/8" shoe, monitor well. Service Top-Drive. Install new safety wires on mop bolts. Adjust Top-drive camera position. Grease crown sheaves. Repair Top Drive -- 3/8" x 1~1/4" bolt was missing from the mop actuator valve assembly. Second valve was found to be loose ~,. tightened remaining and replaced missing bolt. Inspected Top Drive thoroughly for any loose or missing bolts ~- none found. TOH. Mechanic and crew start working on replacing leaky pulsation dampner on Mud Pump#2. Stand back and LD BHA #3. Directional driller graded out bit (12-1/4" Twist and Shout) 1-4-WT-M-E-2-NO-PR. PU BHA #4 (12 -1/4" Hycalog DS69, LWD, & MWD). Till to 13-3/8" shoe wi BHA#4. Mechanic and crew still installing new pulsation dampner on Mud Pump #2. 1.50 2.50 1.50 2.00 14:30-16:30 2.00 16:30-19:30 3.00 19:30-22:30 3.00 22:30-00:00 1.50 !!lIt? IO~ 00:00-01 :00 01:00-01 :30 01:30-03:00 03:00-03:30 03:30-04:30 04:30-12:00 12:00-00:00 1.00 0.50 Continue to replace dampner on !vIP #2. Clean suction screens. Make connection and shallow test MWD. Good signal- no noise from dampner. RIH from 3297'-6732'. Wash and ream tram 6732 - 6899' (60 rpm, 180 spm, 1850 psig). Perfom bench mark survey and establish PWD baseline. Drill ahead f/ 6899' to 7718'. Total ROP= 99.8 fph wi 75% rotating and 25% sliding. Total Flow-- 950 gpm, WOB= 10k, SPP on= 2900 psigl SPP off-- 2600 psig. Torque on 12,000 ft-Ibs. Inclination =37.56 deg I Azimth= 296.96 deB. MW= 9.25 ppg. change. Drill ahead f/ 7718' to 8550'. Total ROP= 121 fph wI 85% 15 sliding. Drilling wi Total Flow = 940 gpm and WOB= 14k. 1.50 0.50 1.00 7.50 12.00 I I I I I I I [ I I I [ I I [ I I I [ ( ( . BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time ... Operations Breakdown 01/18/02 00:00-12:00 12:00-19:00 19:00-21:00 21 :00-00:00 ~ 00:00-12:00 12:00-00:00 12.00 7.00 2.00 3.00 12.00 12.00 01/20/02 00:00-08:00 8.00 08:00-08: 15 0.25 08: 15-08:30 0.25 08:30-09: 15 09: 15-11:00 11 :00-17:30 17:30-19:00 19:00-00:00 0.75 1.75 6.50 1.50 5.00 Drill ahead fJ 8550'-9292'. ART= 4.0 hrs/ AST= 5.3 hrs. At 9292'-Torque on is 15k ft-Ibs/ Torque off 10 k ft-Ibs. ROT 70 rpm, WOB= 15k lbs, Flow rate= 888 gpm and SPP= 3300 psig. PUW= 265k, SLW= 230 k, RWT= 245k. Note: At 0700 hrs, Island Muster Drill. Drill and slide ahead in Colville f/ 9292-9574'. Pump #1 rod oiler not working. Shut-down pumps and reciprocate stand. Drill ahead in Colville f/ 9574'-9602'. Drill ahead f/ 9602' to 9890'. Sliding has been difficult, waiting on lubrication re-stock from shore. Slide from azimuth of277.37 deg to 273.42 des. RQP is good when rotating. Drill ahead from 9890' to 10207'. Slide from azimuth of 273.42 des to 267.91 deg. Steering has improved with baronex spike and added lubrication. MW up to 9.6 ppg for HRZ and continue to wt up to 9.8 ppg for Kuparuk. Top HRZ came in -300' md high @ 10038 md. Drill f/ 10207-10566' md. Reach final inclination and azimuth @10500'. Rotating ahead to casing point TD. ECD Spike to 12.5 ppg. Reduce rate and work pipe. PU Wt increased f/ 305k to 335k Est rotation. Circulate and condition mud. Lost full returns. Shut down pumps and monitor well-- well is static. Move pipe while observing backside-no swabbing. Condition mud and circulate-- monitor returns. Slowly regain returns while pumping 1 bpm and gradually increase to 4 bpm. Pump LCM 25 bbls. barofiber and walnut. Condition mud and circulate-- monitor returns. Increase pump rate trom 4 bpm to 12 bpm. Shut down pumps. Monitor..- ok. Condition mud & circulate-- increase rate to 19 bpm. Drill ahead from 10556 to 10930' md--casing point TD. No losses. Circulate sweep. Pull 5 stands. Pump dry job. Pull next 10 stands. I I r I I I" I I I I I I I I I I I I I ( ( BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 01/21/02 00:00-02:00 02:00-05:00 05:00-07:00 07:00-08:00 08:00-10:30 10:30-14:00 14:00-16:30 16:30-19:0Q 19:00..20:00 20:00-21 :00 21 :00-22:00 22:00-00:00 ~ 00:00-04:30 04:30-07:00 07:00-15:00 15:00-15:30 15:30..18:00 18:00..19:30 19:30-22:00 22:00-00:00 2.00 3.00 Continue Wiper trip to 6282' (Stand 55). Stand #55 wet. Broke out stand, mud continued to flow. Stab TIW Valve & Shut-in annular preventer. SIDPP= 180 psig. No pressure on backside. Bleed DP to zero through bleed line. Open choke and verify zero pressure. Monitor. Open annular preventer. Drop dart valve. Thaw frozen mud pump out side line (-34 below ambient). Fill DP and annulus-well taking fluid--suspect seepage into Schrader and Top ofUgnu after wiper trip. Rih w/3 stands to 6575' md. Bell nipple air boot leaking. Install TIW -- Replace arir boot in scoping bell nipple. RIH. Fill DP every 12- stds to 9486' md. Change out top drive oiler motor. Continue RIH to 10838' md. Backside burping gas. SI annular preventer-.. no pressure. Circulate through choke to remove gas bubble. Note: Mud returns dehydrated--l1.5..12.2 ppg, non-pressured scale. SD pumps-- no pressure, no flow. Open annular preventer. Circulate and condition mud. RIH to TD @ 10930 md. Circulate and condition mud. Note: Background gas ranging from 700 units to 3400 units through-out 2 bottoms-up circulations. Final background gas ranging approximately 3000 units. 2.00 1.00 2.50 3.50 2.50 2.50 1.00 1.00 1.00 2.00 4.50 Wiper trip - pumped out 11 stands to top ofHRZ. Note: Necessary to pump and ream to get past HRZ and necessary to pump and ream to get last stand in to TD. Circulate & condition mud / hole. Rotate & reciprocate. Pump 25 bbl barofiber sweep. Note: Background gas decreased from -1500 - 2500 units to -200 units. POH 13 stands. Pump dry job & blow down mud lines. Continue POH from 6540' - 3240'. Overpull was 50 to 75K over in places. Note: Decision to make a circ and cond run to 6200' md to enhance logging run. Clean floor & monitor well. RIHto 6259'. Circulate 2 x BU. Note: Max. gas 2100 units final background gas between zero and 50 units. POH to 13 3/8" casing shoe. Monitor well. PJSM .. Slip & cut drilling line. 2.50 8.00 0.50 2.50 1.50 2.50 2.00 I I r r r r I r r r r r I I r r r r I ( ( BP Exploration - N orthstar NS 14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 01/23/02 00:00-02:00 02:00-06:00 06:00-07:30 07:30-14:30 14:30-15:30 15:30-17:00 17:00-18:00 18:00-21:00 21 :00-00:00 ~ 00:00-02:00 02:00-04:30 04:30-06:00 06:00-09:30 09:30-10:00 10:00-11:00 11 :00-11:30 11 :30-12:00 12:00-13:00 13:00-00:00 2.00 4.00 1.50 7.00 1.00 1.50 1.00 3.00 3.00 2.00 2.50 1.50 3.50 0.50 1.00 0.50 0.50 1.00 11. 00 POH wI DP & HWDP. Clean out Anadrill tools with mud pumps & ftesh water, blow down mud pump line, & LID BHA. Clear & clean rig floor. PIU test jt, pull wear bushing, set test plug, tie in trip tank to annulus, test BOP's, & set wear bushing. Clean floor & PJSM for logging. RID wireline loggers. Load source to run logs. RllI with platform express & dipole sonic log. Work through obstruction at 6271'. Could not work through obstruction at 6485', POH to remove bow type centralizer and rerun. RllI with log. Tight spots at 6485', 6962', 7249', 9286', 9487', & 10200'. Did not get past 10200' and lost signal at 9487'. Note: Cable failure due to tough hole conditions. DF AL determination to log this interval. The wireline cable was damaged in 2 places above the wireline socket. Communication with tool was lost while trying to work through a tight spot at 9487' md. Were able to get thru this spot and attempted to get to TD prior to POOH eventhough there was no communiction with tool. Stacked up at 1 0200. Stuck tool at 9350' md while POOH -- the distance between the wireline tool to the damaged cable was equal to the distance between the trouble at 9487' md where tool quit and the tight spot at 9350' rod. Suspect there is a ledge at 9350' md and the wireline was slapping against this while working the tool thru the trouble spot at 9487' md. Cut wireline, reconnect and test tools -- all systems working. RD Schlumberger Wireline and tools. PU Casing Tools to Rig Floor and LD 12-1/4" BHA out of derrick. Pull Wear Ring LD elevators and bails and pull floor plate. PJSM for RU Franks Casing Fillup Tool -- Developed procedure with Franks Rep, NAD Casing Operator, Rig Crew, Tool Pusher, NAD DrIg Supt and Drilling Rep -- Pemomed Hazard Analysis Checklist. Rig Up Franks Casing Fill Up Tool. Make up long bails, RU spider and elevator. Function test 9-5/8" casing rams in lower set of pipe rams -- Witnessed by DrIg Rep. RllI with 110 joints of 9-5/8" 47# L80 ModBtrc Casing. Notes: 1. Circ thru float equipment with Franks tool to check floats after MU joint 3. I f f BP Exploration - Northstar NS14 I Daily Operations (I.A.D.C) I Time Elapsed Code Operations Breakdown (hrs) Time I 2. Running speed predicated by trip tank results. 3. Hole taking,..., 1.5 bbls per hour prior to running casing. I 01/25/02 00:00..14:30 14.50 At 10,722' casing stacked out to lOOk. Pulled 550K & could not pull I casing. Slacked off in preparation to pull to 600K & casing fell through tight spot. No other difficulties running casing to TD. 14:30..15:00 0.50 PIU landing jt. & hangar. Land casing @ 10908'. I 15:00..15:30 0.50 RID & LID Frank's fill up tool. 15:30..16:00 0.50 RJU cement head. 16:00-21 :00 5.00 Condition mud and circulate one casing volume -- 1.25 times bottoms I up. Notes: 1. Start circulation at 1/2 bbl. per minute, increasing incrementally I until 10 bpm was achieved. 2. PJSM for cement job was held while circulating. 3. Background Gas throughout circulation peaking at 2850 units. I Reduced 500 units when circulating was complete. 3. Lost 50 bbls. while circulating. 21:00-23:00 2.00 Pressure test cement lines to 3500 psi, pump 75 bbls. of spacer, r drop bottom plug, pump lead & tail cement. See cement report for details. 23 :00-00:00 1.00 Displace cement with rig pumps @ 10 bpm. I 01/26/02 00:00-00:30 0.50 Displace cement. Bumped plug with 9284 stks. (94% pump efficiency I + 1/2 shoe track volume - calculated) Halliburton flow meter & Epoch stroke counter in synchronization with each other barrel for barrel. I 00:30-01 :00 0.50 LID cement head & landing jt. 01:00-03:00 2.00 C/O elevators. PIU 1 stand HWDP & install 9 5/8" packoff. Test to 5,000 psi & bled off. Left 5,000 psi on plastic packing. Stood back I HWDP stand. PI U test joint and set bowl protector. Began bullheading mud down 13 3/8" x 9 5/8" annulus at 1/2 bpm once packoff was landed & tested. I 03:00-06:00 3.00 LID casing tools, change bails, & clear rig floor of tools. 06:00-12:00 6.00 Remove floor mats & plates around rotary table and clean. Pull rotary table and change seal on motor. Replace table, floorplates, clean & I replace mats. 12:00-13:00 1.00 Change sweep from lower to upper annulus. 13:00..17:00 4.00 Warm up, drain, flush and replace gear oil in top drive gear box. I Service top drive, crown, block, and sheaves. 17:00-18:00 1.00 P IV mud motor - LID same. Break sleeve off of motor .. sleeve too big. 8.625 I I I [ [ I I I I I ( [ I ( I I I I I I ( ( BP Exploration - N orthstar NS 14 Daily Operations (I.A.D.C) Time Elapsed Code (hrs) Time 18:00-21 :30 3.50 21 :30-22:00 0.50 22:00-00:00 2.00 01/27/02 00:00-05:30 5.50 05:30-09:30 4.00 09:30-10:00 10:00-11 :00 11 :00-12:00 12:00-13:00 13:00-16:00 16:00-16:30 16:30-19:30 19:30-20:30 20:30-22:00 22:00-22:30 22:30-00:00 01/28/02 00:00-00:00 ~ 00:00-10:00 Operations Breakdown MlUBHA# 5. Test MWD @ 1016.83'. RllI wI 5" DP filling every 25 stands. 0.50 1.00 RllI ftom 3400' to 10770'. Fill pipe every 25 stands. Tag cement stringers @ 10770'. Clean out cement to top ofplugs @ 10,818'. Notes: Plugging off suction screens on mud pumps due to additives in mud not shearing properly. Both hoppers were being utilized simultaneously to mix 17.0 spike fluid & new 9.8 mud. The hopper being utilized to mix the 9.8 mud is not a shear hopper. The polymer created "fish eyes" and the Desco created clumps and plugged off screens. Problem solved by stopping the mixing of spike fluid and lining up # 1 pit on Vortrex Hopper and sheared. Highly recommend this hopper be replaced with another Vortex hopper. Pump up & hook up sensors for casing test, Test casing to 4,300 psi & hold for 30 minutes. Discuss well control while waiting on casing test. Process leak occured when drain plugged in pipe set back and 30 gallons of drilling fluid spilled over lip into cellar area -- Had Spill Drill to assemble crews and clean up. Notes: Called ACS technician immediately to visually inspect the incident. Safety stand down. Clean cellar area. Blow down all mud lines & kill line. Thaw bleed off line. Calibrate mud pump gauges. Drill out shoe track from 10,818' to 10930'. Circulating hole clean. Packing off & high torque while drilling rathole -- picked up and circulated. This occurred in during NS09 also. Drill ftom 10,930' to 10950'. Perform FIT to 13.5 EMW. Drill from 10,950' to 11,000' 1.00 1.00 3.00 0.50 3.00 1.00 1.50 0.50 1.50 24.00 Drill & slide from 11,000' to 11,891' MD. 10.00 Drlg f/ 11891' to 12423' md. Note: Sliding less than optimal -- unable to access total lubricants. Zoom Boom was not working -- rented one ftom Deadhorse but did not arrive island until late. Working with AlC and N AD loaders to I ( ( tiP Exploration - Northstar NS14 I Daily Operations (I.A.D.C) I' Time Elapsed Code Operations Breakdown (hrs) Time 1 coordinate unloading of mud product for easier access. 10:00-11:00 1.00 Circulate and Condition Mud while weighting up -- attempting to circ I and rotate at 120 rpm to determine if barite falling out -- not the case. 11 :00-12:00 1.00 Clean out suction screen. 12:00-13:30 1.50 Ddg f/ 12423' - 12480' md. 1 13 :30-15:00 1.50 Pump Sweep while Circ and Cond Mud. 15:00-18:30 3.50 Wiper Trip to 9-5/8" csg shoe @ 10908' md. Notes: Tight on bottom across Sag and Pulled 40K over at various I points which wiped clean. Rathole under 9-5/8" casing was ratty. 18:30-21 :30 3.00 Pump Hi Vis Weighted Sweep and Circ and Cond for running liner. Notes: I 1. Signs of splintered shale in BU and more signs of splintered shale in weighted fiber sweep. Splintered shale in returns after sweep. 2. Discussion with Core Rig Team and Anchorage team -- Decision I to Weight up 0.5 ppg to 12.3 ppg. 21:30-22:30 1.00 Trip to shoe for weight up to prevent washing out hole while circ and weighting up. I 21 :30-00:00 2.50 Circ while weighting up trom f/ 11.8 to 12.3 ppg. !U/30/02 I 00:00-03:30 3.50 Circulate just below the shoe while increasing MW from 11.8 ppg to 12.3 ppg. 550 GPM/ 2100 psi 03 :30-04:30 1.00 RIH trom 10911' to 12423'. I 04:30-05:30 1.00 Ream tight hole trom 12423' to 12458'. Tag fill at 12458' & clean out to 12480'. First tagged fill @ 12,430 ft. 05:30..08:30 3.00 Circulate & reciprocate 60'. Pump barafiber sweep. I Splintered shales coming across shakers throughout 2.5 x BU. 08:30-10:30 2.00 Circulate, rotate @ 60 RPM, & reciprocate 60'. Spot Barotrol pill. 10:30-12:00 1.50 Blow down top drive mud lines & start to POH. I 12:00-13:00 1.00 Continue POR to shoe @ 10,908'. Work thru tight spot @ 12,400 ft. Wipe out. 13:00-14:30 1.50 Service top drive and monitor well. I 14:30-15:30 1.00 RIH to 12,463' & tag fill 17 ft off bottom. 15:30..16:00 0.50 Wash down & ream trom 12,463' to 12,480'. 550 GPM .. 60 RPM - 2000 PSI I 16:00-16:30 0.50 Drill from 12,480' to 12,490' 16:30-19:30 3.00 Circulate sweep & clean hole. Spot Baratrol pill. 19:30-21 :30 2.00 POH to 9.5/81t shoe @ 10,950 ft. I Tight spot at 12,405' to 12,395 ft. ( Same as previous trip). Work thru and wipe out. Overpulls up to 50 klbs. 21 :30-22:30 1.00 Monitor well @ shoe, pump dry job, & blow down top drive & mud I line. 22:30-00:00 1.50 Drop 2.375" rabbit & continue POH. I I I I I I [ I I I I I I I I I I I I I (- ( BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 01/31/02 00:00..04:30 04:30-06:00 06:00..07:30 07:30-09:00 09:00-09:30 09:30..13:00 13:00-14:00 14:00-16:00 16:00-23:00 23:00-00:00 02/0t/02 00:00-02:00 02:00-04:30 4.50 1.50 1.50 1.50 0.50 3.50 POOH 5" drillpipe to 1017 ft (top ofHWDP) POOH 5" HWDP Lay down 8.1/2" BHA. Bit in good shape. Clear rigfloor and R/U to run 7" Liner. Conduct PJSM for running 7" liner. Make up 7" shoetrack and check floats.. good. Run 42 joints of7", 26 lblft, BTC Mod. Make up Liner Hanger. Up/ Down weight 103 klbs. Clear rigfloor. Attempt to circulate- no go. Pumps unable to generate pressure despite confirmation of charge. Stroking, but not pumping. Double check all surface lines. No obvious problems detected. Conduct PJSM with Halliburton and elect to fill pipe with HOWCO while troubleshooting pumps. RIH on 5" drillpipe filling every 11 stands with halliburton to 9,000 ft while stripping down pumps- establish solids/ contaminates throughout circulating system and in particular at fluid end of pumps. Halliburton finding drilling solids at their end when sucking mud from rig causing problems at his end. Continue to RllI on 5" drillpipe filling pipe with mud pumps. 1.00 2.00 7.00 1.00 2.00 2.50 Run in hole with 7" liner to 10,845 ft.- Just above 9.5/8" shoe. Circulate 1.5 times Liner and string volume @ 6 BPM/ 700 psi. Up weight 280 klbs, down weight 225 klbs. Ensure Mud pumps clear of debris before Running into open hole. Make up Liner cement head to stand of drillpipe and stand back in derrick. Run into open hole. Start stacking weight @ 11,700 ft (Top Kingak @ 11,460 ft). Taking 30 - 125 klbs but making forward progress. Make up Cement Head and hook up circulating lines with shoe @ 12,420 ft. Attempt to circulate.. no go. Pipe free between 12,460 ft and 12,475 ft. Work fluid path and gradually raise rate to 5 BPMl840 psi circulating bottoms up. Fill @ 10,475 ft- unable to wash out. Could not take rate higher than 5 BPM- pack-off. Up weights sometime @ 425 klbs. No sh~le splinters on BU. Pump 50 bbls Alpha spacer. 75 bbls of 15.9 ppg G Slurry(281 sacks) @ 5 BPM/ 1100 psi. Observe dart released. Displace with rig pumps. At final stroke count for plug bump ( 2950 strokes for 251 bbls @ 96% effieciency) observe Plug latch- Go by Howco flowmeter and continue pumping ignoring pump strokes. Observe cement climbing. 13 bbls trom bump packed off and stuck liner. Squeezed fluid away and observe plug bump to 3500 psi. 04:30..05:30 1.00 05 :30-06:30 1.00 06:30..07:00 0.50 07:00-10:30 3.50 10:30-12:00 12:00-13:30 1.50 1.50 I ' ( \ BP Exploration - Northstar NS 14 I Daily Operations (I.A.D.C) I Time Elapsed Code Operations Breakdown (hrs) Time I Check floats. (Mud Pump efficiency works out at 70%!) 13:30-14:00 0.50 Set Packer and back out of liner- good indication. I 14:00-15:00 1.00 Circulate bottoms up @ 18 BPM/ 3500 psi. Observe cement contaminated mud on bottoms up for approximately 90 bbls. 15:00-17:00 2.00 Lay down cement head and break all service connections. I 17:00-22:00 5.00 POH w/ DP & liner / hangar running tool. Tested choke manifold while POH. 22:00-22:30 0.50 Make service breaks on Baker running tool & LID. I 22:30-00:00 1.50 PJSM. Change out blind rams for shear rams. 02/02/02 I 00:00-03:30 3.50 Pull blind rams & replace with shear rams. Install 5 1/2" rams. 03 :30-04:30 1.00 Pull bowl protector & install test plug. 04:30-05:00 0.50 R/U test equip't & fill stack. [ 05:00-10:00 5.00 Test BOP's 250 psi / 4500 psi 5 / 10 minutes. 1 0: 00-11 : 00 1.00 Blow down lines, pull test plug, & install bowl protector. 11 : 00-11 : 3 0 0.50 Test 7" liner to 3200 psi & hold for 30 minutes. okay I 11:30-14:30 3.00 PJSM - cut & slip drilling line. 14:30-15:00 0.50 Adjust brakes & inspect all lines in drum. 15:00-18:00 3.00 M/U BHA #6. (PJSM -load source 1/2 hour) [ 18:00-18:30 0.50 PIU 430' HT HWDP. 18:30-19:00 0.50 PIU 4" HT 40 from pipeshed. 19:00-19:30 0.50 Move 5" HWDP out of way in derrick to access 4" HT 40. I 19:30-20:00 0.50 Reinstall crown saver. 20:00-21 :00 1.00 RIH w/ 4" HT 40. 21 :00-21 :30 0.50 C/O to 5" elevators, M/U x-over & dart sub, & RIH with 1 stand of 5" I DP. 21:30-22:00 0.50 PJSM on freeze protecting 13 3/8" x 9 5/8" annulus. 22:00-22:30 0.50 Surface test MWD @ 2924'. okay I 22:30-00:00 1.50 Freeze protect 13 3/8" x 9 5/8" annulus. 02/03/02 I 00:00-01 :30 1.50 Freeze protect 13 3/8" x 9 5/8" annulus. Pumped 117 bbls @ 1 BPM. Final pressure 830 psi. 01:30-02:00 0.50 BID & test kill line. I 02:00-08:30 6.50 RIH to 12,338' - fill every 40 stands. 08:30-09:00 0.50 Fill DP & wash down to 12,382" 09:00-11 :00 2.00 Drill out shoe track & clean out rat hole to 12490' @ 340 GPM/ 3000 I psi. Cement reasonably hard. 11 :00-14:00 3.00 PJSM - Displace 12.3 mud w/ new 9.1ppg mud. 14:00-16:00 2.00 Clean L pits. Thaw out frozen lines on trip tank. ( - 70degs windchill) I 16:00-17:00 1.00 Drill from 12,490' to 12,515' l\.1D. 17:00-17:30 0.50 Circulate 15 minutes & POH with 1 stand and rack back. 17:30-18:00 0.50 Perform FIT test to 11.3 EMW with 9.2 ppg mud. (1170 psi) I I I I ( ( I ( ( ( ( ( ( ( I I I I I I , I ( t BP Exploration - Northstar NS14 Daily Operations (I.A.D.C) Time Elapsed Code (hrs) Time 18:00-18:30 0.50 18:30-00:00 5.50 02/04/02 00: 00-12: 3 0 12.50 Operations Breakdown Blow down kill line. Drill from 12,515' to 12,610'.340 GPM / 1700 psi. RPM @ 80. 23:00-00:00 1.00 Drill from 12610' to 13,020 MD. TD 340 GpMJ 1900 psi. 80 RPM/ 13 kftlbs ART 8.0 hrs. AST 1.0 hrs. Condition mud & circulate for short trip. POH to 7" shoe. Hole slick. PJSM. Shut down Operations and discuss hazards. Monitor well & wait on weather. Phase 3 conditions slope wide. Winds ranging from 30 - 50 mph with gusts up to 65 mph. Took advantage of the opportunity by cleaning rig, relocating BOP test pump to trip tank area from rig floor, and updating a few procedures. Condition & circulate mud @ 40 SPM / 40 RPM while reciprocating pipe inside shoe. 12:30-14:30 14:30-15:00 15:00-23:00 2.00 0.50 8.00 I I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY :¡ Depth (MD) 10476 to 10530 ft (1VD) 8927 to 8973 ft Show Report No. .......!.... Datemme: 1/19/2002 19:00:00 AM :¡ Zone Production Analysis (From Steam-Still PPM Ratios) The production of this zone is deemed to be GAS / 01 L . At approximately - contact ( and a I contact at approximately feet) for a total of feet of feet of show). I % Depth 10500 ft Gas I!jUnits 1272 Mud Chlorides (ppm) = ---~õvvTíriië-------~-ucnCiñ-------~nCivv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 40.5 - 6.315 = 34.2 C2 5.0 - 1.115 = 3.90 C3 3.270 - 0.956 = 2.314 C4 1.999 - 1.006 = 0.993 C5 1.387 - 0.931 = 0.456 --Þrõërüëtiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 % Depth 10520 ft Gas x Units 1345 Mud Chlorides (ppm) = ---~õvvnilë-------~ücnCiñ-------~nCivv-~---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 53.2 - 6.315 = 46.8 C2 7.46 - 1.115 = 6.35 C3 5.63 - 0.956 = 4.67 C4 5.999 - 1.006 = 4.993 C5 4.079 - 0.931 = 3.148 --Þrõërüëtiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 % Depth ft Gas x Units Mud Chlorides (ppm) = ---F1õvvríriië-------~-ücfíc)ñ-------~në)vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 0.0 - 0.000 = 0.0 C2 0.00 - 0.000 = 0.0 C3 0.00 - 0.000 = 0.0 C4 0.000 - 0.000 = 0.0 - C5 0.000 - 0.000 = 0.0 --~õërüëtiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 4 % Depth ft Gas x Units Mud Chlorides (ppm) = ---~õvvTíriië-------~¡¡cnCiñ-------~në)~------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 0.0 - 0.000 = 0.0 C2 0.00 - 0.000 = 0.00 C3 0.000 - 0.000 = 0.000 C4 0.000 - 0.000 = 0.000 C5 0.000 - 0.000 = 0.000 --Þrõërüëtiõñ---------------------------------------------------------------------------- Analysis IXIGas nOil nWater nNon-Producible Hydrocarbons I Hydrocarbon Ratios C1/C2 = 8.8 C1/C3 = 14.8 C1/C4 = 34.4 C1/C5 = 75.0 I I ( Hydrocarbon Ratios C1/C2 = 7.4 C1/C3 = 10.0 C1/C4 = 9.4 C1/C5 = 14.9 [ I I I Hydrocarbon Ratios C1/C2 = ##### C1/C3 =##### C1/C4 =##### C1/C5 =##### I I I Hydrocarbon Ratios C1/C2 =##### C1/C3 = ##### C 1/C4 = fI:#### C1/C5 = ##### I I I 1000.0 1000.0 feet, there is a I -- show (and C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH - t::- '--- -"l - - - ---- ---- ------ - - - - ----- ~ ------ - - - - - - ... ./ ---~ ------ --- - -..-------- . - - - -------- - 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 NPH ~ - - - - - - - - - - - - - - - - - -- --- ~- - .... - - ... - -- ----------- ------ --- --- ------------------------------ I- L- i..-...-- I -' 100.0 Gas 10.0 Oil NPH 1.0 I, I I I I I . Before I I I I I '[ I I I I I I I sperry-sun DRILLING SERVICES Zone of Interest Report Well Name: NORTHSTAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY Depth (MD) 10476 to 10530 ft (1VD) 8927 to 8973 ft Zone Of Interest Report No. ~ Show Report No. - 1 1/19/200220:00 DatelTime: Hole Diameter: 10478 ft Max CI @ ft 12.25 inches Max ROP @ 10503 ft Max Gas @ Bit Type: 0 Mill Tooth ~PDC D Diamond DOther Dlnsert Avg. ROP Avg. Gas MW MW Avg. Avg. Avg. ~ ftIhr ~ Units Avg. Avg. PPM (in 1000's) In Out WOB RPM GPM min/ft Max % Max CI- Max C1 C2 C3 C4 C5 PPM at Max Gas - 15.0 50.0 118.0 ROP Gas CI- 4.8 0.256 0.106 0.079 0.077 C1 C2 C3 C4 C5 15.0 50.0 135.0 187.0 1836.0 128 7.190 1.710 0.456 0.193 145.9110.3512.81410.72810.2531 Formation Data At MAX GAS the visual sample percentages were: 70 % SST , 20 % The reservoir rock was a TRANSLUCENT-OPAQUE -c~ SANDSTO~ the grain shape was SUBANGULAR TO ROUND Approximate visual porosity was GOOD Grain sorting was MODERATE-WELL and the rock cement was was INTERGRANULAR and the secondary components in the rock fragments were: The rock hardness was FRIABLE and the sample contamination was SL T~, ....!£... % SHALE, - % The grain (crystal) size was VF-FINE FRI % and the visual permeability was SILICEOUS/ARGILLACEOW. The porosity type GLAUCONITE, CARBONACEOUS and Preliminary Gas-In-Air Show Data Gas 011 c~ II Gas Oil Cut ~unm (PPM's in 1000's) Fluor? Fluor? Bun~ (PPM's in 1000's) Fluor? Fluor? Depth % C1 C2 C3 C4 C5 Y/N Y/N Depth % C1 C2 C3 C4 C5 Y/N Y/N 10476 1801 133.4 8.380 2.072 0.517 0.178 Y ------- 10485 1761 145.9 10.35 2.814 0.728 0.253 Y ------- 10492 1682 145.3 10.14 2.780 0.732 0.231 N ------- 10498 1474 124.8 9.94 2.825 0.736 0.240 N ------- 10503 1005 109.5 7.440 1.969 0.526 0.220 N ------- 10510 1399 60.9 3.790 0.946 0.289 0.429 N ------- 10530 372 27.1 2.150 0.643 0.142 0.099 N Liquid Hydrocarbon Data The liquid hydrocarbon was first detected at feet and continued through feet. The liquid phase of the mud was The liquid hydrocarbon occurred in the form of SEE BELOW and was present in the When the (was/were) mixed with water and studied in the UVbox, the liquid hydrocarbon covered % of the in color, exhibited a fluorescence and had an approximate and staining (waslwas not) present. The cuttings exhibited a cut that was fluorescence. surface of the water. The oil was API gravity of ; odor was in color with a Logger's Opinion of the Show Interval TOP OF ZONE - SAMPLE EXAMINATION AND CUT - (F/10476' MD T/1 0530'M D) HAD TRACE OF VERY WHITE FLUORESCENCE BUT NO CUT. TOP OF KUPARUK = 10141' MD, 8648' TVD TOP OF KUPARUK "C" = 10476' MD, 8927' TVD . . STEAM STILL ANALYSIS PREDICTS KUPARUK "C" INTERVAL WOULD PRODUCE GAS AND SOME OIL IN BOTTOM OF SECTION ~ I II sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY r Depth (MD) 10530 to 10620 ft (1VD) 8927 to # 9049 ft Show Report No. . 1 A Datemme: 12/18/01 1830 r Zone Production Analysis (From Steam-Still PPM Ratios) The production of this zone is deemed to be GAS . At approximately - contact ( and a I contact at approximately feet) for a total of feet of feet of show). r % Depth 10547 ft Gas ~Units 1261 Mud Chlorides (ppm) = ---~õ\Mríñië-------~jjch()ñ-------~h()~------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 68.0 - 6.310 = 61.7 C2 8.4 - 1.115 = 7.30 C3 4.955 - 0.956 = 3.999 C4 2.972 - 1.006 = 1.966 C5 2.033 - 0.931 = 1.102 --~õ(fuctiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 % Depth 10550 ft Gas x Units 1588 Mud Chlorides (ppm) = ---~Ci~Tíñië-------~jjch()ñ-------~h()~-~---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 136.6 - 6.310 = 130.3 C2 16.15 - 1.115 = 15.04 C3 9.97 - 0.956 = 9.01 C4 6.160 - 1.006 = 5.154 C5 3.860 - 0.931 = 2.929 --~õ(fuctiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 % Depth 10575 ft Gas x Units 712 Mud Chlorides (ppm) = ---~õ\Mríñië-------~jjcti()ñ-------~h()~------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 82.8 - 6.310 = 76.5 - C2 9.97 - 1.115 = 8.9 - C3 6.38 - 0.956 = 5.4 C4 3.830 - 1.006 = 2.8 C5 2.360 - 0.931 = 1.4 --Þrõ(fuctiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 4 % Depth 10603 ft Gas x Units 2029 Mud Chlorides (ppm) = ---~õ\Mrín4ë-------~-ucti()ñ-------~h()~------------------------------------------..------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 93.9 - 6.310 = 87.6 C2 12.20 - 1.115 = 11.09 C3 8.490 - 0.956 = 7.534 C4 5.970 - 1.006 = 4.964 C5 4.050 - 0.931 = 3.119 --~rõ(fuctiõñ---------------------------------------------------------------------------- Analysis IX'IGas mOil nWater nNon-Producible Hydrocarbons I Hydrocarbon Ratios C1/C2 = 8.5 C1/C3 = 15.4 - C1/C4 = 31.4 C1/C5 = 56.0 I I I Hydrocarbon Ratios C1/C2 = 8.7 - C1/C3 = 14.5 - C1/C4 = 25.3 C1/C5 = 44.5 ( I r Hydrocarbon Ratios C1/C2 = 8.6 C1/C3 = 14.1 - C1/C4 = 27.1 C1/C5 = 53.5 I I I I Hydrocarbon Ratios C1/C2 = 7.9 - C1/C3 = 11.6 - C1/C4 = 17.6 - C1/C5 = 28.1 I I 1000.0 100.0 1000.0 feet, there is a I show (and C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH I- I- I- I- - - - ---------- - -~--~ ---- ---- -- - - - - I --- ~ ~~ .... - ---- -----. --- - - ~ ------ ---------- ------ - - - - - - - - - L- - ..L Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 NPH == - - - ---- ---- ---- - - - --..- ~- ~ ---- - - ----- . ~ ~ ---' ~ ------:.¡ ~ - - - - - - - --- -------- ---- ---' 100.0 Gas 10.0 Oil NPH 1.0 d.: f I sperry-sun DRilLING SERVICES Zone of Interest Report Well Name: NORTH STAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY Depth (MD) 10530 to 10620 ft (1VD) 8973 to 9049 ft Zone Of Interest Report No. ~ Show Report No. - 1 A 1/19/200222:00 Datemme: :1 I I Hole Diameter: 12.25 inches Max ROP @ 10556.0 ft Max Gas @ 10604.0 ft Max CI @ Bit Type: 0 Mill Tooth ~PDC 0 Diamond DOther Dlnsert I Avg. ROP Avg. Gas I Before During After MW MW Avg. Avg. Avg. ~ ftIhr ~ Units Avg. Avg. PPM (in 1000's) In Out WeB RPM GPM minlft Max % Max CI- Max C1 C2 C3 C4 C5 PPM at Max Gas - 15.0 50.0 56.0 ROP Gas CI- 49.5 2.870 0.708 0.246 0.107 C1 C2 C3 C4 C5 14.0 48.0 209.0 209.0 2029.0 102 6.180 1 .430 0.407 0.134 106.516.49011.79010.55910.2601 15.0 51.0 85.0 21.4 1.320 0.409 0.176 0.102 I I Formation Data At MAX GAS the visual sample percentages were: 30 % SST , 40 % The reservoir rock was a TRANSLUCENT-OPAQUE -colored SANDSTO~ the grain shape was SUBANGULAR-ROUND Approximate visual porosity was GOOD Grain sorting was MODERATE-WELL and the rock cement was was INTERGRANULAR and the secondary components in the rock fragments were: The rock hardness was FRIABLE and the sample contamination was SLTST ,.22....% SHALE, - % The grain (crystal) size was VF-FINE FRI % and the visual permeability was SILICEOUS/ARGILLACEOU~ . The porosity type GLAUCONITE, CARBONACEOUS and I ( Preliminary Gas-In-Air Show Data Gas 011 Cut Gas 011 Cut ~un. (pPM's in 1000's) Fluor? Fluor? ~unm (PPM's in 1000's) Fluor? Fluor? Depth % C1 C2 C3 C4 C5 Y/N Y/N Depth % C1 C2 C3 C4 C5 Y/N Y/N 10536 793 49.5 2.876 0.708 0.246 0.107 N N 10590 1140 76.9 5.060 1.410 0.428 0.156 ------- ------ 10545 1140 59.3 3.050 0.746 0.251 0.140 N N 10608 ~ ~ ~ ..1ZlliL ~ ~ ------- 10550 1588 69.4 3.870 0.964 0.278 0.110 N N 10615 885 61.2 3.390 0.889 0.238 0.117 ------- 10555 1500 101.9 6.180 1.440 0.407 0.134 N ------- 10559 1039 102.8 7.490 2.080 0.604 0.149 N ------- 10565 558 52.3 3.480 1.230 0.458 0.157 N ------- 10577 655 48.1 2.800 0.751 0.241 0.098 N I I I [ Liquid Hydrocarbon Data The liquid hydrocarbon was first detected at feet and continued through feet. The liquid phase of the mud was The liquid hydrocarbon occurred in the form of SEE BELOW and was present in the When the (was/were) mixed with water and studied in the UV box, the liquid hydrocarbon covered % of the in color, exhibited a fluorescence and had an approximate and staining (was/was not) present. The cuttings exhibited a cut that was fluorescence. surface of the water. The oil was API gravity of ; odor was in color with a I I I Logger's Opinion of the Show Interval TOP OF ZONE - SAMPLE EXAMINATION AND CUT - (FL10530' MD T/10620'MD) NO FLUORESCENCE, NO CUT. BOTTOM OF KUPARUK "B" STEAM STILL ANALYSIS PREDICTS BOTTOM KUPARUK WOULD PRODUCE GAS AND SOME OIL. I I ~ II .~ sperry-sun DRILLING SERV1CES Show Report Well Name: NORTHSTAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY I Depth (MD) 12490 to 12555 ft (lVD) 10739 to 10801 ft Show Report No. ...2.... Datemme: 2/04/2002 19:00:00 AM I Zone Production Analysis (From Steam-Still PPM Ratios) The production of this zone is deemed to be GAS/OI L . At approximately - feet, there is a contact ( and a I contact at approximately feet) for a total of feet of feet of show). I % Depth 12513 ft Gas ~ Units 180 Mud Chlorides (ppm) = ---~õ\Mrír1ë-------~-uënë)ñ-------~hë)vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 9.3 - 0.001 = 9.3 C2 0.8 - 0.001 = 0.78 C3 0.302 - 0.001 = 0.301 C4 0.162 - 0.001 = 0.161 C5 0.107 - 0.001 = 0.106 --~rõëruëffõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 % Depth 12541 ft Gas x Units 112 Mud Chlorides (ppm) = ---~õ\Mnrr1ë-------~jjënë)ñ-------~hë)vv-~---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 5.4 - 0.001 = 5.4 - C2 0.49 - 0.001 = 0.49 C3 0.18 - 0.001 = 0.18 C4 0.100 - 0.001 = 0.099 C5 0.088 - 0.001 = 0.087 --~õëruëtiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 % Depth 12520 ft Gas x Units 82 Mud Chlorides (ppm) = ---F1õ\Mrín4;-------~-uënë)ñ-------Šhë)vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 2.6 - 0.379 = 2.2 C2 0.58 - 0.135 = 0.4 C3 0.58 - 0.186 = 0.4 C4 0.447 - 0.204 = 0.2 C5 0.294 - 0.242 = 0.1 --Þrõëru~tiõñ---------------------------------------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 4 % Depth 12540 ft Gas x Units 105 Mud Chlorides (ppm) = ---~õ\Mrír1ë-------š-uënë)ñ-------Šhë)Vi------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 3.4 - 0.379 = 3.0 - C2 0.66 - 0.135 = 0.52 C3 0.600 - 0.186 = 0.414 C4 0.430 - 0.204 = 0.226 C5 0.270 - 0.242 = 0.028 --~rõëruëtiõñ---------------------------------------------------------------------------- Analysis IXlGas mOil nWater nNon-Producible Hydrocarbons I Hydrocarbon Ratios C1/C2 = 11.9 C1/C3 = 30.9 C1/C4 = 57.8 C1/C5 = 87.7 I I I Hydrocarbon Ratios C1/C2 = 11.2 C1/C3 = 30.0 - C1/C4 = 54.9 C1/C5 = 62.5 I I I Hydrocarbon Ratios C1/C2 = 4.9 - C1/C3 = 5.6 C1/C4 = 8.9 C1/C5 = 41.8 I I I I Hydrocarbon Ratios C1/C2 = 5.8 C1/C3 = 7.3 C1/C4 = 13.4 C1/C5 = 107.9 I I 1000.0 1000.0 NPH I -- show (and C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 NPH GAS TRA P GAS IN A R ....- -- -- --" ....- --.---~---- ---------- ---------- .- - ""'-- .~ ----- --- ~.-- i ~---------- ----- - - - - ---------- ------ ----- 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 100.0 STEAM S1. ILL GAS D! TA - _....- ........' ....-- -- ----------J ~ -~ - - - ~ - - - - ----------- /' .off- ../ --- ---- // ----------- ----~ V ----- ------. ----, Gas 10.0 Oil NPH 1.0 I I I I I I I I Before During - After I I I I I I I I I I I I sperry-sun DRilLING SERVICES Zone of Interest Report Well Name: NORTH STAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY Depth (MD) 12490 to 12555 ft (1VD) 10739 to 10801 ft Zone Of Interest Report No. ...2- Show Report No. - 2 2/4/2002 20:00 Datemme: 6.125 inches Max ROP @ 12511 ft Max Gas @ 12513 ft Max CI @ Hole Diameter: Bit Type: 0 Mill Tooth ~PDC 0 Diamond 0 Other 0 Insert Avg. Rap Avg. Gas MW MW Avg. Avg. Avg. ~ ftlhr ~ Units Avg. Avg. PPM (in 1000's) In Out WOB RPM GPM minlft Max % Max CI- Max C1 C2 C3 C4 C5 PPM at Max Gas - 45SL OSL 25.0 Rap Gas CI- 0.9 0.077 0.039 0.024 0.050 C1 C2 C3 C4 C5 45SL OSL 55.0 75.0 180.0 5.20 0.428 0.160 0.090 0.088 9.4 1 0.7910.30210.16210.1071 35SL OSL 21.0 Formation Data At MAX GAS the visual sample percentages were: 60 % SST , 30 % The reservoir rock was a L ToMEO GRAY,GRAY/BROWN -c~ SANDSTO~ the grain shape was SUBANGULAR TO SUBROUND Approximate visual porosity was POOR Grain sorting was MODERATE-POOR and the rock cement was was INTERGRANULAR and the secondary components in the rock fragments were: The rock hardness was SILTY CLAY and the sample contamination was SLT~,~% SHALE '_% The grain (crystal) size was VF-FINE POOR % and the visual permeability was ARGILLACEOUS/SIL TY. The porosity type GLAUCONITE, PYRITE and Preliminary Gas-In-Air Show Data Gas 011 ~ II Gas 011 Cut ~unk' (PPM's in 1000's) Fluor? Fluor? Bd (PPM's in 1000's) Fluor? Fluor? Depth % C1 C2 C3 C4 C5 Y/N Y/N Depth % C1 C2 C3 C4 C5 Y/N Y/N 12509 74 3.3 0.253 0.097 0.055 0.064 Y ------- 12518 65 3.1 0.24 0.088 0.047 0.057 Y ------- 12523 103 5.0 0.42 0.155 0.087 0.065 Y ------- 12531 67 4.7 0.39 0.151 0.084 0.109 Y ------- 12537 81 6.3 0.558 0.207 0.111 0.082 Y ------- 12543 108 6.0 0.535 0.202 0.109 0.075 Y ------- 12553 99 5.7 0.507 0.187 0.101 0.080 Y Liquid Hydrocarbon Data The liquid hydrocarbon was first detected at feet and continued through feet. The liquid phase of the mud was The liquid hydrocarbon occurred in the form of SEE BELOW and was present in the When the (was/were) mixed with water and studied in the UV box, the liquid hydrocarbon covered % of the in color, exhibited a fluorescence and had an approximate and staining (was/was not) present. The cuttings exhibited a cut that was fluorescence. surface of the water. The oil was API gravity of ; odor was in color with a Logger's Opinion of the Show Interval SAG RIVER ZONE - SAMPLE EXAMINATION AND CUT - (F/12490' MD T/12555'MD) 10-20% DULL TO BRIGHT YELLOW SAMPLE FLUORESCENCE. A MODERATELY FAST YELLOW-WHITE CUT FLUORESCENCE WAS OBSERVED. TOP OF SAG RIVER = 12459' MD, 10710' TVD - STEAM STILL ANALYSIS PREDICTS SAG RIVER INTERVAL WOULD PRODUCE OIL. GAS TRAP GAS-iN-AIR RATIOS SHOW GAS. LOW OVERALL GAS READINGS FROM STEAM STILL AND GAS TRAP GAS INDICATE FORMATION TIGHT. 100% Gas-In-Air = 10,000 units I I:,' I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY I Depth (MD) 12653 to 12760 ft (TVD) 10895 to 10996 ft Show Report No. ...2 Datemme: 2/04/2002 19:00:00 AM I Zone Production Analysis (From Steam-Still PPM Ratios) The production of this zone is deemed to be 01 L . At approximately - feet, there is a contact ( and a I contact at approximately feet) for a total of feet of feet of show). I % Depth 12655 ft Gas ~ Units 92 Mud Chlorides (ppm) = ---F1õ\Mnrr1ë-------~Licti()ñ-------§h()vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 7.2 - 1.046 = 6.2 C2 1.4 - 0.331 = 1.05 C3 1.424 - 0.472 = 0.952 C4 1.305 - 0.510 = 0.795 C5 0.972 - 0.397 = 0.575 --~rõëfüëffõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 2 % Depth 12660 ft Gas x Units - 133 Mud Chlorides (ppm) = ---F1õivvnrn~-------~-üctiõii------:šFio1Ñ------------------------------------------~------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 12.7 - 1.046 = 11.7 C2 2.13 - 0.331 = 1.80 C3 2.00 - 0.472 = 1.53 C4 2.029 - 0.510 = 1.519 C5 1.544 - 0.397 = 1.147 --~rõëfüëffõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 3 % Depth 12700 ft Gas x Units 82 Mud Chlorides (ppm) = ---~õ\Mrír1ë-------~-üctiõii-------§h()VV------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 20.7 - 1.046 = 19.6 C2 3.33 - 0.331 = 3.0 C3 2.99 - 0.472 = 2.5 C4 2.400 - 0.510 = 1.9 C5 1.610 - 0.397 = 1.2 --~rõëfüëffõñ--------------------------------------------------~------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 4 % Depth 12760 ft Gas x Units 105 Mud Chlorides (ppm) = ---~lõ\Mniië-------~-ücti()ñ------:Šh()VV------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 6.0 - 1.046 = 4.9 C2 1.52 - 0.331 = 1.19 C3 2.033 - 0.472 = 1.561 C4 1.996 - 0.510 = 1.486 C5 1.355 - 0.397 = 0.958 --~rõëfüëffõñ---------------------------------------------------------------------------- Analysis nGas pqOil nWater nNon-Producible Hydrocarbons I Hydrocarbon Ratios C1/C2 = 5.9 C1/C3 = 6.5 C1/C4 = 7.8 C1/C5 = 10.8 I I I Hydrocarbon Ratios C1/C2 = 6.5 C1/C3 = 7.6 C1/C4 = 7.7 C1/C5 = 10.2 I I I Hydrocarbon Ratios C1/C2 = 6.5 C1/C3 = 7.8 C1/C4 = 10.4 C1/C5 = 16.2 I I I I Hydrocarbon Ratios C1/C2 = 4.2 C1/C3 = 3.2 C1/C4 = 3.3 - C1/C5 = 5.2 I I 1000.0 1000.0 NPH I show (and C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 NPH STEAM STI ..L GAS RA 105 ---- -- ---- -- - -- -- - - - - - ---------- ---------- ---- --- ------ - - - - - - - - - ....11 ------ ----- 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 100.0 STEAM STI ,"L GAS RA ~ 105 - --- --- -- -- ~------------ ---------- ----------- -- ---- ----- ----------- ------- .~I - - ------- ----. Gas 10.0 Oil NPH 1.0 I ¡ ~ sperry-sun DRILLING SERVICES Zone of Interest Report Well Name: NORTH STAR NS14 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: Doug Wilson Report Delivered To: KEN LEMLEY Depth (MD) 12653 to 12750 ft (1VD) 10895 to 10987 ft Zone Of Interest Report No. --1- Show Report No. - 3 2/4/2002 20:00 I 6.125 inches Max ROP @ 12664 ft Max Gas @ 12671 ft Max CI @ I Hole Diameter: Bit Type: 0 Mill Tooth ~PDC 0 Diamond DOther 0 Insert I Avg. ROP Avg. Gas I Before During After MW MW Avg. Avg. Avg. ~ ftlhr ~ Units Avg. Avg. PPM (in 1000's) In Out WeB RPM GPM minlft Max % Max CI- Max C1 C2 C3 C4 C5 PPM at Max Gas - 15.0 60.0 18.0 ROP Gas CI- 1.3 0.174 0.103 0.066 0.063 C1 C2 C3 C4 C5 15.0 60.0 80.0 108.0 196.0 9.55 0.856 0.352 0.150 0.114 13.811.2210.47610.17510.1301 u.- .~ - I I Formation Data At MAX GAS the visual sample percentages were: 50 % SST , 20 % The reservoir rock was a TRANSLUCENT,L T-MEDGRY -colored SST +CONcr- the grain shape was SUBANGULAR TO ANGULAR Approximate visual porosity was GOOD Grain sorting was MODERATE-POOR and the rock cement was was INTERGRANULAR and the secondary components in the rock fragments were: The rock hardness was UNCONSOLIDATED and the sample contamination was CON£.. --12.- % SHALE,.2Q.... % SILTS. The grain (crystal) size was VF-PEB SZ GOOD % and the visual permeability was SILICEOUS The porosity type CHERT/MICROPOR CHT and I Preliminary Gas-In-Air Show Data Gas 011 ~ II Gas 011 Cut ~un~ (PPM's in 1000's) Fluor? Fluor? Bun. (PPM's in 1000's) Fluor? Fluor? Depth o/c C1 C2 C3 C4 C5 Y/N Y/N Depth o/c C1 C2 C3 C4 C5 Y/N Y/N 12663 150 6.4 0.600 0.241 0.101 0.094 Y ------- 12673 ~ ~ -1Q!. ~ ~ ~ ---!... 12684 149 12.0 1.10 0.433 0.167 0.100 Y ------- 12691 126 9.6 0.86 0.350 0.150 0.086 Y ------- 12704 122 7.6 0.686 0.300 0.136 0.113 Y ------- 12736 104 6.2 0.577 0.250 0.122 0.088 Y ------- 12750 65 3.3 0.338 0.174 0.089 0.094 Y I I I I I Liquid Hydrocarbon Data The liquid hydrocarbon was first detected at feet and continued through feet. The liquid phase of the mud was The liquid hydrocarbon occurred in the form of SEE BELOW and was present in the When the (was/were) mixed with wat~r and studied in the UV box, the liquid hydrocarbon covered % of the in color, exhibited a fluorescence and had an approximate and staining (was/was not) present. The cuttings exhibited a cut that was fluorescence. surface of the water. The oil Was API gravity of ; odor was in color with a I I Logger's Opinion of the Show Interval UPPER IVISHAK ZONE - SAMPLE EXAMINATION AND CUT - (F/12563' MD T/12760'MD) 10-40% DULL TO BRIGHT YELLOW.WHITE SAMPLE FLUORESCENCE. A POOR DULL ORANGE CUT FLUORESCENCE WAS OBSERVED. DRY SAMPLE CUT YIELDED A PALE YELLOW CUT FLOURESCENCE TOP OF IVISHAK = 12653' MD, 10895' TVD STEAM STILL ANALYSIS PREDICTS IVISHAK INTERVAL WOULD PRODUCE OIL. APPROXIMATE OIL GRAVITY VISUALLY OBSERVED THROUGH CUT FLUORESCENCE WHEN SAMPLE WAS DRY WAS API 43 DEGREES. 100% Gas-In-Air = 10.000 units I I I I, I I [ I I [ [ I I [ [ I I I I I I I ~: ~, ,) , ',' ';I BP Alaska NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 1 1 n /02 0 0 Move Rig GAVIN KIDD Mudlogger's Morning Report ...ustomer: Well: Area: Lease: Rig: Job No.: spe..........v- sun CAI LLI N G SEAVI C=E S Current 24 hr Avg 24 hr Max Pump and Flow Data ft/h r ft/hr ( ft/hr @ ) Pump 1 spm DH flow units unit~ ( units @ ) Pump 2 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres psi AV @ DC spe....,....,v- sun CRILLI N G SERVII::ES Mudlogger's Morning Report lustomer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data ft/h r ft/h r ( ft/hr @ ) Pump 1 spm DH flow units unit~ ( units @ ) Pump 2 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres psi AV @ DC I I I I I I I I ,I Logging Engineer: REG WILSON /TOM MANSFIELD :1 ,:' .,-~ ',"'" " "", I ( I I I Trip Depth: Short Trip Depth Tight Spots: Depth before to to Drill Rate during Connection Gas and Mud Cut ft units ft units ft units Drilling Breaks after before ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Gas during Cgl % Lithology Sst Ls Sitst after ---- ---- ---- ---- * 10000 units = 100% Gas In Air ( r ' ( ( ( ( ( ( ( ( ( I I I I' II",. 'II"""." . ,." r I I Mudlogger's Morning Report Justomer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 3 1 /9/02 1318' 1318' Drillin~ GAVIN KIDD spe....,....,v- sun CAlL LING SEAVIt:ES Current 24 hr Avg 24 hr Max Pump and Flow Data 160 ft/hr 130 ft/hr ( 418 ft/hr @ 412 ) Pump 1 75 spm DH flow 4 units 2 unit~ ( 4 units @ 1254 ) Pump 2 95 spm Total flow 720 48 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 1275 psi A V @ DC I .,ustomer: BP Alaska ~ Report No.: 4 Well: NorthStar NS 14 Date: 1/1 0/02 spe....,....,v- sun Area: North Slope Depth 3316' CAt LLt N G SEAVIc::es Lease: NorthStar NS 14 Footage Last 24 hrs: 1998' Rig: Nabors 33E Rig Activity: POOH Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: GAVIN KIOD Shows: f f Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ft/h r 83.25 ft/hr ( 653 ft/hr @ 2161 ) Pump 1 107 spm DH flow 15 units 15 unit~ ( 47 units @ 2067 ) Pump 2 107 spm Total flow 900 48 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 1970 psi A V @ DC I f I f I f I I I I I I I I Trip Depth: Short Trip Depth . .Tight Spots: ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Connection Gas and Mud Cut ft units ft units ft units Drilling Breaks before Drill Rate during after before Gas during after Cgl % Lithology Sst Ls Sitst Depth to to ---- ---- ---- ---- Drilled F/1318' T/3316 TO, Circulate to clean hole. Currentl Logging Engineer: Reg Wilson / Mark Lindloff * 10000 units = 100% Gas In Air I...' I, , I ( I I I I I I I I I I I I'! sper'r'V- sun [J A I LL I N G 5 e A v I c: E 5 Mudlogger's Morning Report ";tl¡'!'\~1j:šJi~~\~wîçY¡#i¡t¡i~~;i~~'i~@~t~\i;;l¡~t\(,~¡;~~1i~\~¡~:*~t~~k~~;i;'?;~t1~&¡*1;;ii¡q¡¡1;\¡~\yti~)~f;fi~$¡¡r .,ustomer: BP Alaska Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 5 1/11/02 3316' 0 Cementing GAVIN KIDD I I I I Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 110 spm DH flow 0 units 4 unit~ ( 15 units @ 3316 ) Pump 2 spm Total flow 465 48 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 400 psi A V @ DC I' ! , . l I I I I I I I I I I' I I I I I "...;ustomer: BP Alaska ~ Report No.: 6 Well: NorthStar NS 14 Date: 1/12/02 sper""'\1- sun Area: North Slope Depth 3316' DRILL I N G SERVICES Lease: NorthStar NS 14 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Testing BOP's Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: GAVIN KIDD Shows: I I I Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ft/h r 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 spm Total flow 40 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 0 psi A V @ DC I I I I [ ( I I I I I I I I .,ustomer: BP Alaska I I I I ( [JAILLING SEAVIc:es Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 7 1 /1 3/02 3336' 20 Drilling/FIT GAVIN KIDD sper'r'V- sun Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ftlhr 0 ftlhr ( 0 ftlhr @ 0 ) Pump 1 85 spm DH flow 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 85 spm Total flow 719 45 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 1300 psi A V @ DC i ~ I Mudlogger's Morning Report Well: Area: Lease: Rig: Job No.: :=Ieport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: [:J A I L..L. I N G SEAVIC::ES NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 8 1/14/02 5175' 1,839 - Drilling GAVIN KIDD I spe...,.-.v- sun I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 35 ft/hr 77 ft/hr ( 648 ft/hr @ 4183 ) Pump 1 110 spm DH flow Gas* 37 units 48 unit~ ( 177 units @ 4241 ) Pump 2 112 spm Total flow 940 Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 2300 psi AV @ DC Ii ; . ) r I Mud Wt In Mud Wt Out 9.20 9.20 ppg ppg Visc ~ secs API filt 6.5 ml HTHP - - ml Mud Wt at Max Gas 9.2 ppg PV 29 cP YI 15 Ibs/100ft2 Gels 10 / 14 / 0 Ibs/100ft2 pH 7.5 Sd 2 % --- I 2 Type: STC FGXIC Bit Size: 12.25" 47.00 RPM: 80 Hrs. On Bit: 12.3 Jets: 16 \ 20 \ 20 \ \ \ TFA: ------ Total Revs on Bit: 198 Footage for Bit Run 1.0580 - 1,859 I ft ft Trip Gas: Short Trip Gas: 0 194 Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: - 1600 Feet of Fill on Bottom: r ' I I I I I I I I I DRILLING SERVices Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 ::Ieport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 9 1/15/02 6453 1,278 Drilling GAVIN KIDD ~ ~ "~. ' \,1 ,I spe...,....,v- sun I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 120 ft/hr 178 ft/hr ( 648 ft/hr @ 5952 ) Pump 1 111 spm DH flow Gas* 31 units 57 unit~ ( 1049 units @ 6045 ) Pump 2 113 spm Total flow 953 Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 2560 psi AV @ DC r Mudlogger's Morning Report I I I Mud Wt In Mud Wt Out 9.10 9.10 ppg ppg Vise 51 secs API filt 7.8 ml HTHP ml Mud Wt at Max Gas 9.1 - - - - PV 14 cP YI 25 Ibs/100ft2 Gels 11 / 14 / 14 Ibs/100ft2 pH 7.0 Sd --- I 2 Type: STC FGXIC Bit Size: 12.25" 60.00 RPM: 80 Hrs. On Bit: 25.2 Jets: 16 \ 20 \ 20 \ --- Total Revs on Bit: 370 I I I I I I I I I I I- I Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: I spe....,r"V- sun Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 CRILLI N G SERVIC:ES , Mudlogger's Morning Report ","'C""'>'c,::>:"'" 24 hr Avg 24 hr Max ft/hr 120 ft/hr ( 512 ft/hr @ 6550 units 28 unit~ ( 51 units @ 6569 Deg F ( deg F @ 10 1/16/02 6899 446 TRIP IN Joe Polya ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data ~ spm DH flow a spm Total flow spm AV @ rsr psi AV @ DC I Current RO.P. a Gas* a Temp Out 75 I I Vise 49 sees API tilt 7.5 ml PV 10 eP VI 27 Ibs/100ft2 Gels I Type: DS69HFGLNPU Bit Size: 12.25" RPM: a Hrs. On Bit: 0.0 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: ------ Total Revs on Bit: a Footage for Bit Run I ft ft Trip Gas: Short Trip Gas: a 0 1.0350 0 to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: - 1600 Feet of Fill on Bottom: ppm ppm ft to I Sd % Sit 20 % 50 % 30 % Current Lithology: I Connection Gas and Mud Cut ft units ft units ft units ft ft ft units units units ft ft ft I Drilling Breaks I Gas during Depth Drill Rate during before after ---- after before I to to ---- units units units %LCM ppg ppg ppg Cgl % Lithology Sst Ls Sitst ---- ---- I I I I I DRILLI N G seAVlc:es Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 11 1/17/02 8578 1,679 Drilling Joe Polya I spel"""'r'\{- sun I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 167 ft/hr 152 ft/hr ( 387 ft/hr @ 6953 ) Pump 1 106 spm DH flow Gas" 38 units 46 unit~ ( 252 units @ 6899 ) Pump 2 108 spm Total flow 910 Temp Out 75 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 3050 psi AV @ DC -- I I Mud Wt In Mud Wt Out 9.40 9.40 ppg ppg Vise 57 sees API filt 8.8 ml PV 12 eP YI 28 Ibs/1 00ft2 Gels - - I 3 Type: DS69HFGLNPU Bit Size: 12.25" 41.00 RPM: 80 Hrs. On Bit: 15.2 I I I I I (" I I I I I NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 ~eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 12 1/18/02 9602 1,024 Drilling/Sliding Joe Polya I spe....,...,v- sun Well: Area: Lease: Rig: Job No.: DRILLI N G seRVices I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data 129 ft/hr 107 ft/hr ( 266 ft/hr @ 8820 ) Pump 1 95 spm DH flow 37 units 60 unit~ ( 162 units @ 9466 ) Pump 2 95 spm Total flow 790 - 91 Deg F ( deg F @ ) Pump 3 spm AV @ rsr Pump Pres 2800 psi AV @ DC ( I Vise ~ sees API filt 10.0 ml HTHP - - ml Mud Wt at Max Gas 9.6 ppg PV 16 eP VI 29 Ibs/100ft2 Gels ~ / ~ / ~ Ibs/1 00ft2 pH 9.1 Sd 0.25 % I Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: ------ Total Revs on Bit: 436 Footage for Bit Run I Trip Depth: Short Trip Depth Tight Spots: ft ft Mud Cut: Mud Cut: to ppg Trip CI: 17000 ppg Short Trip CI: Feet of Fill on Bottom: Trip Gas: Short Trip Gas: to to I %LCM I :1 I I I I I I I I ppm ppm ft I i'¡;fjJi;ï¡~~;t¡!Œ}*!:t~k\9'{\(,\¡)i,iwni;\'(\t1j(;*tJ\'i;!;)ifi:;1;'i;;¡;¡¡\tïi(;i,8(\i¡;;~:j'¡Q;:;;;;;Yi;ïïbjRi¡~ï;';N¡1fHjl¡¡A¡~lt¡,)C~:':j¡iìj;ï*1*C[;i1;ïŽ\~\¡i~\iìj~;ï~~~;:!;¡~¡jtáJ;¡i*i¡;i,¡jlï\:j;it(ï\;&\Y;$;1;il;;¡ï;;¡;1H¡¡¡%j¡i.;¡f1@1~;1%1~¡â , '~d;ur ~~stom~r:BPAlaska' '" '" . 'ut ~~p~;t'No.: Well: NorthStar NS 14 Date: spe.....,....-.v- sun Area: North Slope Depth [J A I ~L I N G seA v I c: e s Lease: NorthStar NS 14 Footage Last 24 hrs: Rig: Nabors 33E Rig Activity: Job No.: AK AM 22002 Report For: Shows: Mudlogger's Morning Report 13 1/19/02 10169' 567 Drilling/Sliding Joe Polya I I I Current 24 hr Avg 24 hr Max Pump and Flow Data 42 tt/hr 107 tt/hr ( 215 tt/hr @ 10049 ) Pump 1 95 spm DH flow 94 units 60 unit~ ( 475 units @ 10237 ) Pump 2 95 spm Total flow 820 - Temp Out 91 Deg F ( deg F @ ) Pump 3 spm AV @ DP 126 - Pump Pres 2750 psi A V @ DC 168 f I Mud Wt In Mud Wt Out 9.80 9.80 ppg ppg Vise ~ sees API filt 4.2 ml HTHP - - ml Mud Wt at Max Gas 9.8 ppg PV 13 eP YI 21 Ibs/100ft2 Gels ~ / ~/ ~lbs/100ft2 pH 8.9 Sd 0.25 % I 3 Type: DS69HFGLNPU Bit Size: 12.25" 27.00 RPM: 0 Hrs. On Bit: 51.7 I Trip Depth: Short Trip Depth Tight Spots: ft ft Trip Gas: Short Trip Gas: Mud Cut: Mud Cut: to I I I I I I I I I II I I CAILLI N G 5EAVIC:E5 Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 ~eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 14 1 /20/02 10930 761 POOH Joe Polya I spe...-.f'""'V- sun I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 93 ft/hr ( 215 ft/hr @ 10503 ) Pump 1 100 spm DH flow Gas* 0 units 254 unit~ ( 2248 units @ 10514 ) Pump 2 100 spm Total flow Temp Out 91 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 3150 psi AV @ DC I I Mud Wt In Mud Wt Out 9.80 9.80 ppg ppg Visc 43 sees API filt 3.8 ml HTH P 9.4 ml Mud Wt at Max Gas - -- PV 11 cP YI 14 Ibs/100ft2 Gels ~ / ~ / ~ Ibs/1 OOft2 pH 9.5 I I I I I I I f il I I I I I ~ \[ spe...,.....,v- sun Well: NorthStar NS 14 Area: North Slope Lease: NorthStar NS 14 Rig: Nabors 33E Job No.: AK AM 22002 SEAVIC::ES ~eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 15 1 /21 /02 10930 0 Short Trip Joe Polya I [JAI LLI N G I Mudlogger's Morning Report 1 Current 24 hr Avg 24 hr Max Pump and Flow Data R,O,P. 0 ft/hr ft/hr ( ft/hr @ ) Pump 1 85 spm DH flow Gas* 2366 units 917 unit~ ( 4019 units @ 10886 ) Pump 2 85 spm Total flow Temp Out 105 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 2500 psi A V @ DC I r Mud Wt In Mud Wt Out 10,20 ppg 10.20 ppg Vise ~ sees API filt 3,4 ml HTHP - 9~ ml Mud Wt at Max Gas 11,9 ppg PV 13 eP YI 23 Ibs/100ft2 Gels ~ / ~ / ~ Ibs/1 00ft2 pH 8,8 Sd 0 % I 3 Type: DS69HFGLNPU Bit Size: 12,25" -90,00 RPM: 0 Hrs, On Bit: 61,3 Jets: 15 \ 15 \ 15 \ 15 \ 15 \ 15 TFA: ------ Total Revs on Bit: 825 Footage for Bit Run ( Trip Depth: Short Trip Depth Tight Spots: ft 6700 ft to Trip Gas: Short Trip Gas: 4019 Mud Cut: Mud Cut: to ppg Trip CI: f#i ppg Short Trip CI: - 17000 Feet of Fill on Bottom: ppm ppm ft to I %LCM ( I [ I I I 1 I .1 I ~ustomer: BP Alaska (, leport No.: 16 Well: NorthStar NS 14 Date: 1 /22/02 sper'f"""V- sun Area: North Slope Depth 10930 DRILLI N G SERVIc::es Lease: NorthStar NS 14 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Slip & Cut Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: Joe Polya Shows: I I I Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ft/hr ft/hr ( ft/hr @ ) Pump 1 85 spm DH flow 0 units 58 unit~ ( 2169 units @ 10886 ) Pump 2 85 spm Total flow ~ 105 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ Pump Pres 2500 psi AV @ DC 150 I Visc 47 secs API filt 5.0 ml HTHP 11.7 ml Mud Wt at Max Gas - -- PV 11 cP YI 18 Ibs/100ft2 Gels 12 / 26 / 30 Ibs/100ft2 pH 9.5 Sd --- 3 Type: DS69HFGLNPU Bit Size: 12.25" RPM: Hrs. On Bit: 61.3 I I Trip Depth: Short Trip Depth Tight Spots: ft 1 0930 ft to Trip Gas: Short Trip Gas: 2169 to I ( I I I I I I I I I I Customer: BP Alaska ( Report No.: 17 Well: NorthStar NS 14 Date: 1 /23/02 spe....,....,v- sun Area: North Slope Depth 10930 I:J A I L... L... I N G SEAVIc::es Lease: NorthStar NS 14 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: E-Log Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: Joe Polya Shows: I I 'I Current Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC 24 hr Max ft/hr @ units @ deg F @ 24 hr Avg ft/hr ft/hr ( units unit~ ( Deg F ( ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres 64 I I Mud Wt In Mud Wt Out ppg ppg --- Vise 47 sees API filt 5.0 ml HTHP 11.8 ml Mud Wt at Max Gas - -- PV 13 eP VI 18 Ibs/100ft2 Gels 12 / 20 / 25 Ibs/100ft2 pH 9.0 Sd 9.90 9.90 ( Type: - RPM: Bit Size: Hrs. On Bit: Jets: \ \ \ \ \ TF A: ------ Total Revs on Bit: Footage for Bit Run I Trip Depth: Short Trip Depth Tight Spots: to ft ft Trip Gas: Short Trip Gas: Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: to I I I I I I I I I I ppg 0 % ppm ppm ft %LCM i Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: þ\:1t~~~t,;:¡¡1];)iRi~1¡*¿S1ID;¡~i@$i4;H;ilt;iiiì\;i¡*i~]ïB;B~~;fì¡+ii¡i;~i¡\:¡¡~~¡1tßf@111i¡~¡ii¡¡;%i'1j;ìtì;;¡1\'""...,~.... (' Customer: BP Alaska { Well: NorthStar NS 14 spe....,....,v- sun Area: North Slope C A I LL I N G 5 e A v I c: E 5 Lease: NorthStar NS 14 Rig: Nabors 33E Job No.: AK AM 22002 I I Mudlogger's Morning Report 18 1 /24/02 10930 0 E-Log Joe Polya R.O.P. Gas" Temp Out 24 hr Avg 24 hr Max Pump and Flow Data ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow units 55 unit~ ( 196 units @ 5200' trip) Pump 2 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi AV @ DC I Current 40 64 I I 6.2 ml Gels I Type: - RPM: Bit Size: Hrs. On Bit: I Trip Depth: Short Trip Depth Tight Spots: ft ft Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Trip Gas: Short Trip Gas: to to %LCM I I Connection Gas and Mud Cut ft units ft units ft units ft ft ft ft ft ft units units units I Drilling Breaks I Depth Drill Rate during Gas during after ---- after before before I to to ---- units units units ppm ppm ft ppg ppg ppg Cgl % Lithology Sst Ls Sitst ---- ---- I I I I I 1 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 19 1 /25/02 10930 0 CMT 9 5/8 CSG Joe Polya CRILLI N G SeRVIE::eS Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 I sperr'Y- sun I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow Gas* 0 units 150 unit~ ( 2917 units @ 7300 stks ) Pump 2 spm Total flow Temp Out 44 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi AV @ DC I I 7.5 ml HTH P 14.2 ml Mud Wt at Max Gas - -- Gels 9 / 14 / 17 Ibs/100ft2 pH 8.5 Sd --- I Jets: \ \ \ --- Total Revs on Bit: I I I r I I I I I I I ! I ( Customer: BP Alaska If Report No.: 20 Well: NorthStar NS 14 Date: 1/26/02 spe..-.r'V- sun Area: North Slope Depth 10906 DRILLI N G SERVIc:es Lease: NorthStar NS 14 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: P/U BHA, RIH Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: Joe Polya Shows: ( II Current 24 hr Avg 24 hr Max Pump and Flow Data ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow units unit~ ( units @ ) Pump 2 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC 42 I Mud Wt In Mud Wt Out Vise 42 sees API tilt 7.5 ml PV 9 cP YI 23 Ibs/100ft2 Gels 9.90 ppg 9.90 ppg I I I I ( I I I I I I I I I ( ':ustomer: BP Alaska , Report No.: 21 '( Well: NorthStar NS 14 Date: 1/27/02 spe....,....,v- sun Area: North Slope Depth 11 004 DR I LLI N G SERVices Lease: NorthStar NS 14 Footage Last 24 hrs: 74 Rig: Nabors 33E Rig Activity: Drilling Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: Joe Polya Shows: I I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 68 ftlhr 93 ftlhr ( 181 ftlhr @ 11001 ) Pump 1 77 spm DH flow Gas" 49 units 38 uniÜ ( 77 units @ 10998 ) Pump 2 75 spm Total flow 550 Temp Out 42 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 2650 psi AV @ DC I I Mud Wt In Mud Wt Out Vise 45 sees API filt 6.5 ml HTHP 14.0 ml Mud Wt at Max Gas - -- PV 15 cP YI 22 Ibs/100ft2 Gels 7 I 13 1 15 Ibs/100ft2 pH 9.5 Sd 11 .50 ppg 11 .50 ppg --- I Bit No.: 4(RR3) Type: DS70FNPV Bit Size: Wt On Bit: 10.00 RPM: 60 Hrs. On Bit: 81/2 1.5 Jets: 15 \ 15 \ 15 \ 13 \ 13 \ 13 TF A: ------ Total Revs on Bit: 30 Footage for Bit Run I Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: \ \ \- [ \ \ \ I I I I ppg 0 % I ( ," ~ DRILLI N G SERVICES Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Sh ows: 22 1 /28/02 11985 891 Drilling Joe Polya ;.'1'. ], I spe...,....,v- sun I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 8 (SLIDE) ft/hr 125 ft/hr ( 192 ft/hr @ 11915 ) Pump 1 77 spm DH flow Gas. 90 units 78 unit~ ( 103 units @ 11915 ) Pump 2 75 spm T atal flow 550 Temp Out 98 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 2700 psi AV @ DC I Mud Wt In Mud Wt Out 11 .40 ppg 11 .40 ppg Vise 56 sees API filt 5.8 ml PV 23 eP YI 21 Ibs/100ft2 Gels I Bit No.: 4(RR3) Type: DS70FNPV Bit Size: Wt On Bit: 10.00 RPM: 60 Hrs. On Bit: I I I I I I I I I I I I I (' spe....,..,v- sun I I !:JRI LLI N G SERVI~ES Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 23 1 /29/02 12480 495 Short Trip Joe Polya I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr 85 ft/hr ( 220 ft/h r @ 12425 ) Pump 1 spm DH flow Gas* units 100 unit~ ( 200 units @ 12408' ) Pump 2 spm Total flow Temp Out 98 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi AV @ DC I Mud Wt In Mud Wt Out 12.00 ppg 12.00 ppg Vise 52 sees API filt PV 17 eP VI 28 Ibs/1 00ft2 I Bit No.: 4(RR3) Type:- Wt On Bit: 10.00 RPM: I I I I I I I I I I I ( Gustomer: BP Alaska if Report No.: 24 Well: NorthStar NS 14 Date: 1 /30/02 spe....,....,v- sun Area: North Slope Depth 12490 Lease: NorthStar NS 14 Footage Last 24 hrs: 10 DRILLING SERVIJ::ES Rig: Nabors 33E Rig Activity: POOH for 7" Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: Gavin Kidd Shows: 1,1' I I I I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr 36 ft/hr ( 72 ft/hr @ 12483 ) Pump 1 spm DH flow Gas* units 44 unit~ ( 49 units @ 12483 ) Pump 2 spm Total flow Temp Out 102 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi AV @ DC ( I Mud Wt In Mud Wt Out Visc 54 sees API filt 5.0 ml HTHP 13.8 ml Mud Wt at Max Gas - -- PV 18 eP YI 29 Ibs/100ft2 Gels 14 / 36 / 42 Ibs/100ft2 pH 8.9 Sd I ( I [ [ ( ( I I I I I ( ( sper'r"V- sun ~ I I I I I I I I r [ I I I I I I I I DRILLI N G seRVices Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 25 1/31/02 12490 0 Run 7" liner Gavin Kidd Mudlogger's Morning Report Current 24 hr Avg ft/hr ft/hr ( units unit~ ( Deg F ( 24 hr Max ft/hr @ units @ deg F @ ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC 42 Mud Wt In Mud Wt Out Vise 52 sees API filt 5.8 ml HTHP 14.0 ml Mud Wt at Max Gas - -- PV 21 cP VI 23 Ibs/100ft2 Gels ~ / ~ / ~ Ibs/1 00ft2 pH 8.2 Sd I I (' I, spe...-.....,y- sun f ! DR I L.LI N G SERVIc:es Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 26 2/1/02 12490 0 Chg. BOP rams Gavin Kidd 'I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow Gas" units unit~ ( units @ ) Pump 2 spm Total flow Temp Out 40 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC I I Mud Wt In Mud Wt Out Vise 53 sees PV 22 eP YI 22 I I I I I I I I I I I I I '" '( spe...,...,v- sun I I DRILLING SEAVIE::eS Well: Area: Lease: Rig: Job No.: NorthStar NS 14 North Slope NorthStar NS 14 Nabors 33E AK AM 22002 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 27 2/2/02 12490 0 Freeze Protect Gavin Kidd I Mudlogger's Morning Report I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow Gas" units unit~ ( units @ ) Pump 2 spm Total flow Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi AV @ DC I I Vise 56 sees API filt 5.5 ml HTHP ml Mud Wt at Max Gas - -- PV 12 cP YI 23 Ibs/100ft2 Gels --2- / ~ / ~ Ibs/1 OOft2 pH 9.5 Sd I I I I I [ [ I I I I I Iii; , '.::ustomer: BP Alaska l Report No.: .;:: Well: NorthStar NS 14 Date: ~~¡, spe...,.....,v- sun Area: North Slope Depth ,i~: C A I L.L.I N G 5 e A v I c: E 5 Lease: NorthStar NS 14 Footage Last 24 hrs: II,:; :\¡~i' Rig: Nabors 33E Rig Activity: ~.:.:.,'.~ M dl 'M' R Job No.: AK AM 22002 Report For: .~..t.~. u ogger s ornmg eport Sh . 'M1 ows. ~¡¡ 28 2/3/02 12606' 116' Drilling Gavin Kidd Shublik I I ( I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 75 ft/hr 50 ft/hr ( 290 ft/hr @ 12495 ) Pump 1 spm DH flow Gas* 99 units 65 unit~ ( 108 units @ 12512 ) Pump 2 96 spm Total flow 342 Temp Out 72 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 1950 psi A V @ DC I I Vise 49 sees API filt 3.2 ml HTHP ml Mud Wt at Max Gas - -- PV 12 eP YI 31 Ibs/100ft2 Gels ~ / .....!i.. / ~ Ibs/1 00ft2 pH 8.2 Sd I I I 1 ( I 1 I I I I I 'I ~.' i~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ¡i,11¡:1';;¡t,j+;í~\t))J5~f¡~);¡J:;~;¡)*!;+:;f~~i¡~;?;i~L'¡¡(:\{\$~¡¡ti}'i¥R¡,Ii~¿¡t;WJï;¡fd~~~tj;%\~\},I¡jt;~$i!¡~i¡Jï~,jj¡;:i¡j~ti'if{¡;¡;J;iï;~\j)f;¡!;;j;;jfj¡fj¡j¡'Ii'¡i;¡;¡¡;þi\i I( ';ustomer: BP Alaska it , Well: NorthStar NS 14 Area: North Slope Lease: NorthStar NS 14 Rig: Nabors 33E Job No.: AK AM 22002 29 2/4/02 13020 414 WOW Gavin Kidd I spe.....rv- sun DAIL..L..ING SERVIc:es I Mudlogger's Morning Report I Current na na 76 24 hr Max Pump and Flow Data 145 ft/hr @ 12908 ) Pump 1 spm DH flow 198 units @ 12674 ) Pump 2 96 spm Total flow 342 deg F @ _J Pump 3 spm AV @ DP Pump Pres 2000 psi AV @ DC 24 hr Avg ft/hr 57 ft/hr ( units 81 unit~ ( Deg F ( R.O.P. Gas* Temp Out I I 9.30 9.30 ppg ppg Vise 48 sees API filt 4.4 ml HTHP 10.2 ml Mud Wt at Max Gas - -- PV 8 eP VI 26 Ibs/100ft2 Gels ~ / ~ / ~ Ibs/1 00ft2 pH 8.0 Sd I STX-30CD Bit Size: 60 Hrs. On Bit: Jets: 15 \ 15 \ 15 \ \ \ TFA: 0.5180 ------ Total Revs on Bit: 138Krevs Footage for Bit Run 530 I Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: [ %LCM I [ I I f I I I I I I ppg 0.1 % ppm ppm ft I f ~ustomer: BP Alaska f Report No.: 30 , Well: NorthStar NS 14 Date: 2/5/02 sper"""V- sun Area: North Slope Depth 13020 Lease: NorthStar NS 14 Footage Last 24 hrs: 0 DRILLING seRVIc::es Rig: Nabors 33E Rig Activity: Run 4.5" Liner Mudlogger's Morning Report I Job No.: AK AM 22002 Report For: Gavin Kidd Shows: I I ( Current 24 hr Avg 24 hr Max Pump and Flow Data na ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow na units unit~ ( units @ ) Pump 2 spm Total flow Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC I I 9.30 9.30 ppg ppg Vise 46 sees API filt 5.0 ml HTHP 11.8 ml Mud Wt at Max Gas - -- PV 9 cP VI 24 Ibs/100ft2 Gels 8 / 10 / 11 Ibs/100ft2 pH 8.0 Sd --- I I Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: Short Trip Depth 13020 ft Short Trip Gas: 27 u Mud Cut: ppg Short Trip CI: Tight Spots: to to to Feet of Fill on Bottom: - 1;'li;lilil;iillli;\lilli'iillllilili!l!ii;ilill:i;ililili!lliIIII;il!il;;'i¡i;ii'ilillilli,iili;ililil;lillliillll¡:i!ililillilili;liili;ii'ii;j;;ii;ililiillillillil;illi,ilili;i;;liil¡;lli'ililililj;;I{,!i;ili;ililiil'ilil;l¡nIII;lli;;!i!!','Ii!illilill:l!ii!lj;II;!lili¡jili¡;i,jl;l:lili,!ililIl:lililllilli]i'!]i!ili!;lil;iIlil'iUIWII;;!!11li!i!II;;ilillililijililli;ili;lIlli;iliillli!llijilil;ill'll,i;ilii!ll;@illjiIIiilIHiIMllil¡!!llil1¡"jililli!i'Ii!ii;il;illii;ili¡WI,jilill¡jililililli:li!iili!illilill:jIIli!lililijii;{I;lilliillliilli;jiliWilliliPlliIIJiWllijijiit\!liiii,'lli Current Lithology: % % % % %LCM I I I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units ppg ppg ppg Drilling Breaks before Drill Rate during after before Gas during after Cgl % Lithology Sst Sh Sitst I I Depth to to ---- ---- ---- ---- I I I I Ivishak @ 12653' M D, 10895' TVD Kavik @ 12980' MD, 11206' TVD Logging Engineer: Dol.!9 Wilson I Tom Mansfield * 10000 units = 100% Gas In Air I I I I .Schlumberger ~ ( 6HA# 1 I Job # 40007081 Date In 09-Jan-02 Date Out 09-Jan-02 Hole Size 16 Customer BP ADW Time In 0:01 Time Out 8:00 Hole Sect Surface Well NS14 Depth In 199 Depth Out 333 Bha Type Clean out Field Northstar TVD In 199 TVD Out 333 Hrs BRT 8.0 Rig Nabors 33E Drlg Hrs 1.2 Drlg Ft 134 Avg ROP 112 AFE # 831310 Slide Hrs 0.5 Slide Ft 40 Slide ROP 80 DD's Tunnell/Rinke Rot Hrs 0.7 Rot Ft 94 Rot ROP 134 Co. Men Kidd/Dinger Pump Hrs 1.8 Rotate % 70 Slide % 30 PDM Run # 1 R/S 5/6 PDM Jet Blk Inclln 0.01 Az In Bit>Svy 28.00 PDM SeTH 962-3561 Stages 3.0 Bearing Mud InclOut 1.64 Az Out 78.78 T/F Corr PDMSize 9 5/8 Rev/Gal 0.110 Rubber RM100D AvgDls 1.0 MaxDls 1.1 PlanDis Mud Type SeaH20 Spud Mud Wt Sand % RPM 50 GPM 450 SPP On: 270 BHT F Mud Vis Solids % Rot TO 3 WOB 5 SPP Off: 320 '. Item ..'.. ".'..Description .' Vendor SIN ....'.." ..".. . DD ..: ..........10 ...".....StabQDF.N.i ..' .CQnn'ectiof}"Length ..CumLength MX-C1 1 TFA=1.031 HTC T25DC 16 3x20,1 x12 7518 Reg P 1.35 1.35 9 5/8 Std PDM 1.83° 7 5/8 Reg B 2 *Float Ana 962-3561 9 5/8 Tool 15 7/8 15.70 6518 H-90 B 26.60 27.95 Orienting Sub 6 5/8 H-90 P 3 Ana GLDD-105 8 2 1/2 6518 H-90 B 1.45 29.40 MONEL STAB 6518 H-90 P 4 Ana 800-011-SB 8 2 7/8 16 2.40 6518 H-90 B 5.87 35.27 MONEL LC 6518 H-90 P 5 Ana 810-001-LC 8 1/16 2 13/16 6518 H-90 B 10.45 45.72 MONEL LC 6518 H-90 P 6 Ana 810-009-LC 8 2 7/8 6518 H-90 B 9.74 55.46 MONEL STAB 6518 H-90 P 7 Ana 800-010-SB 8 2 7/8 16 2.40 6518 H-90 B 5.63 61.09 X-OVER 6 5/8 H-90 P 8 *Corrosion Ring Ana ANA614 7 x 8 2 7/8 1.20 4 1/21F B 3.09 64.18 26 Jts. HWDP 5" 4112 IF P 9 NAD 26 HWDP 5 3 4 1/2 IF B 788.74 852.92 if i . I Illiil:fI:I~~II..illllilil~;L Clean out 20" conductor. Gyro survey conductor. Expect conductor to be straight. IADC # 115 Motor 36.6 38.4 ~onductor was not straight, slide 40 feet to correct Footage 134 Jars 1 .2 Hrs 1.2 Bit #1 23.6 24.8 Pick up MWD tool and rest of BHA k Revs 6 k 1.8 Grade Green ~~. Comment Will re-run i i I I I I I ( I [ ( I I I I I I t Schlurnberger r Job # 40007081 "I, ' Customer 8P ADW I Well NS14 'I Field Nmthstar Rig Nabors 33E I AFE # 831310 , l DD's Tunnell/Rinke Co. Men Kidd/Clump I ;"-,1\11 Run # 2 , JM ser# 962-3561 , JM Size 9 5/8 I' t:'"Jd rype SeaH20 Spud I BHT F 75 Item Description MX-C1 r 1 TFA=1.031 , 9 5/8 Std PDM 1 .830 2 *Float MONELLC (~ ~ (2 L 6 MONEL LC MONEL STA8 MWD r ,:, ,/ :,' Orienting Sub MONEL STA8 i I ',; ~ (-19 J-1J I~ ~ 13 (-11 115 I .'-:-:. ~ , I .. t I J ~HA Expected Behavior: MONEL DC MONEL DC MONEL STA8 MONEL DC *Corrosion Ring HYDJARS 26 Jts. HWDP 5" DP 5" to Surface RIS 5/6 Stages 3.0 RevlGal 0.100 Mud Wt 9.4 Mud Vis 84 Vendor HTC Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana Ana DAI LEY NAD NAD SIN T25DC 962-3561 810-001-LC 810-009-LC 800-011-S8 169 GLDD-105 800-007 -S8 831-009DC 831-002DC 800-010-S8 831-019DC 1417-1119 26 HWDP DP 6/100 sliding hold rotating IdHA Actual Behavior: I ~omments I Reason for Trip: [ I .I ':[) As expected TD Date In 09-Jan-02 Time In 8:30 Depth In 333 TVD In 333 Drlg Hrs 20.6 Slide Hrs 5.7 Rot Hrs 14.9 Pump Hrs 31.0 PDM Jet Blk Bearing Mud Rubber RM100D Sand % 4 Solids % 6 OD ID 16 3x20.1 x12 9 5/8 Tool 8 1/16 2 13/16 8 2 7/8 8 2 7/8 8 1/4 3 1/4 8 2 1/2 8 2 7/8 7 15/16 2 13/16 7 7/8 2 13/16 8 2 7/8 8 2 13/16 7 5/8 3 5 3 5 4 8/29 ¡ IA # Date Out 11-Jan-02 Time Out 6:00 Depth Out 3316 TVD Out 3223 Drlg Ft 2983 Slide Ft 645 Rot Ft 2338 Rotate % 78 Inclln 1.64 Az In 78.78 InclOut 34.64 Az Out 300.23 Avg Dls 2.6 Max Dls 4.5 RPM 60 GPM 900 Rot TO 7 K nibs WOB 30 Stab OD F.N. I Connection 15 7/8 15.70 7 5/8 Reg P 7 5/8 Reg 8 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H90 P 6 5/8 H90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 8 6 5/8 H90 41/2 IF 4112 IF P 41/2 IF B 4112 IF P 41/2 IF 8 16 2.40 2.29 16 2.39 16 2.40 1.66 Bit Data IADC # 117 Footage 2983 Hrs 20.6 k Revs 165 k - Grade 1-3-WT-H-E-1-NO-TD Comment Good Run 2 Hole Size 16 Hole Sect Surface Bha Type Steerable Hrs BRT 45.5 Avg ROP 145 Slide ROP 113 Rot ROP 157 Slide % 22 Bit>Svy - TIF Corr 198.0 Plan Dls 2.5 SPP On: 2200 SPP Off: 2100 Length I Cum Length 1.35 26.60 10.45 9.74 5.87 29.85 1.45 5.62 30.84 30.70 5.63 30.51 31.50 788.74 Tool Motor Jars Bit #1 Hrs. In 38.4 90.0 24.8 1.35 27.95 38.40 48.14 54.01 83.86 85.31 90.93 121 .77 152.47 158.10 188.61 220.11 1008.85 1008.85 Hrs. Out 69.4 110.6 45.4 31.0 I Schlumberger Ii \ i IA # 3 I r Job # 40007081 Date In 13-Jan-02 Date Out 16-Jan-02 Hole Size 12 1/4 Customer BP ADW Time In 15:00 Time Out 19:00 Hole Sect Intermediate Well NS 14 Depth In 331 6 Depth Out 6899 Bha Type Stee rable I Field Northstar TVD In 3223 TVD Out 6032 Hrs BRT 76.0 Rig Nabors 33E Drlg Hrs 28.4 Drlg Ft 3583 Avg ROP 126 AFE # 831310 Slide Hrs 2.8 Slide Ft 305 Slide ROP 109 l DD's Rinke Rot Hrs 25.6 Rot Ft 3278 Rot ROP 128 ,-- Co. Men Kidd/Clump Pump Hrs 47.0 Rotate % 91 Slide % 9 ~ _~'M Run # 2 R/S 3/4 PDM Jet Blk Inclln 36.64 Az In 300.23 Bit>Svy 63.08 JM SetH 962-1056 Stages 4.5 Bearing Mud InclOut 39.23 Az Out 300.21 T/F Corr 144.0 . - JM Size 9 5/8 Rev/Gal 0.200 Rubber RM 1 OOD A vg Dis Max Dis Plan Dis . I ;Jd Type Seawater Mud Wt 9.2 Sand % Tr RPM 100 GPM 950 SPP On: 2550 BHT F Mud Vis 51 Solids % 5 Rot TQ 11 K ftlbs WOB 30 SPP Off: 2350 . Item Description Vendor SIN OD ID Stab OD F.N. Connection Length Cum Length I Bit #2 FGXIC 1 TFA=1,058 STC MJ6428 12 1/4 1X162X20 1X18 65/8RegP 1.00 1.00 95/8 Std PDM 1.15° 65/8 Reg B I 2 *Float Ana 962-1056 9 5/8 Tool 12 1/8 17.78 6518 H-90 B 26.74 27.74 I MONEL LC 6 5/8 H-90 P 3 Ana 805-005-LC 8 2 7/8 6518 H-90 B 5.00 32.74 MONEL LC 6 5/8 H-90 P I 4 Ana 810-003-LC 8 2 7/8 65/8 H-90 B 9.72 42.46 I MONEL STAB 65/8 H-90 P 5 Ana 800-002-SB 8 2 7/8 12 1/8 2.40 6518 H-90 B 5.55 48.01 l MWD 6 5/8 H90 P 6 Ana 169 8 1/4 3 1/4 2.29 65/8 H90 B 29.85 77.86 - , MONEL STAB 6 5/8 H-90 P ':"f Ana 800-017-SB 8 2 7/8 12 1/16 2.40 65/8H-90B 5.49 83.35 IT MONEL DC 6 5/8 H-90 P . .' Ana 831-009DC 7 15/16 2 13/16 65/8 H-90 B 30.84 114.19 , , MONEL DC 6518 H-90 P I 9 Ana 831-002DC 7 7/8 213/16 65/8H-90B 30.70 144.89 r MONEL STAB 6518 H-90 P 10 Ana 800-013-SB 8 2 7/8 12 2.45 65/8 H-90 B 5.44 150.33 MONEL DC 65/8 H-90 P I 11 'Corrosion Ring* Ana 831-019DC 8 2 13/16 65/8 H-90 B 30.51 180.84 r HYD JARS 6 5/8 H90 12 DAILEY 1417-1119 7 5/8 3 1.66 41/21F 31.50 212.34 26 Jts. HWDP 5" 41/2 IF P I 13 NAD 26 HWDP 5 3 41/21F B 788.74 1001.08 ~ DART SUB 14 GM7996 1001.08 I DP 5" to Surface 41/2 IF P 15 NAD DP 5 4 8/29 4112 IF B 1001.08 r,.c. I r '~ J ~HA Expected Behavior: Hold while rotating Bit Data Tool Hrs. In Hrs. Out IADC # 117 Motor 43.8 90.8 .JHA Actual Behavior: As expected Footage 3583 Jars 110.6 139.0 I Hrs 28.4 Bit #2 28.4 ~omments / Reason for Trip: Bit to GR=61 ,09 k Revs 477 k 47.0 Grade 1-4-WT-M-E-2-NO-PR r Comment I I' 'r I r r I , I I ( t I I I I I I "'í.. ,J ,;',) I I I Job # 40007081 Date In 16-Jan-02 Date Out 23-Jan-02 Hole Size 12 1/4 Customer BP ADW Time In 19:00 Time Out 6:00 Hole Sect Intermediate Well NS14 Depth In 6899 Depth Out 10930 Bha Type Steerable I Field Northstar TVD In 6032 TVD Out 9314 Hrs BRT 155.0 Rig Nabors 33E Drlg Hrs 56,6 Drlg Ft 4031 Avg ROP 71 AFE # 831310 Slide Hrs 29.0 Slide Ft 907 Slide ROP 31 . DD's Rinke Rot Hrs 27.6 Rot Ft 3124 Rot ROP 113 .~o. Men Kidd/Clump Pump Hrs 93.5 Rotate % 77 Slide % 23 . ..' A Run # 3 RIS 3/4 PDM Jet Blk Inclln 36.64 Az In 300.23 Bit>Svy 83.79 PDM Ser# 962-1049 Stages 6.0 Bearing Mud Incl Out 30.26 Az Out 262.00 TIF Corr 327.2 I PDM Size 9 5/8 Rev1Ga10.200 Rubber RM100D Avg Dls Max Dls 2.5 Plan Dls 1.0 . Mud Type Seawater Pol. Mud Wt 10.2 Sand % RPM 80 GPM 800 SPP On: 3000 BHT F 170 Mud Vis 44 Solids % 10 Rot TQ 17 WOB 15 SPP Off: 2800 t Item Description Vendor SIN OD ID Stab OD F.N. Connection Length Cum Length DS69HFGLNPUV 1 Bit#3 TFA=1.035 HvcaloQ 201675 12 1/4 6x15 6518 Reg P 1.00 1.00 9 5/8 XP PDM 1.15° 6 5/8 Reg B I 2 .Float Ana 962-1049 9 5/8 Tool 12 1/8 16.29 65/8H-90B 31.10 32.10 I MONEL LC 6 5/8 H-90 P 3 Ana 810-003-LC 8 2 7/8 65/8H-90B 9.72 41.82 MONEL STAB 6518 H-90 P I 4 Ana 800-002-SB 8 2 7/8 12 1/8 2.40 6518 H-90 B 5.55 47.37 .1 LWD 6 5/8 H90 P 5 Ana 8044 8 5/16 15.13 65/8FHB 22.79 70.16 I' .. MWD 6 5/8 FH P ~. Ana 196 8 1/4 3 1/4 2.11 6518 H90 B 28.25 98.41 :. MONEL STAB 6 5/8 H-90 P Ana 800-017-SB 8 2 7/8 12 1/16 2.40 6518 H-90 B 5.49 103.90 r . MONEL DC 6 5/8 H-90 P 18 Ana 831-009DC 715/16 213/16 65/8H-90B 30.84 134.74 MONEL DC 6 5/8 H-90 P I' 9 Ana 831-002DC 7 7/8 2 13/16 6518 H-90 B 30.70 165.44 ;. MONEL STAB 6518 H-90 P 10 Ana 800-013-SB 8 2 7/8 12 2.45 65/8H-90B 5.44 170.88 MONEL DC 6 5/8 H-90 P 1 11 .Corrosion Ring Ana 831-019DC 8 2 13/16 6518 H-90 B 30.51 201.39 J HYD JARS 6 5/8 H90 12 DAILEY 1417-1119 7 5/8 3 1.66 4112 IF 31.50 232.89 26 Jts. HWDP 5" 4112 IF P 1 13 NAD 26 HWDP 5 3 41/21FB 788.74 1021.63 " DART SUB 14 GM7996 1021.63 I DP 5" to Surface 4112 IF P ¡ 5 NAD DP 5 4 8/29 4112 IF B 1021.63 I'>, ~. .: '. .I 'I ,I qHA Expected Behavior: Hold while rotating 5/100 sliding Bit Data Tool Hrs. In Hrs.Out IADC # Motor 68.4 161,9 '.aHA Actual Behavior: slight drop while rotating 2/100 sliding Footage 4031 Jars 139.0 195.6 I Hrs 56.6 Bit #3 56.6 ~omments I Reason for Trip: Bit to MWD GR=81.8 LWD GR=64.5 Res=53.5 k Revs 676 k 93.5 )WD=55.25 (TD) Grade 2-1-CT-A-X-IN-WT-TD I Comment Schlurnberger I IA # 4 " r I I I. I I I I I I [ I I I I '.' '.'. :, " .! .' . '.,;: I Schlumberger ~ I IA # 5 ! I Job # 40007081 Date In 26-Jan-02 Date Out 31-Jan-02 Hole Size 8 1/2 Customer BP ADW Time In 17:30 Time Out 6:30 Hole Sect Intermediate Well NS14 Depth In 10930 Depth Out 12490 Bha Type Steerable I Field Northstar TVD In 9914 TVD Out 10740 Hrs BRT 109.0 Rig Nabors 33E Drlg Hrs 28.2 Drlg Ft 1560 A vg ROP 55 AFE # 831310 Slide Hrs 9.2 Slide Ft 91 Slide ROP 10 L DD's Tunnell Rot Hrs 19.0 Rot Ft 1469 Rot ROP 77 , . Co. Men Polya/Dinger Pump Hrs 62.9 Rotate % 94 Slide % 6 pnM Run # 4 R/S 4/5 PDM Jet Blk Inclln 30.26 Az In 262.00 BibSvy 74.00 '::-:(~-'!JM Ser# 675-3690 Stages 7.0 Bearing Mud InclOut 14.72 Az Out 269.46 T/F Carr 78.0 . . "< I :".'::"JDM Size 6 3/4 Rev/Gal 0.500 Rubber RM100D Avg Dis 1.9 Max Dis 2.2 Plan Dis 0.8 I ',- Mud Type KCL Polymer Mud Wt 12.3 Sand % tr RPM 100 GPM 550 SPP On: 2400 BHT F 151 Mud Vis 54 Solids % 15 Rot TO 20 WOB 15 SPP Off: 2800 " Item Description Vendor SIN OD ID Stab OD F.N. Connection Length Cum Length I Bit #4 DS70FNPV 1 RR#3TFA=.907 Hvcaloq 200347 8 1/2 3x15.3x13 41/2 Reg P 1.00 1.00 6 3/4 XP 1 .15 4 1/2 Reg B I 2 *Float Ana 675-3690 6 3/4 Tool 8 3/8 20.05 4112 XH B 26.53 27.53 I NM LEAD 41/2 XH P 3 675-10-004LC 6 3/4 2 13/16 41/2 XH B 9.80 37.33 NM STABILIZER 41/2 XH P I 4 Ana 675-004SB 6 3/4 2 13/16 8 112 2.42 41/2 XH B 5.70 43.03 I CDR (PWD) 4 1/2 XH P 5 Ana 659 6 3/4 Tool 6.80 51/2 FH B 21.59 64.62 I MWD 51/2 FH P 6 Ana 750 6 3/4 Tool 6.90 4112 XH B 27.82 92.44 NM STABILIZER 41/2 XH P , ) '.. *Baffle plate Ana 675-011 SB 6 3/4 2 13/16 8 1/2 2.45 41/2 XH B 5.62 98.06 t:/¡,:' NM FLEX 4 1/2 XH P I <} 675-31-016FC 63/4x5 213/16 2.50 41/2XHB 31.01 129.07 . ,',;' NMFLEX 41/2XHP 'II 9 675-31-014FC 6 11/16x5 2 13/16 2.50 41/2 XH B 31.02 160.09 ,II NM FLEX 4112 XH P 10 675-31-021FC 63/4x5 213/16 2.50 41/2XHB 31.02 191.11 X-OVER 4 1/2 XH P 'I 11 *Corrosion Ring Ana GLDD1042 6 3/4 2 3/4 41/2 IF B 1.98 193.09 ,I 3Jts HWDP 41/21F P 12 NAD (3) 5" HWDP 5 3 4112 IF B 91.00 284.09 HYD JARS 4112 IF P 113 DAILEY 1416-1574 61/2 23/4 1.69 41/21FB 32.63 316.72 ," 23 Jts HWDP 41/2 IF P 14 NAD (23) 5" HWDP 5 3 4112 IF B 697.73 1014.45 I Dart Valve Sub 4 1/2 IF P 15 BPX GM11240 6 3/4 31/8x41/2 41/21FB 2.38 1016.83 DP 5" to Surface 41/2 IF P ,16 NAD DP 5 4 8/29 4112 IF B 1016.83 t', '<. ",:.q '::\~ '. ;;:.. '. J 1 J qHA Expected Behavior: Slight drop while rotating .5°/100 Bit Data Tool Hrs. In Hrs. Out IADC # Motor 62.9 '.òHA Actual Behavior: Dropped likce a rock Footage 1560 Jars 16.1 44.3 r Hrs 28.2 Bit #4 31.2 59.4 ~omments I Reason for Trip: Reached planned TD k Revs 579 k 62.9 Grade 1-1-WT-A-X-I-CT-PTD 'I' Comment ! I I I ( I I I I I I I ! [ ! I I i :';q: ~ Schlumberger I Job # 40007081 I' Customer BP ADW ¡ " Well NS14 ~ '" " Field Nõrthstar Rig Nabors 33E AFE # 831310 DD's Tunnell Co. Men Kidd/Dinger . r. PDM Run # 5 , PDM SetH ~603 I PDM Size 4 3/4 Mud Type Drill-N r BHT F 155 . Item Description Bit #5 STX-30CD 1--1 ~ f~ L".:J , . r .- I 4 3/4 PDM SSS 1.15 Float NM Flex LC NM IB Stab I I 4.75 ARC I ";1 SLIM PLUSE MWD f~ 4.75 ADN ,I ¿ r I 10 ~ 11 NMDC NM DC PBL Sub HYDJAR Corrision ring XO 12 L_1~ I :"',',',:': '"t , :,+ 14 Jts HWDP 69 Jnts. DP 4" XO i.. ..'- I~ ~ I 17 I~ I Dart Valve Sub DP 5" to Surface R/S 7/8 Stages 2.0 Rev/Gal 0.300 Mud Wt 9.1 Mud Vis 50 Vendor HTC Ana Ana Ana Ana Ana Ana Ana Ana SIN R71 JL 475-2603 975301 60060811SZ 475-061 SPRM-28419 ADN-124 475-31-003DC 475-31-002DC Daliey I NOR475BP64 1400-1177 DAILEY NAD NAD NAD BPX BPX NAD NR400 001 B 4" HWDP 69DP 4 HT27872 GM11240 DP Date In 02-Feb-02 Time In 15:00 Depth In 12490 TVDln 10741 Drlg Hrs 15.5 Slide Hrs 4.2 Rot Hrs 11.3 Pump Hrs 33.1 PDM Jet 8 Bearing OSB Rubber RM100D Sand % 0.1 Solids % 4.5 OD ID 6 1/8 3x15 4 3/4 Tool 4 5/8x3 9/16 2 1/4 4 3/4 2 1/4 4 3/4 2 1/4 4 3/4 2 1/4 4 3/4 2 1/2 4 3/4 2 5/16 4 3/4 2 1/4 4 3/4 2 1/2x1 1/2 4 3/4 2 1/4 5 1/8 2 5/8 4 2 11/16 4 3 5/16 6 1/4 2 1/2 6 3/4 3 1/8x4 1/2 5 4 8/29 II '!HA Expected Behavior: I Hold rotating ahead aHA ActualBehavior: Held in Shublik, Dropped 1.1/100 in Ivasik " ~~!nments / Reason for Trip: ~ , :¡::') D&I=77.40, GAMMA=48.58, RES=43.66, POR=104.30, DEN=101.05 "'" ,~: .. ,. I ,';, i ]A # Date Out 05-Feb-02 - Time Out 18:30 - Depth Out 13020 TVD Out 11244 Drlg Ft 530 Slide Ft 91 Rot Ft 439 Rotate % 83 Inclln 14.72 Az In 269.46 InclOut 17.19 Az Out 258.81 A vg Dls 1.1 Max Dls 1.4 RPM 80 GPM 340 Rot Ta 13 WOB 25 Stab OD ~ F.N. I Connection 6 17.85 6 2.15 1.70 1.54 5 13/16 1.34 1.82 3112 Reg P 3112 Reg B 3112 IF B 3112 IF P 3112 IF B 3112 IF P 3 1/2 IF B 3112 IF P 3112 IF B 3 1/2 IF P 3 1/2 IF B 3112 IF P 3112 IF B 3112 IF P 3112 IF B 3112 IF P 3112 IF B 3112 IF P 3112 IF B 3112 IF P 3112 IF B 3112 IF P HT 40 B HT 40 P HT 40 B HT 40 P HT 40 B HT 40 P 41/2 IF B 4112 IF P 4112 IF B 4112 IF P 4112 IF B 6 Hole Size 6 1/8 - Hole Sect Production Bha Type Steerable Hrs BRT 75.5 A vg ROP 34 Slide ROP 22 Rot ROP 39 Slide % 17 Bit>Svy 77.40 T/F Carr 311.0 Plan Dls 2.0 SPP On: 1800 SPP Off: 21 00 Length I Cum Length 0.75 0.75 23.52 24.27 7.69 31.96 4.87 36.83 24.15 60.98 33.87 94.85 26.68 121.53 31.01 152.54 30.91 183.45 8.13 191.58 29.58 221 . 16 2.54 223.70 430.03 653.73 2170.63 2824.36 2.47 2826.83 2.38 2829.21 2829.21 Bit Data IADC # Footage 530 Hrs 15.5 k Revs 149 k . - Grade 3-3-WT-A-E-1/16-BT-PTD Comment Tool Motor Jars Bit #5 Hrs. In 0.0 0.0 0.0 Hrs. Out 33.1 15.5 15.5 33.1 - - - --... ~ ~ - - - ...- - ~ ,.--., - - - - - DRilliNG SERVICES BHA # Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out ftlhr % GRADE 1 1 MX-C1 T25DC 16 1.031 199 333 134 1.2 110 50 6K 30 GREEN-WILL RERUN I 2 1RR MX-C1 T25DC 16 1.031 333 3316 2983 20.6 145 60 165K 22 1-2-WT-H-E-1-NO-TD 3 2 FGIXC MJ6428 12.25 1.058 3316 6899 3583 28.4 126 100 477K 9 1-4-WT-M-E-2-NO-PR 4 3 DS69HFGLNPUV 201675 12.25 1.035 6899 10930 4031 56.6 71 80 676K 23 2-1-CT-A-X-IN-WT-TD 5 4 DS70FNPV 200347 8.5 .907 10930 12490 1560 28.2 55 100 579K 6 1-1-WT-A-X-I-CT-PTD I 6 5 STX-30CD R71JL 6.125 .518 12490 13020 530 15.5 34 80 149K 17 3-3-WT-A-E-1/16-BT-PTD I ! I I i I ¡ I I I , i I i i i i i i i i .. -~~> '-". _..~ - - - - sperry-sun DRilliNG SERVICES Waterbase Mud Record Date JG/U" mmI ---oT ~ 1m1 01/17102 un. O/U" ""ð17m "'11 7H1 1mJr mm7 '100M ""J/ 'fm Depth ft ""'2m- '1'mf' '3fI6 MW Vis 1 PV . imi ""§:'f ~ ~ . 9 T 15" 23 "H' 54118 - -- YP 7 23 26 - ~ - - Customer: BP ALASKA Well: NORTHSTAR NS14 Area: BEAUFORT SEA, ALASKA Lease: NORTHST AR Rig: NABORS DRILLING RIG 33E Mud Company: BAROID DRILLING FLUIDS Job No.: AK-AM 22002 Gels - Oil 1 Water 1 Sd Fltr HTHP I Cake 1 Sol % % 7:5 "'§:ã 11m' 9:4 §3" rr:'T 6.0 "U Ti 4A 13.6 14:'Ø" 1'IT :& 1r I4:õ '1'G' ---ro:z . ~ m :B'" "Dr 2ð" = . , ,. ,. . v. T. 3:r 3:r "'ß' 4. 4. . U. õ'. . . . . . . ~ )J . '.( -grn- % .5 m TI T. 11 13. n:rß" 0 ~ 7T ï!õ 1ß' ~ ~ ~ - CEC mgeIhg "'DT "'5:ð" pH -g:o- ãJr lJ:Olr 9.1 I 0.60 9]f T!' "'7:õ "!so- iB 1JD" -:::- uH:35 1)-:00 . 8.5 -ocflf -=--~-T ~:~~ "'D]'ð'" õ:õi "lJM "lJM - Casing Program Pm Pf / Mf . .0411 .0 .00/.05 .00/.60 .00/1.20 .30/1.00 -:B1] .00/1.80 .00/2.30 .00/2.5 .00/3.2 .2512.60 .20/2 40 . . "?/~ . .0213. 1Jm'. 2m". 1rm". . . .0413. i1nl .0mE' .021.044 .00/.25 0.00/.14 - - 20 133/811 9 5/811 711 - 4 1/211 Chlorides ppm 26500 20000 17000 16000 16000 17000 IßRr - inch at inch at inch at inch at inch at inch at Calcium -.. - - 201 - 3118 - 10908 12471 13018 ftl Comments 1720 œ -mr "ED" -mr "Rð' 'US' -m- l1IØ" 'lð ""Rõ Tm'" -m -m ~ "'1B 74õ .~'. O-RLG 12 1/4" 121/4" TO DRL~ 81/2" 81/2" TD DRLG61/8" 6 1/8" TD ~~'- rs "1iff "'ßB '"'ßß' -mrr l'DfIT rømr rømr rnm- 10930 10930 Ißß" J=g. 42 ~~::~ '. 11895 i:FJ I j~:~ 12490 12606 13020 LB/100 10S/10M mll30 17/19 15/23 15/22 15/23 8/19 8/9 10/14 11i14 12i16 1"2i11 14'i1i 1õiii ~: I 5It!. 11/20 12/26 12/20 []! 8/14 g¡:¡¡ g¡:¡¡ Z!lD:!! 1 0/34 ~ 11/35 14136 1õi2s 1õi2i 7i9 12ii4 1i12 Iii ~ ( '\ ~, I I r: I (I L I Survey Client: BPXA Reid: Northstar Structure: Northstar PF Well: NS.14 Borehole: NS14 UWI/API#: Date: Grid Convergence: Scale Factor: Survey Computation Method: DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference: January 24, 2002 1.23170967° 0.99992902 Magnetic Declination: Total Field Strength: Dip: Declination Date: Magnetic Declination Model: North Reference: Coordinate Reference To: Minimum Curvature Lubinski 285.810" N 0.000 ft, E 0.000 ft Borehole: KB 55.8 ft above MSL 26.574° 57511.700 nT 80.928° January 07, 2002 BGGM 2001 True North Wellhead (True) Location: N 70 29 27.977, W 148 41 35.865 : N 6030951.560 ftUS, E 659830.670 ftUS Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Comment MD Inti Azim TVD VSec NS EW Closure CIAzim DLS Tie-In 0.00 0.00 70.00 0.00 0.00 0.00 0.00 0.00 0.00 I ~dg 1/100 50.00 0.30 24.52 50.00 -0.02 0.12 0.05 0.13 24.52 0.60 :WRO 100.00 0.39 13.11 100.00 -0.03 0.40 0.15 0.43 20.03 0.23 GYRO 150.00 0.65 12.61 150.00 -0.01 0.85 0.25 0.88 16.32 0.52 GYRO 200.00 1.18 3.63 199.99 0.12 1.64 0.34 1.67 11.81 1.09 I ~YRO 295.00 1.65 78.78 294.97 -0.90 2.88 1.75 3.37 31.23 1.86 I3YRO 375.00 1.75 76.40 374.93 -2.99 3.39 4.06 5.29 50.15 0.15 GYRO 453.00 2.20 74.43 452.89 -5.30 4.07 6.66 7.81 58.56 0.58 I ~YRO 545.00 2.06 75.02 544.82 -8.23 4.97 9.96 11.13 63.46 0.15 " ~YRO 635.00 1.99 74.55 634.77 -10.95 5.81 13.03 14.27 65.97 0.08 GYRO 725.00 1.36 79.39 724.73 -13.25 6.42 15.59 16.86 67.61 0.72 [ ,YRO 820.00 1.78 74.79 819.69 -15.52 7.02 18.12 19.43 68.83 0.46 ~YRO 910.00 2.24 70.11 909.64 -18.15 7.98 21.12 22.58 69.30 0.54 .3YRO 1005.00 2.47 71.40 1004.56 -21.34 9.27 24.81 26.48 69.52 0.25 GYRO 1098.00 2.19 71.14 1097.48 -24.46 10.48 28.39 30.26 69.74 0.30 I ;~~g 1195.00 2.05 73.17 1194.41 -27.44 11.58 31.80 33.84 69.99 0.16 1290.00 2.01 74.20 1289.35 -30.29 12.53 35.03 37.20 70.32 0.06 ' GYRO 1385.00 1.60 74.96 1384.31 -32.85 13.32 37.92 40.19 70.64 0.43 r '-"YRO 1480.00 1.53 79.22 1479.27 -35.12 13.91 40.44 42.77 71.02 0.14 ~YRO 1575.00 0.63 35.96 1574.25 -36.44 14.57 41.99 44.45 70.87 1.22 GYRO 1667.00 1.28 303.69 1666.24 -35.63 15.54 41.44 44.26 69.44 1.57 I ~YRO 1765.00 1.33 305.36 1764.22 -33.52 16.81 39.60 43.02 67.00 0.06 I ~YRO 1860.00 2.32 299.62 1859.17 -30.61 18.40 37.03 41.35 63.58 1.06 ~YRO 1955.00 3.20 294.09 1954.06 -26.12 20.43 32.94 38.76 58.19 0.97 GYRO 2050.00 3.43 294.90 2048.90 -20.69 22.71 27.94 36.00 50.89 0.25 I ~YRO 2145.00 4.49 300.59 2143.67 -14.29 25.80 22.16 34.01 40.66 1.19 ~YRO 2240.00 6.62 302.08 2238.22 -5.44 30.60 14.32 33.78 25.07 2.25 GYRO 2335.00 9.47 303.45 2332.28 7.27 37.82 3.15 37.95 4.77 3.01 GYRO 2430.00 12.58 302.42 , 2425.51 24.64 47.67 -12.10 49.19 345.75 3.28 I ~YRO 2525.00 16.01 302.18 2517.56 47.13 60.20 -31.93 68.15 332.06 3.61 GYRO 2549.00 16.42 302.65 2540.60 53.55 63.79 -37.59 74.05 329.49 1.79 GYRO 2620.00 18.28 301.66 2608.37 73.87 75.05 -55.52 93.36 323.51 2.65 I ¡O,:d MWD 2646.76 19.52 301.01 2633.68 82.22 79.56 -62.92 101.44 321.66 4.70 2740.95 21.84 297.51 2721.80 114.57 95.76 -91.95 132.76 316.16 2.79 ,',.." 2836.10 23.56 296.52 2809.58 150.58 112.43 -124.67 167.88 312.05 1.85 " . ',\':ii', , I 2929.42 26.17 297.80 2894.24 189.05 130.36 -159.57 206.05 309.25 2.86 I NS14_Final_surveys.xls Page 1 of 3 **Projections and Interpolations in Italics** 2/26/02-2:59 PM 1'1 I ,'I ~ ( J, \1 3024.95 28.94 297.79 2978.93 232.27 150.96 -198.66 249.51 307.23 2.90 3116.52 31.52 299.35 3058.04 277.22 173.03 -239.13 295.16 305.89 2.94 I 3210.78 33.92 299.01 3137.34 326.79 197.86 -283.61 345.81 304.90 2.55 3243.14 34.63 298.45 3164.08 344.55 206.62 -299.59 363.93 304.59 2.40 3409.19 34.81 297.54 3300.56 437.00 251.01 -383.10 458.01 303.23 0.33 I 3505.69 35.87 296.26 3379.28 491.77 276.26 -432.88 513.52 302.55 1.34 3599.66 37.20 294.81 3454.78 546.91 300.36 -483.36 569.08 301.86 1.69 3692.32 39.11 293.81 3527.64 603.52 323.92 -535.53 625.87 301.17 2.17 3788.78 39.30 294.22 3602.39 663.87 348.73 -591 .22 686.41 300.53 0.33 I 3883.95 38.76 294.72 3676.32 723.11 373.55 -645.77 746.03 300.05 0.66 3978.58 38.20 293.50 3750.40 781.38 397.61 -699.51 804.62 299.61 1.00 4074.07 37.49 294.05 3825.80 839.40 421.23 -753.12 862.92 299.22 0.82 4168.06 38.88 294.27 3899.68 896.88 445.01 -806.14 920.81 298.90 1.49 I 4263.22 39.16 294.59 3973.61 956.12 469.79 -860.68 980.55 298.63 0.36 4360.67 38.90 294.22 4049.31 1016.80 495.14 -916.57 1041.76 298.38 0.36 4457.04 38.96 294.00 4124.28 1076.72 519.88 -971.84 1102.16 298.14 0.16 I 4553.67 39.15 293.78 4199.32 1137.00 544.54 -1027.51 1162.88 297.92 0.24 4647.36 39.54 295.58 4271.78 1195.68 569.34 -1081.47 1222.18 297.76 1.29 4741.90 39.38 295.79 4344.77 1254.87 595.38 -1135.62 1282.23 297.67 0.22 I 4837.85 38.95 295.00 4419.16 1314.62 621.37 -1190.36 1342.78 297.56 0.69 4931.72 39.14 295.50 4492.06 1372.95 646.59 -1243.84 1401.87 297.47 0.39 5027.86 38.66 297.78 4566.89 1432.24 673.65 -1297.80 1462.22 297.43 1.57 5122.11 38.46 297.37 4640.59 1489.76 700.85 -1349.88 1520.97 297.44 0.34 I 5218.11 38.23 298.87 4715.88 1547.94 728.92 -1402.40 1580.52 297.46 1.00 5310.92 38.02 297.94 4788.89 1603.86 756.17 -1452.80 1637.81 297.50 0.66 5408.65 38.05 297.86 4865.87 1662.74 784.35 -1506.02 1698.03 297.51 0.06 I 5503.46 38.23 298.32 4940.44 1719.95 811.92 -1557.67 1756.58 297.53 0.35 5597.85 38.42 298.62 5014.49 1777.06 839.82 -1609.13 1815.10 297.56 0.28 5693.08 38.63 297.81 5088.99 1834.99 867.87 -1661.39 1874.41 297.58 0.57 [ 5788.24 38.48 298.94 5163.41 1892.88 896.05 -1713.58 1933.71 297.61 0.76 5883.28 38.63 299.40 5237.73 1950.51 924.92 -1765.30 1992.93 297.65 0.34 5977.40 38.50 299.97 5311.32 2007.47 953.98 -1816.27 2051 .57 297.71 0.40 6075.27 38.58 301 .40 5387.87 2066.41 985.10 -1868.71 2112.46 297.80 0.91 I 6171.62 37.94 301.36 5463.53 2123.88 1016.16 -1919.65 2172.01 297.89 0.66 6266.25 38.09 301.81 5538.08 2179.96 1046.69 -1969.29 2230.17 297.99 0.33 6362.40 38.01 301.43 5613.80 2236.98 1077.76 -2019.76 2289.32 298.08 0.26 I 6453.66 37.89 301.54 5685.76 2291.02 1107.07 -2067.62 2345.34 298.17 0.15 6548.11 38.78 300.05 5759.85 2347.61 1137.05 -2117.94 2403.86 298.23 1.36 6643.96 39.07 299.80 5834.42 2406.01 1167.10 -2170.13 2464.06 298.27 0.34 [ 6736.59 38.91 299.81 5906.41 2462.56 1196.07 -2220.71 2522.32 298.31 0.17 6831.83 39.23 300.21 5980.36 2520.75 1226.09 -2272.68 2582.32 298.35 0.43 6926.21 38.95 299.35 6053.61 2578.50 1255.65 -2324.33 2641.81 298.38 0.65 7021.08 38.83 299.32 6127.45 2636.41 1284.83 -2376.26 2701.37 298.40 0.13 7115.55 38.45 299.22 6201.24 2693.78 1313.67 -2427.72 2760.35 298.42 0.41 I 7211.15 38.32 299.06 6276.18 2751.55 1342.57 -2479.56 2819.71 298.43 0.17 7306.51 38.36 299.16 6350.97 2809.11 1371.35 -2531 .25 2878.86 298.45 0.08 7401.99 38.55 299.27 6425.74 2866.87 1400.33 -2583.07 2938.23 298.46 0.21 I 7496.25 38.77 299.37 6499.35 2924.13 1429.17 -2634.41 2997.11 298.48 0.24 7591.27 38.49 299.35 6573.58 2981.80 1458.25 -2686.11 3056.42 298.50 0.29 7688.26 38.17 299.10 6649.66 3040.31 1487.62 -2738.61 3116.57 298.51 0.37 I 7783.31 37.93 299.10 6724.51 3097.32 1516.11 -2789.80 3175.15 298.52 0.25 7877.79 37.56 298.92 6799.22 3153.63 1544.16 -2840.38 3232.98 298.53 0.41 7972.53 37.41 297.64 6874.40 3209.92 1571.48 -2891.15 3290.63 298.53 0.84 8064.07 37.12 296.96 6947.25 3264.24 1596.90 -2940.40 3346.05 298.51 0.55 I . NS14_Final_surveys.xls Page 2 of 3 **Projections and Interpolations in Italics** 2/26/02-2:59 PM :~ :, Ii ,', f "I ',:, 'I ~ 8161.93 37.06 295.61 7025.31 3322.27 1623.03 -2993.31 3405.02 298.47 0.83 8256.66 36.87 293.95 7101.00 3378.53 1646.91 -3045.02 3461.86 298.41 1.07 I 8351.69 36.57 293.69 7177.18 3434.79 1669.86 -3097.00 3518.50 298.33 0.36 8445.77 36.14 291.96 7252.95 3490.14 1691.49 -3148.40 3574.01 298.25 1.18 8539.20 35.68 291.61 7328.62 3544.64 1711.83 -3199.28 3628.47 298.15 0.54 I 8635.89 35.10 292.19 7407.44 3600.32 1732.71 -3251 .24 3684.14 298.05 0.69 8731 .32 34.79 290.19 7485.67 3654.73 1752.47 -3302.20 3738.40 297.95 1.24 8826.04 34.25 289.32 7563.71 3708.28 1770.62 -3352.71 3791.54 297.84 0.77 8921.95 34.05 288.55 7643.09 3762.04 1788.09 -3403.64 3844.74 297.72 0.50 I 9015.74 34.02 287.07 7720.81 3814.50 1804.14 -3453.61 3896.46 297.58 0.88 9110.36 34.18 286.59 7799.16 3867.54 1819.50 -3504.39 3948.59 297.44 0.33 9205.82 34.21 285.17 7878.12 3921.19 1834.18 -3555.99 4001.16 297.28 0.84 9302.76 34.63 285.26 7958.09 3975.98 1848.56 -3608.86 4054.76 297.12 0.44 I 9398.49 34.58 283.91 8036.88 4030.33 1862.25 -3661.47 4107.84 296.96 0.80 9491.99 34.53 282.06 8113.89 4083.29 1874.17 -3713.15 4159.32 296.78 1.12 9587.00 34.83 280.33 8192.02 4137.17 1884.66 -3766.17 4211.41 296.58 1.08 I 9683.87 34.72 277.37 8271.60 4192.00 1893.16 -3820.75 4264.06 296.36 1.75 9776.05 34.59 275.70 8347.43 4243.73 1899.13 -3872.82 4313.40 296.12 1.04 9872.37 34.43 273.42 8426.80 4297.24 1903.47 -3927.21 4364.19 295.86 1.35 9961 .34 34.90 271.69 8499.98 4346.49 1905.72 -3977.76 4410.71 295.60 1.23 I 10060.91 34.84 268.54 8581.68 4401.28 1905.83 -4034.67 4462.15 295.28 1.81 10158.37 34.38 264.29 8661.90 4453.47 1902.39 -4089.89 4510.68 294.95 2.52 10253.49 33.48 260.70 8740.83 4502.22 1895.47 -4142.51 4555.57 294.59 2.31 I 10344.74 33.21 259.68 8817.06 4547.44 1886.93 -4191.93 4597.04 294.23 0.68 10443.96 32.55 259.69 8900.39 4595.80 1877.28 -4244.93 4641.51 293.86 0.67 10538.95 32.38 260.34 8980.53 4641.71 1868.44 -4295.14 4683.94 293.51 0.41 I 10633.70 32.25 261.10 9060.61 4687.58 1860.27 -4345.13 4726.60 293.18 0.45 10729.47 31.51 260.89 9141.93 4733.49 1852.36 -4395.09 4769.49 292.85 0.78 10824.61 30.60 261.95 9223.43 4778.19 1845.03 -4443.61 4811.43 292.55 1.12 10845.01 30.26 261.95 9241 .02 4787.64 1843.58 -4453.84 4820.32 292.49 1.67 I :in~t good survey past shoe 11012.68 29.33 262.22 9386.53 4863.91 1832.11 -4536.36 4892.36 291.99 0.56 11108.71 28.19 262.27 9470.71 4906.26 1825.87 -4582.14 4932.53 291.73 1.19 11203.41 27.48 264.15 9554.45 4947.07 1820.64 -4626.04 4971.42 291.48 1.19 I 11298.00 26.59 264.88 9638.71 4987.13 1816.52 -4668.84 5009.77 291.26 1.00 11393.23 25.90 264.04 9724.12 5026.35 1812.46 -4710.75 5047.40 291.04 0.82 11486.62 26.40 263.40 9807.95 5064.49 1807.96 -4751.67 5084.00 290.83 0.61 I 11583.36 25.89 264.67 9894.79 5104.07 1803.52 -4794.06 5122.08 290.62 0.78 11678.49 24.91 267.07 9980.73 5142.41 1800.57 -4834.75 5159.15 290.43 1.49 11772.34 24.49 266.30 10065.99 5179.47 1798.30 -4873.90 5195.07 290.25 0.56 11868.30 23.77 266.65 10153.57 5216.48 1795.89 -4913.05 5231.00 290.08 0.76 I 11962.97 23.23 269.04 10240.39 5252.38 1794.46 -4950.77 5265.95 289.92 1.16 I 12055.68 21.72 268.54 10326.05 5286.27 1793.72 -4986.20 5299.02 289.79 1.64 12151.30 20.16 268.35 10415.35 5318.89 1792.79 -5020.36 5330.87 289.65 1.63 12243.56 18.13 268.84 10502.51 5347.79 1792.05 -5050.61 5359.11 289.54 2.21 I 12338.35 15.98 269.02 10593.12 5374.39 1791.52 -5078.40 5385.14 289.43 2.27 12396.93 14.72 269.46 10649.61 5389.25 1791.32 -5093.91 5399.69 289.37 2.16 I ~i~:t good suNey in 6 1/8 hole 12541.27 17.54 263.88 10788.26 5427.03 1788.82 -5133.88 5436.60 289.21 2.23 12635.16 18.37 261.89 10877.58 5453.68 1785.23 -5162.60 5462.55 289.08 1.10 12729.87 17.51 260.69 10967.69 5480.22 1780.82 -5191.43 5488.38 288.93 0.99 12825.53 18.63 258.09 11058.63 5506.78 1775.34 -5220.58 5514.19 288.78 1.44 I ~rojected survey to TO 12920.20 17.38 258.39 11148.66 5532.72 1769.37 -5249.23 5539.41 288.63 1.32 12936.84 17.19 258.81 11164.55 5537.11 1768.39 -5254.08 5543.69 288.60 1.37 13020.00 16.25 261.03 11244.19 5558.63 1764.19 -5277.63 5564.69 288.48 1.37 I I NS14_Final_surveys.xls Page 3 of 3 **Projections and Interpolations in Italics** 2/26/02-2:59 PM I I I I I I I ( I ( I I I ( I I I I I ~' { NS14 Formation Tops NS14 Pro1!nosed Toos Actual Deoths Delta Fonnation TVDss TVDrkb MDrkb TVDss TVDrkb MDrkb TVO Top Penna frost 1149 1204 1206 1148 1204 1206 0 Base Pennafrost 1499 1554 1556 1498 1554 1556 0 SV6 - Top Confminf! Zone 3010 3065 3118 3004 3060 3118 5 Surface Casine: Point 3170 3225 3306 3170 3226 3316 -1 SV5 - Base Confmint! Zone 3280 3335 3442 3274 3330 3570 5 SV4 3600 3655 3854 3574 3630 3875 25 SV2 - Top Upper Injection Zone 4000 4055 4368 3972 4028 4340 27 SVI - Top Major Shale Barrier 4400 4455 4882 4367 4423 4841 32 TMBK - ToD Lower Injection Zone - TOD Uf!DU 4745 4790 5358 4704 4760 5261 30 M87F - ToD Schrader Bluff - Base Uf!DU 6360 6385 7403 6294 6350 7305 35 M60T - Base Lower Injection Zone (Top Colville) 6995 7020 8216 6929 6985 8111 35 THRZ - Top HRZ 8740 8795 10338 8507 8563 10038 232 BHRZ - Base HRZ 8800 8855 10408 8589 8645 10137 210 TOD KuDaruk 8870 8925 10490 8674 8730 10243 195 KuDaruk C 9000 9055 10643 8868 8924 10472 131 Top Miluveach 9250 9305 10936 9164 9220 10845 85 Intennediate Casinf! Point 9350 9405 11054 9258 9314 10930 91 Intennediate Lof!l!Înf! Point 9350 9405 11054 9258 9314 10930 91 TOD Kin!!ak 9750 9805 11523 9700 9756 11429 49 Geol Tar!!et #1 9880 9935 11675 9819 9875 11561 60 Top Sat! River 10700 10755 12637 10654 10710 12459 45 Intermediate Casinf! Point 10740 10795 12684 10675 10731 12480 64 ANADRILL SCHLUMBERGER Survey report Client........... ... ... ..: BP Exploration (Alaska) Inc. Field............ ........: Northstar Well.....................: NS-14 API number........ .... ...: 50-029-23026-00 Engineer.................: Leafstedt RIG:.....................: Nabors 33E STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference........ ..: Driller's Pipe Tally GL above permanent.......: 15.57 ft KB above permanent.......: N/A-Top Drive DF above permanent.......: 55.51 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 285.81 degrees [(c)2002 Anadrill IDEAL ID6_1C_l0] ... 5-Feb-200202:14:25 1 of 6 Page Spud date. . . . . . . . . . . . . . . . : Last survey date.. .......: Total accepted surveys...: MD of first survey. ......: MD of last survey.... ....: 09-Jan-02 05-Feb-02 143 0.00 ft 13020.00 ft ~~~ ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2000 Magnetic date..... .......: 31-Dec-2001 Magnetic field strength..: 1149.90 HCNT Magnetic dec (+E/W-).....: 26.57 degrees Magnetic dip...... .......: 80.92 degrees ----- MWD survey Reference Criteria --------- Reference G....... .......: 1002.69 mGal Reference H....... .......: 1150.23 HCNT Reference Dip..... .......: 80.93 degrees Tolerance of G. ..........: (+/-) 2.50 mGal Tolerance of H.... .......: (+/-) 6.00 HCNT Tolerance of Dip. .... ....: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.57 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.57 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 -". ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) -------- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 ------ ------ Incl angle (deg) ------ ------ 0.00 0.30 0.39 0.65 1.18 1.65 1.75 2.20 2.06 1.99 1.36 1.78 2.24 2.47 2.19 2.05 2.01 1.60 1.53 0.63 1.28 1.33 2.32 3.20 3.43 4.49 6.62 9.47 12.58 16.01 ------- ------- Azimuth angle (deg) ------- ------- 0.00 24.52 13.11 12.61 3.63 78.78 76.40 74.43 75.02 74.55 79.39 74.79 70.11 71.40 71.14 73.17 74.20 74.96 79.22 35.96 303.69 305.36 299.62 294.09 294.90 300.59 302.08 303.45 302.42 302.18 ------ ------ Course length (ft) ------ ------ 0.00 50.00 50.00 50.00 50.00 95.00 80.00 78.00 92.00 90.00 90.00 95.00 90.00 95.00 93.00 97.00 95.00 95.00 95.00 95.00 92.00 98.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 [(c)2002 Anadrill IDEAL ID6_1C_10) 6 7 8 9 10 295.00 375.00 453.00 545.00 635.00 11 12 13 14 15 725.00 820.00 910.00 1005.00 1098.00 16 17 18 19 20 1195.00 1290.00 1385.00 1480.00 1575.00 21 22 23 24 25 1667.00 1765.00 1860.00 1955.00 2050.00 26 27 28 29 30 2145.00 2240.00 2335.00 2430.00 2525.00 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 100.00 150.00 199.99 294.97 374.93 452.89 544.82 634.77 724.73 819.69 909.64 1004.56 1097.48 1194.41 1289.35 1384.31 1479.27 1574.25 1666.24 1764.22 1859.17 1954.06 2048.90 2143.67 2238.22 2332.28 2425.51 2517.56 5-Feb-200202:14:25 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.02 -0.03 -0.01 0.12 -0.90 -2.99 -5.30 -8.23 -10.95 -13.25 -15.52 -18.15 -21.34 -24.46 -27.44 -30.29 -32.85 -35.12 -36.44 -35.63 -33.52 -30.61 -26.12 -20.69 -14.29 -5.44 7.27 24.64 47.13 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 0.12 0.40 0.85 1.64 2.88 3.39 4.07 4.97 5.81 6.42 7.02 7.98 9.27 10.48 11.58 12.53 13.32 13.91 14.57 15.54 16.81 18.40 20.43 22.71 25.80 30.60 37.82 47.67 60.20 0.00 0.05 0.15 0.25 0.34 1.75 4.06 6.66 9.96 13.03 15.59 18.12 21.12 24.81 28.39 31.80 35.03 37.92 40.44 41.99 41.44 39.60 37.03 32.94 27.94 22.16 14.32 3.15 -12.10 -31.93 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 0.13 0.43 0.88 1.67 3.37 5.29 7.81 11.13 14.27 16.86 19.43 22.58 26.48 30.26 33.84 37.20 40.19 42.77 44.45 44.26 43.02 41.35 38.76 36.00 34.01 33.78 37.95 49.19 68.15 0.00 24.52 20.03 16.32 11.81 31.23 50.15 58.56 63.46 65.97 67.61 68.83 69.30 69.52 69.74 69.99 70.32 70.64 71.02 70.87 69.44 67.00 63.58 58.19 50.89 40.66 25.07 4.77 345.75 332.06 2 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 0.00 0.60 0.23 0.52 1.09 1.86 0.15 0.58 0.15 0.08 0.72 0.46 0.54 0.25 0.30 0.16 0.06 0.43 0.14 1.22 1.57 0.06 1.06 0.97 0.25 1.19 2.25 3.01 3.28 3.61 ----- ----- Srvy tool type ----- ----- TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR ------ ------ Tool qual type ------ ------ -~ -~~ . .. ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) --- -------- -------- 31 32 33 34 35 2549.00 2620.00 2646.76 2740.95 2836.10 ------ ------ Incl angle (deg) ------ ------ 16.42 18.28 19.52 21.84 23.56 26.17 28.94 31.52 33.92 34.63 34.81 35.87 37.20 39.11 39.30 38.76 38.20 37.49 38.88 39.16 38.90 38.96 39.15 39.54 39.38 38.95 39.14 38.66 38.46 38.23 ------- ------- Azimuth angle (deg) ------- ------- 302.65 301.66 301.01 297.51 296.52 297.80 297.79 299.35 299.01 298.45 297.54 296.26 294.81 293.81 294.22 294.72 293.50 294.05 294.27 294.59 294.22 294.00 293.78 295.58 295.79 295.00 295.50 297.78 297.37 298.87 ------ ------ Course length (ft) ------ ------ 24.00 71.00 26.76 94.19 95.15 93.32 95.53 91.50 94.33 32.36 166.05 96.50 93.97 92.66 96.46 95.17 94.63 95.49 93.99 95.16 97.45 96.37 96.63 93.69 94.54 95.95 93.87 96.14 94.25 96.00 [(c)2002 Anadrill IDEAL ID6_1C_10] 36 37 38 39 40 2929.42 3024.95 3116.45 3210.78 3243.14 41 42 43 44 45 3409.19 3505.69 3599.66 3692.32 3788.78 46 47 48 49 50 3883.95 3978.58 4074.07 4168.06 4263.22 51 52 53 54 55 4360.67 4457.04 4553.67 4647.36 4741.90 56 57 58 59 60 4837.85 4931.72 5027.86 5122.11 5218.11 -------- -------- TVD depth (ft) -------- -------- 2540.60 2608.37 2633.68 2721.80 2809.58 2894.24 2978.93 3057.98 3137.33 3164.08 3300.56 3379.28 3454.78 3527.64 3602.39 3676.32 3750.40 3825.80 3899.68 3973.61 4049.31 4124.28 4199.32 4271.77 4344.76 4419.16 4492.06 4566.89 4640.58 4715.88 5-Feb-200202:14:25 -------- -------- Vertical section (ft) -------- -------- 53.55 73.87 82.22 114.57 150.58 189.05 232.27 277.19 326.79 344.55 437.00 491.77 546.91 603.52 663.87 723.12 781.38 839.40 896.89 956.12 1016.80 1076.72 1137.00 1195.68 1254.87 1314.62 1372.95 1432.24 1489.76 1547.94 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 63.79 75.05 79.56 95.76 112.43 130.36 150.96 173.01 197.87 206.63 251.02 276.26 300.36 323.92 348.73 373.56 397.61 421.23 445.01 469.79 495.15 519.88 544.54 569.34 595.38 621.37 646.60 673.66 700.85 728.92 -37.59 -55.52 -62.92 -91.95 -124.67 -159.57 -198.66 -239.10 -283.61 -299.59 -383.10 -432.88 -483.36 -535.53 -591.22 -645.77 -699.51 -753.13 -806.14 -860.69 -916.57 -971.84 -1027.51 -1081.48 -1135.62 -1190.36 -1243.85 -1297.80 -1349.88 -1402.40 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 74.05 93.36 101.44 132.76 167.88 206.05 249.51 295.13 345.81 363.94 458.01 513.52 569.08 625.87 686.41 746.03 804.62 862.92 920.81 980.55 1041.76 1102.16 1162.88 1222.19 1282.23 1342.78 1401.87 1462.23 1520.97 1580.52 329.49 323.51 321.66 316.16 312.05 309.25 307.23 305.89 304.90 304.59 303.23 302.55 301.86 301.17 300.53 300.05 299.61 299.22 298.90 298.63 298.38 298.14 297.92 297.76 297.67 297.56 297.47 297.43 297.44 297.46 3 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 1.79 2.65 4.70 2.79 1.85 2.86 2.90 2.95 2.55 2.40 0.33 1.34 1.69 2.17 0.33 0.66 1.00 0.82 1.49 0.36 0.36 0.16 0.24 1.29 0.22 0.69 0.39 1.57 0.34 1.00 ----- ----- Srvy tool type ----- ----- GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ --~- -,-- ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 61 62 63 64 65 5310.92 5408.65 5503.46 5597.85 5693.08 ------ ------ Incl angle (deg) ------ ------ 38.02 38.05 38.23 38.42 38.63 38.48 38.63 38.50 38.58 37.94 38.09 38.01 37.89 38.78 39.07 38.91 39.23 38.95 38.83 38.45 38.32 38.36 38.55 38.77 38.49 38.17 37.93 37.56 37.41 37.12 ------- ------- Azimuth angle (deg) ------- ------- 297.94 297.86 298.32 298.62 297.81 298.94 299.40 299.97 301.40 301.36 301.81 301.43 301.54 300.05 299.80 299.81 300.21 299.35 299.32 299.22 299.06 299.16 299.27 299.37 299.35 299.10 299.10 298.92 297.64 296.96 ------ ------ Course length (ft) ------ ------ 92.81 97.73 94.81 94.39 95.23 95.16 95.04 94.12 97.87 96.35 94.63 96.15 91.26 94.45 95.85 92.63 95.24 94.38 94.87 94.47 95.60 95.36 95.48 94.26 95.02 96.99 95.05 94.48 94.74 91.54 [(c)2002 Anadrill IDEAL ID6_1C_10J 66 67 68 69 70 5788.24 5883.28 5977.40 6075.27 6171.62 71 72 73 74 75 6266.25 6362.40 6453.66 6548.11 6643.96 76 77 78 79 80 6736.59 6831.83 6926.21 7021.08 7115.55 81 82 83 84 85 7211.15 7306.51 7401.99 7496.25 7591.27 86 87 88 89 90 7688.26 7783.31 7877.79 7972.53 8064.07 -------- -------- TVD . depth (ft) -------- -------- 4788.89 4865.87 4940.43 5014.48 5088.99 5163.40 5237.73 5311.32 5387.87 5463.53 5538.08 5613.80 5685.76 5759.85 5834.41 5906.41 5980.35 6053.61 6127.45 6201.24 6276.17 6350.97 6425.74 6499.34 6573.57 6649.66 6724.51 6799.22 6874.39 6947.25 5-Feb-200202:14:25 -------- -------- Vertical section (ft) -------- -------- 1603.86 1662.74 1719.96 1777.07 1834.99 1892.88 1950.51 2007.48 2066.41 2123.88 2179.96 2236.98 2291.02 2347.61 2406.01 2462.56 2520.76 2578.51 2636.42 2693.78 2751.55 2809.11 2866.88 2924.13 2981.80 3040.31 3097.32 3153.63 3209.92 3264.24 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 756.18 784.35 811.92 839.83 867.87 896.05 924.92 953.98 985.10 1016.17 1046.69 1077.76 1107.07 1137.06 1167.10 1196.07 1226.09 1255.65 1284.83 1313.67 1342.58 1371.35 1400.34 1429.17 1458.25 1487.62 1516.12 1544.16 1571.48 1596.90 -1452.80 -1506.02 -1557.67 -1609.13 -1661.40 -1713.58 -1765.30 -1816.27 -1868.71 -1919.65 -1969.29 -2019.76 -2067.62 -2117.94 -2170.13 -2220.71 -2272.69 -2324.34 -2376.26 -2427.72 -2479.57 -2531.25 -2583.07 -2634.41 -2686.12 -2738.61 -2789.80 -2840.38 -2891.15 -2940.40 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 1637.81 1698.03 1756.58 1815.10 1874.41 1933.72 1992.93 2051.57 2112.46 2172.01 2230.17 2289.32 2345.35 2403.87 2464.06 2522.32 2582.32 2641.81 2701.37 2760.35 2819.71 2878.86 2938.23 2997.11 3056.42 3116.57 3175.15 3232.98 3290.64 3346.05 297.50 297.51 297.53 297.56 297.58 297.61 297.65 297.71 297.80 297.89 297.99 298.08 298.17 298.23 298.27 298.31 298.35 298.38 298.40 298.42 298.43 298.45 298.46 298.48 298.50 298.51 298.52 298.53 298.53 298.51 4 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 0.66 0.06 0.35 0.28 0.57 0.76 0.34 0.40 0.91 0.66 0.33 0.26 0.15 1.36 0.34 0.17 0.43 0.65 0.13 0.41 0.17 0.08 0.21 0.24 0.29 0.37 0.25 0.41 0.84 0.55 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ T -c.. --c~. ~ .""" ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) --- 96 97 98 99 100 -------- -------- 91 92 93 94 95 8161.93 8256.66 8351.69 8445.77 8539.20 ------ ------ Incl angle (deg) ------ ------ 37.06 36.87 36.57 36.14 35.68 35.10 34.79 34.25 34.05 34.02 34.18 34.21 34.63 34.58 34.53 34.83 34.72 34.59 34.43 34.90 34.84 34.38 33.48 33.21 32.55 32.38 32.25 31.51 30.60 30.26 ------- ------- Azimuth angle (deg) ------- ------- 295.61 293.95 293.69 291.96 291.61 292.19 290.19 289.32 288.55 287.07 286.59 285.17 285.26 283.91 282.06 280.33 277.37 275.70 273.42 271.69 268.54 264.29 260.70 259.68 259.69 260.34 261.10 260.89 261.95 261.95 ------ ------ Course length (ft) ------ ------ 97.86 94.73 95.03 94.08 93.43 96.69 95.43 94.72 95.91 93.79 94.62 95.46 96.94 95.73 93.50 95.01 96.87 92.18 96.32 88.97 99.57 97.46 95.12 91.25 99.22 94.99 94.75 95.77 95.14 20.40 ((c)2002 Anadrill IDEAL ID6_1C_10J 8635.89 8731.32 8826.04 8921.95 9015.74 101 102 103 104 105 9110.36 9205.82 9302.76 9398.49 9491.99 106 107 108 109 110 9587.00 9683.87 9776.05 9872.37 9961.34 111 112 113 114 115 10060.91 10158.37 10253.49 10344.74 10443.96 116 117 118 119 120 10538.95 10633.70 10729.47 10824.61 10845.01 -------- -------- TVD depth (ft) -------- -------- 7025.31 7101.00 7177.17 7252.94 7328.62 7407.44 7485.67 7563.71 7643.08 7720.81 7799.16 7878.12 7958.08 8036.88 8113.89 8192.02 8271.59 8347.42 8426.79 8499.97 8581.67 8661.90 8740.83 8817.06 8900.38 8980.53 9060.60 9141.92 9223.43 9241.02 5-Feb-200202:14:25 -------- -------- Vertical section (ft) -------- -------- 3322.27 3378.53 3434.80 3490.14 3544.64 3600.32 3654.74 3708.28 3762.04 3814.50 3867.54 3921.19 3975.98 4030.33 4083.29 4137.17 4192.00 4243.73 4297.24 4346.49 4401.28 4453.47 4502.22 4547.44 4595.81 4641.71 4687.58 4733.49 4 7 7 8 ..19 4787.64 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 1623.04 1646.91 1669.86 1691.49 1711.83 1732.72 1752.47 1770.62 1788.09 1804.15 1819.50 1834.18 1848.56 1862.25 1874.17 1884.66 1893.16 1899.13 1903.47 1905.72 1905.83 1902.39 1895.47 1886.93 1877.28 1868.44 -1860.27 1852.36 1845.03 1843.58 -2993.31 -3045.03 -3097.00 -3148.40 -3199.28 -3251.24 -3302.20 -3352.71 -3403.64 -3453.62 -3504.39 -3555.99 -3608.86 -3661.48 -3713.15 -3766.17 -3820.75 -3872.82 -3927.21 -3977.76 -4034.67 -4089.89 -4142.51 -4191.93 -4244.93 -4295.14 -4345.13 -4395.09 -4443.61 -4453.84 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 3405.02 3461.86 3518.50 3574.01 3628.47 3684.14 3738.41 3791.54 3844.74 3896.46 3948.59 4001.16 4054.76 4107.85 4159.32 4211.42 4264.06 4313.40 4364.19 4410.71 4462.15 4510.68 4555.57 4597.04 4641.51 4683.94 4726.60 4769.49 4811.43 4820.32 298.47 298.41 298.33 298.25 298.15 298.05 297.95 297.84 297.72 297.58 297.44 297.28 297.12 296.96 296.78 296.58 296.36 296.12 295.86 295.60 295.28 294.95 294.59 294.23 293.86 293.51 293.18 292.85 292.55 292.49 5 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 0.83 1.07 0.36 1.18 0.54 0.69 1.24 0.77 0.50 0.88 0.33 0.84 0.44 0.80 1.12 1.08 1.75 1.04 1.35 1.23 1.81 2.52 2.31 0.68 0.67 0.41 0.45 0.78 1.12 1.67 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ .-, -~~" r ANADRILL SCHLUMBERGER Survey Report 5-Feb-200202:14:25 Page 6 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 121 11012.68 29.33 262.22 167.67 9386.52 4863.91 1832.11 -4536.36 4892.36 291.99 0.56 MWD 122 11108.11 28.19 262.50 95.43 9470.18 4906.03 1826.00 -4581.87 4932.32 291.73 1.20 MWD 123 11203.41 27.48 262.43 95.30 9554.45 4946.89 1820.17 -4625.98 4971.19 291.48 0.75 MWD 124 11298.00 26.59 263.41 94.59 9638.70 4986.49 1814.86 -4668.65 5008.99 291.24 1.05 MWD 125 11393.22 25.90 262.67 95.22 9724.11 5025.32 1809.76 -4710.44 5046.14 291.02 0.80 MWD 126 11486.63 26.40 263.62 93.41 9807.96 5063.31 1804.85 -4751.32 5082.57 290.80 0.70 MWD .--" 127 11583.36 25.89 265.01 96.73 9894.79 5102.96 1800.63 -4793.73 5120.75 290.59 0.82 MWD 128 11678.49 24.91 265.48 95.13 9980.72 5141.16 1797.24 -4834.39 5157.65 290.39 1.05 MWD 129 11772.34 24.49 265.76 93.85 10065.99 5177.97 1794.25 -4873.49 5193.29 290.21 0.46 MWD 130 11868.30 23.77 266.17 95.96 10153.56 5214.87 1791.48 -4912.62 5229.08 290.04 0.77 MWD 131 11962.97 23.23 267.41 94.67 10240.38 5250.55 1789.37 -4950.31 5263.78 289.87 0.77 MWD 132 12055.68 21.72 267.20 92.71 10326.04 5284.16 1787.70 -4985.71 5296.53 289.73 1.63 MWD 133 12151.30 20.16 268.35 95.62 10415.35 5316.65 1786.36 -5019.86 5328.23 289.~59 1.69 MWD 134 12243.56 18.13 268.84 92.26 10502.50 5345.55 1785.61 -5050.10 5356.49 289.47 2.21 MWD 135 12338.35 15.98 269.02 94.79 10593.12 5372.15 1785.09 -5077.90 5382.53 289.37 2.27 MWD 136 12396.93 14.72 269.46 58.58 10649.61 5387.01 1784.88 -5093.40 5397.09 289.31 2.16 MWD 137 12541.21 17.54 263.88 144.28 10788.20 5424.78 1782.39 -5133.36 5434.00 289.15 2.23 MWD 138 12635.16 18.37 261.89 93.95 10877.58 5451.44 1778.79 -5162.09 5459.98 289.0I 1.10 MWD 139 12729.87 17.51 260.69 94.71 10967.68 5477.99 1774.38 -5190.93 5485.82 288.87 0.99 MWD 140 12825.53 18.63 258.09 95.66 11058.62 5504.54 1768.90 -5220.08 5511.65 288.72 1.44 MWD ~~_. 141 12920.20 17.38 258.39 94.67 11148.65 5530.48 1762.94 -5248.73 5536.89 288.57 1.32 MWD 142 12936.84 17.19 258.81 16.64 11164.54 5534.88 1761.96 -5253.58 5541.17 288.54 1.37 MWD Survey Projected to Total Depth: 143 13020.00 16.25 261.03 83.16 11244.19 5556.39 1757.76 -5277.13 5562.17 288.42 1.37 MWD [(c)2002 Anadrill IDEAL ID6_1C_10J . ..- bp ~I~" '~':"".""'>"""',",,,',:,',,',",',",',",',',','.".'"',;,'"".,,.',,,',," ~ \, ( Date: 03-07-2002 Transmittal Number:92415 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor NS14 01-23-2002 SCH 1 3200 6150 DIPOLE SONIC; al)}~tl<D c~ ~~~J Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Tim Putnam MB3-6 Attn: Buford Bates (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) RECEIVED f;1,\R 0 7 2002 Alaska Oil & Gas Cons. Conunision Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~ t \ , Date: 02-14-2002 Transmittal Number:9240 1 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. <j-- Top SW Name Date Contractor Loa Run Depth Bottom Depth Log Type NS09 12-05-2001 SCH 1-6 200 13433.50 VISION RESISTIVITY; (TVD) - ~ NS09 12-05-2001 SCH 1-6 200 13433.50 VISION DENSITY; (TVD) ~ r NS09 12-05-2001 SCH 1-6 200 13433.50 VISION RESISTIVITY; NS09 12-05-2001 SCH 1-6 200 13433.50 VISION DENSITY; (MD) ...NS14 02-05-2002 ANA - 0 13020 MWD SURVEY REPORT; (HARDCOPY) "" MWD SURVEY REPORT; (DISKETTE) .-' \ â 1J57ët J J. - 3/- 2ðO( ~ C H <lS NSOC} 1- G:., 2kJt~- 1'3~33.~-o LDwa FClt?"^'ÆT (co) ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 ð;ttñ:'Höwi:tidOl<laQ d'(.AOGC e )f' Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED FEB 1.'3 2002 Alaska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 '" I~ ~1f!A\1fŒ (ill~ !A\~!A\~~!A\ ,I' .~ ALAS KA 0 IL AND GAS CONSERVATION COMMISSION / / / TONY KNOWLES, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage Alaska 99519 Re: Northstar Unit NS 14 BP Exploration (Alaska) Inc. Pennit No: 201-118 Sur Loc: 1179' NSL, 644' WEL, Sec. 11, T13N, R13E, UM Btmhole Loc. 2847' NSL, 765' WEL, Sec. 10, T13N, R13E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting detenninations are made. Annular disposal has not been requested as part of the Permit to Drill application for Northstar Unit NS 14. 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 ofBOPE 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. Sincerely, (¡'MA^,'~ /~. ~/ C~; Ôechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 21th day of December, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASKA t STATE OF ALASKA - AND GAS CONSERVATION COMwl PERMIT TO DRILL 20 MC 25.005 jlON dfvl H 1'7,\Z,\Jò ì ~>l()-\ Revised: 12/13/01 1 a. Type of work 181 Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1179' NSL, 644' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 2936' NSL, 245' WEL, SEC. 10, T13N, R13E, UM At total depth 2847' NSL, 765' WEL, SEC. 10, T13N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 312808, 4167' MD (Approx.) NS13 is 13.77'awayat 600' MD 16. To be completed for deviated wells Kick Off Depth 1900' MD Maximum Hole Angle 18. Casin~ Program I Specifications 1"70. 1 b. Type of well 0 Exploratory [J¡Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas m Single Zone Þ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 55.8' Northstar Unit 6. Property Designation ADL 312799 7. Unit or Property Name Northstar Unit 8. Well Number NS14 9. Approximate spud date 01/08/02 I Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 4472 13283' MD /11305' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 39 0 I Maximum surface 4116 psig, At total depth (TVD) 11210' / 5243 psig Setting Depth 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 in r lin th M TV M T 2011 X-56 WELD 201' Surface Surface 201' 201' Driven 13-3/811 L-80 BTC 3306' Surface Surface 33061 3226' 13 sx PF 'L', 466 sx Class 'G' 9-5/811 L-80 BTC-Mod 11054' Surface Surface 11054' 9405' 76 sx Econolite 437 Class 'G' 711 L-80 BTC-Mod 1781' 109031 9277' 12684' 10795' 82 sx Class 'G' 4-1/211 13Cr Vam Ace 749' 125341 1 0667' 13283' 11305' 98 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD true vertical RECEIVED DEe 1 9 2001 Alaska Oil & Gas Cons. ~ Anchorage Perforation depth: measured 0 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherriff, 564-5204 Barbara Holt, 564-5791 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that tI:~~:::t true a~ correct to the best of my knowledge I Signed Floyd Hernand .~ Title Senior Drilling Engineer Date \ 1../1 ~ -0 ( 20. Attachments API Number 50- 029-23026-00 Samples Required 0 Yes m No Hydrogen Sulfide MeasuresjSfVes 0 No Required Working Pressure tor BOPE 0 2K 0 3K Other: Permit Number 201-118 Conditions of Approval: Rev. 12-01-85 Commissioner by order of the commission Date Original Signed By RIGINAL bp ( II'." '\ .,. ,\If."'. .......~ ~.~ ~..- ~...'" ...~ -F~'" .'1"'1\. ". BP Exploratioll- Alaska Inc. To: Tom Maunder - AOGCC Date: December 19, 2001 From: Allen Sherritt Northstar Operations Drilling Engineer Subject: Reference: NS14 Application for Drilling Permit - Revision of permit application for change in bottom hole location greater than 500 feet. Permit #201-118; API #50-029-23026-00 Mr. Maunder, A revision to the Drilling Permit (#201-118) is requested for well NS-14. The current permitted BHL is being changed, greater than 500 feet, to optimize well bore placement and maximize reserves. NS-14 is currently scheduled for Nabors 33E on January 1, 2002. Spud dater was initially estimated to be Jan 8th, but excellent drilling performance to date has moved the projected spud to Jan 1st. A Diverter waiver is also requested on NS14. To date, BP has drilled seven development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. All seven surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. Please find attached the revised NS-14 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact Barb Holt @ 564-5791 or Floyd Hernandez @ 564-5960. I will be return to the office January 2nd, 2002. Sincerely, Allen Sherritt BP Northstar Operations Drilling Engineer 564-5204 { { NS14 Well Plan Summary l!ïPe of Well (producer or injector): I Producer I Northstar Slot: NS14 Surface Location: 1179' FSL, 644' FEL, Sec. 11, T13N, R13E, UM X = 659831 Y = 6030952 Target (top of SAG): 29361 FSL (23431 FNL), 2451 FEL (50341 FWL), Sec. 10, T13N, A13E 300' Radius X = 654912 Y = 6032605 9935' TVDrkb Bottom Hole Location: 28471 FSL (24321 FNL), 7651 FEL (45141 FWL), Sec. 10, T13N, A13E 400' Radius X = 654394 Y = 6032505 10795' TVDrkb I AFE Number: 1831310 I I Estimated Start Date: 11/01/02 I ~ Nabors 33E I l.Qperating days to complete: 141.4 I 1 MD: 113283 I I TVDrkb: 1113051 I RKB/Surface Elevation: (a.m.s.l.)-.J 55.8' / 16.0' I I Well Desi9.!l..{conventional, slim hole, etc.)~ Modified BiQ Bore I ~ective: ¡Ivishak Producer with fiber optic surveillance control line I Mud Program: S S d Mud 16" Hole S From Surface to -3306' MD / 3226' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel API FL pH (ppg) (seconds) 10 sec Initial 8.8- 9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 >6 15 - 25 4-10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 -100 20 - 35 >6 1 0 - 25 4-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. d. Hole Mud P Inhibited KCI 12-1/4" Hole Sect" From Surface Casing Shoe to 11054' MD / 9406' TVD (-top Miluveach). Interval Density I PV YP Tauo API/ HTTP FL pH Initial 8.7-9.3 10 -16 20 - 30 4-7 6 -10 8.5 - 9.5 Top HAl 9.6 10-16 20 - 25 4-7 4-6/<12 8.5-9.5 Top Kuparuk to Miluveach 9.8 10-18 20 - 28 4-7 4-6/<12 8.5-9.5 Drillin9 Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 12684' MD / 10795' TVD (top of Sag) Interval Densit PV YP Tauo API FL Miluveach & Kinaak to top of Saa 11.3 10 - 25 20 - 25 4 - 7 4-6/<10 H - 8.5 - 9.5 Prod Hole Mud P s '/CaCO3 Drill-In Fluid 6-1/8" Hole Sect" From Intermediate Casing Shoe to 13283' MD / 11305' TVD Interval Density (ppg) PV YP Tauo APIFL pH Initial/Final 9.3 8 - 12 20 - 25 4-7 3-5 8.5 - 9.5 NS14 Permit to Drill RevisiJ #201-118 ~, Di rectional: (P9) KOP: :t1900. MD Cantenarv curve 3°/100' build Maximum Hole Angle: :t38.9° Close Approach Well: Surface- 10' well spacing with NS13- 13.77' displacement at 600' MD. NS-10, 29.04' at 700' MD. Gyro will be used for initial surveys and kickoff Survey Program: Gyros as required from surface to +/-1300'. Standard MWD surveys from +/-1300' to TD. DRilliNG CLOSE APPROACH: No close approach issues exist while drilling NS14 except for surface proximity to NS13 and NS10. NS14 passes anti-collision criteria with all wells identified as a "major risk." Gyros will be run from surface to -1300' MD or until reliable MWD surveys can be taken. L . p 16" Section: Drilling: GR/Directional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples(100'intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Res, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples from 10544' MDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitorinç)) Open Hole: Quad Combo (GR/Res/Den/Neu/Sonic), RFT pressures only Cased Hole: None 8-112" Section: Drilling: GR/Directional, Res, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitorinq) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GR/Directional, Res, Den, Neu, (LWD recorded.) Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitorina) Open Hole: RFT pressures only Cased Hole: USIT (after rig release) 2 NS14 Permit to Drill Revisil . #201-118 i InteQ!:!!y Testina: Test Point 12 ~" Surface Shoe 9 518" Intermediate Shoe Depth 20' min from 12 1/4" shoe 20' min from 9 518" shoe 20' min from 7" shoe Test Type FIT FIT EMW 12.5 ppg EMW Target 13.5 ppg EMW Target 7" Drillino Liner Shoe FIT 11.3 EMW Taraet Formation Markers: Formation Tops MD TVDss Pore EMW Comments Press. (ppg) (psi) Top Permafrost 1206 1149 542 8.65 Base Permafrost 1556 1499 699 8.65 SV6 3118 3010 1379 8.65 Set surface casino 150' tvd below top of SV6 SV5 3442 3280 1500 8.65 SV4 3854 3600 1644 8.65 SV2 4368 4000 1824 8.65 SV1 4882 4400 2004 8.65 Top Ugnu (UG4A) 5358 4770 2170 8.65 TMBK Top Schrader 7403 6360 2886 8.65 Top Seabee (CM3) 8220 6995 3171 8.65 Colville Shales Top HRl 10338 8740 3956 8.65 Base H RZ 10408 8800 3982 8.65 Top Kuparuk 10490 8870 4235 9.13 HYdrocarbon bearinq mainly qas . Top Kuparuk C 10643 9000 4333 9.20 Hydrocarbon bearinq mainly Qas . Top Miluveach 10936 9250 4395 8.99 Set intermediate casing 100' TVD into the top of the Miluveach Top Kinaak 11523 9750 4690 9.20 Top Sag River 12637 10700 5005 8.95 Set drilling liner into the top of the Sag River to cover up the KinQak. Hydrocarbon bearina. Top Shublik 12755 10800 5052 8.95 Hydrocarbon bearing. Possible loss circulation zone. Top Ivishak 12854 10885 5091 8.95 Hydrocarbon bearing. Possible loss circulation zone. Anticipated OWC 13107 11100 5166 8.95 Top Kavik 13236 11210 5243 8.95 Proposed TO 13283 11224 5388 8.95 Top Lisbu me 13322 11264 5407 9.19 Possible loss circulation zone c - /Tub- p asln~ n g - Hole Size Casing! WtlFt Grade Conn Casing Casing Top Hole 8tm Tba 0.0. Lenath M DITVDrkb M DITVDrkb 20" 20" 169# X-56 WELD 201' Surface 201 '/201 ' 16" 13 318" 68# L-80 BTC 3306' Surface 3306'/3226' 12~" 9 5/8" 47# L-80 BTC-Mod 11 054' Surface 11054'/9405' 8 Y2" 7" 26# L-80 BTC-Mod 1781' 10903'/9277' 12684'/10795' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 749' 12534'/10667' 13283'/11305' TubinQ 4-1/2" 12.6# 13Cr Vam Ace 12534' Surface 12534'/10667' 3 NS14 Permit to Drill RevisiJ. #201-118 ~, Permafrost: The 13-3/8" surface casing will be run approximately 1600' TVD below the permafrost to -3306' MD I 3226' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a Permafrost 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. Cement Calculations: The following cement calculations are based upon a single stage job, with TAM port collar as 2nd Casin 13-3/8" Surface Basis: Stage 1 : Lead: Based on 2355' of Open Hole + 200% excess from the permafrost to surface + 500/0 excess for the remainder of the hole volume down to 750' above the shoe. Lead TOC: Surface Tail: Based on 750' of 16" open hole x 13 3/8" casing with 50% excess + 80' shoe joint. Tail TOG: -2556' MD Total Cement / S acer Preflush 20 bbl sea water S acer 50 bbl AI ha S acer wei hted to 1.0 over mud wei ht Lead 453 bbl I 613 sk I 2544 ft of 10.7 ppg Permafrost 'L' Cement. 4.15 dIsk, BHST 50° I BHGT 50°, TT = 6.0 hrs Tail 96 bbl I 466 sk I 541 ft of 15.8 ppg Premium 'G' wI 2% CaGI2. 1.16 dIsk, BHST 50° I BHCT 50°, TT = 4.0 hrs The followin cement calculations are based upon a single stage cement job. Casin -5/8" Intermediate Basis: Stage 1: Lead: Based on 617' of 12 1/4" open hole x 9 5/8" csg with 30% excess Lead TOG: At -3725' MD (3556' TVD ail: Based on 1152' of 12 ~" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. ail TOC: At -9902' MD 8424' TVD IStage 1: Total Cement / Spacer Preflush Spacer Lead Tail cement calculations are based upon a single stage cement job. I " Drilling Liner IStage 1 : Slurry: Based on 1630' of 8 1/2" open hole x 7" csg with 50% excess + 150' 95/8" csg x 7" csg liner lap + 00' 9-5/8" csg x 5" drillpipe above TaL + 80' shoe joint. Slur TOG: At -10904' MD 9323' TVD IStaae 1: Total Cement / Spacer Spacer 75 bbl Alpha Spacer wei hted to 1.0 pp over mud MW Slurry 77 bbl I 282 sk I 432 ft of 15.8 ppg Premium 'G'. 1.53 dIsk, BHST 250° I BHGT 150°, TT = 4.0 hrs 4 NS14 Permit to Drill Revisit. #201-118 ( Cement Calculations: Cont'd The followin cement calculations are based upon a single stage cement job. 'Casin -1/2" Prod Liner Basis: tage 1: lurry: Based on 599' of 6 1/8" open hole x 4 1/2" csg with 50% excess + 150' 7" csg x 4 1/2" csg liner la 200' 7" csg x 4" drillpipe above TaL + 80' shoe joint. lur TOC: At -12534' MD 10668' TVD ,taae 1: Total Cement / SDacer Spacer 5 bbl Alpha Spacer wei hted to 1.0 pp over mud MW Slurry 7 bbl / 98 sk /150 ft of 15.8 ppg Premium 'G'. 1.53 d/sk, BHST 2500 / BHCT 1500, TT = 4.0 hrs Well Control: ~ A Diverter waiver has been requested on NS14. To date, BP has drilled seven development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. All seven surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and capable of handling maximum potential surface pressures ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams ~ Annular preventer ~ Based upon the calculations below, BOP equipment will be tested to 4500 psi. Surface Section: . Maximum anticipated BHP: 1379 psi @ 3010' TVDss - SV6 . Maximum surface pressure: 1078 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Intermediate Section: . Maximum anticipated BHP: 4332 psi @ 9000' TVDss - Kuparuk 'c' . Maximum surface pressure: 3432 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Drilling Liner Section: . . Maximum anticipated BHP: 5005 psi @ 10700' TVDss - Sag River . Maximum surface pressure: 3935 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production Section: . Maximum anticipated BHP: 5243 psi @ 11210' TVDss - Total Depth . Maximum surface pressure: 4116 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: 4500 psi (annular to 3500 psi) . Planned completion fluid: 8.5 ppg Seawater /6.8 ppg Diesel 5 NS14 Permit to Drill RevisiJ. #201-118 { Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S: ./' Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ./' No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A-03 exploration/appraisal wells. ./' No H2S was detected while drilling the NS10 waste disposal well, NS27, NS29, NS31 or NS13. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-O1, A-O2, and A-O3. DISPOSAL: Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS1 0 Class I Waste Disposal Well. SURFACE HOLE SECTION: . Mudloggers will be rigged up throughout the entire section. No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. No faults are anticipated in the surface interval. Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre as required prior to penetrating sand intervals. Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. Hole stabilization in the shallow unconsolidated intervals can be problematic if mud properties are relaxed. Hi viscosities as used elsewhere on the North Slope should be sufficient to control any potential running gravels. Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2001 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. . . . . . . . 6 NS14 Permit to Drill RevisicÍ #201-118 { INTERMEDIATE SECTION: . Mudloggers will be rigged up throughout the entire section. Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2001 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. No faults are anticipated in the surface interval. The shallow intervals beneath Northstar are, by interpretation, not faulted. However, if faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. The kick tolerance for the 12 1/4" open hole section would be 76 bbls assuming an influx from the Kuparuk interval at -9055' TVD. This is the worst-case scenario based on a 9.70 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (based on a FIT) of 12.5 ppg at the 13-3/8" shoe, and 9.8 ppg mud in the hole. . . . . . . . DRilliNG liNER SECTION: . Mudloggers will be rigged up throughout the entire section. The directional target has been designed to pass between two faults bounding the north and south sides of the target. These faults are not expected to be penetrated, however, be prepared for any potential lost circulation. A copy of the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. Full returns were lost while weighting up the mud system from 11.3 ppg to 11.6 ppg on NS27. PWD indicated an on bottom ECD of 11.8 ppg when the losses occurred. The new casing design isolates the weaker formations above by top setting in the Miluveach. Though initial mud weight will be 11.3 ppg, the new casing design allows flexibility to increase mud weight, as required, in the Jurassic shale interval. Gas in the SAG is possible. Circulate as required. According to Geology, the top of the SAG is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.75 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" shoe, and 11.3 ppg mud in the hole. . . . . . 7 NS14 Permit to Drill Revisicl #201-118 f PRODUCTION SECTION: . Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. The drilling liner shoe will be drilled out with the 11.3 ppg mud. The mud will then be displaced with a 9.3 ppg drill-in fluid. Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. Losses are not expected but calcium carbonate (CaCO3) will be maintained in the system. Severe lost circulation was encountered on the NS29. A copy of the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan. The Ivishak is a conglomerate section. Directional control will be maintained with MWD surveys to minimize doglegs. The well is not planned to penetrate the Lisburne limestone. On offset wells, losses have been encountered in the Lisburne. The project Geologist will be in charge of picking the base of the Ivishak and only rathole sufficient to bury the open hole logs will be drilled. However, if the Lisburne is penetrated, the LCM Decision Tree will be in place on the rig. The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TD. This scenario is based on a 9.68 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.3 ppg (based on FIT) at the 7" shoe, and 9.3 ppg mud in the hole. . . . . . . 8 NS14 Permit to Drill Revisl . #201-118 ~, SUMMARY DRilliNG OPERATIONS Pre-Ria Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) Ri~L Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the top of the SV6 marker at approximately 3306' MD. POOH. 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stage. A TAM port collar will be run at +/- 1600' MD. In the event the cement does not circulate to surface, this port collar will be utilized to ensure a successful cement job is performed. 5. ND diverter / riser system and NU casing / multi-bowl wellhead. NU BOPE and test to 250/5000 psi. 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to 12.5 ppg. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point (approximately 11 ,054'MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 9.8 ppg at the top of Kuparuk. POOH. 9. RU Schlumberger. Run open hole logs, (GR/RES/NEU/DEN/Sonic/RFT) in two logging runs. POOH and RD Schlumberger. 10. Make a clean out run, if required, and condition the hole for casing. POOH. 11. Run 9-5/8", 47# intermediate casing. Cement the casing to the top of the SV2 sand in a single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with 1 annular volume of mud upon installing and testing the packoff. After WOC, freeze protect the annulus by down-squeezing diesel to 2000' MD. 12. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4300 psi with 9.8 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 13. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT targeting 13.5 ppg EMW. (FIT/LOT procedure on file with AOGCC). 14. Weight up to 11.3 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 12684' MD. POOH. 15. Run and cement a 7" 26# drilling liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting string. 16. RIH w/ 6-1/8" directional assembly and clean out to the landing collar. Pressure-test the liner to a 3700 psi with 11.3-ppg mud, (this exceeds the minimum requirement of 500 psi over the leak off pressure for liner lap testing.) This test pressure may change based on the actual mud weight in the hole and the actual FIT. 17. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe with 11.3-ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.3 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.3 ppg drill-in fluid. 18. Drill 6-1/8" production interval to the proposed TD at 13283' MD. POOH. 9 NS14 Permit to Drill Revisit. #201-118 (' 19. RU Schlumberger E-line unit. Run open hole RFT's for pressures only. POOH and RD Schlumberger. 20. Make a clean out run, if required, and condition the hole for a liner. POOH. 21. Run and cement the 4-1/2" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting tool. 22. Close the blind rams and pressure-test the liner lap to 3400 psi with 9.3 ppg fluid in the well for 30 minutes. 23. Cleanout the 4 Y2" liner to the float collar. Wash down and circulate prior to displacing to seawater. 24. Circulate to clean seawater (less than 40 NTU's) using spacers as per Baroid recommendation 25. POOH with the clean out assembly and prepare to run the 4 Y2" completion. 26. Run the 4 Y2", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 27. RIH to packer setting depth. Dual SSSV control lines will be run from the SVLN at +1- 2000' TVD (2002' MD) to surface. 28. Run space out pups and terminate the 2 - 0.25" control lines and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function test the fiber optic line. 29. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 30. RU the U-tubing manifold and pump diesel down the 4 Y2" x 9 5/8" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (4296' MD). Line up the manifold to U-tube. Monitor the flow rate around the packer. Contact AOGCC and/or MMS inspector to witness test. 31. Drop ball and rod for setting packer. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 32. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid for AOGCC/MMS required mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart and AOGCC/MMS MIT form to Drilling Engineer. 33. Bleed off annulus to 0 psi. Ensure both the tubing and annulus pressures are 0 psi. 34. Install (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Post-Ria Work: 1. MIRU slickline. Pull the ball and rod I RHC profile from 'XN' nipple below the new production packer. 2. MIRU Schlumberger Wireline. Run USIT. RD Schlumberger Wireline. 3. Perforate -140' Ivishak formation between the Top Ivishak and OWC. 4. Install DSHV Estimated Spud Date: January 8, 2001 Allen Sherritt Operations Drilling Engineer 564-5204 10 NS14 Permit to Drill RevisiJ: #201-118 ( NS14 Rig-site Summarvof Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE tØlt.~ "þ~ ,UfÞYV£ ~ fA It hJy If . f '?~ 5 t-'.~ SA;], '~, ~ ~t-?£rf'¡:t- . ,ß /'2 .'zo. ¿71 ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. ~ Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. ~ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in NS10, NS27, NS29, NS31, or NS13. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nip piing up the BOP's. ~ Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 Y2" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation, the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick- up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. ~ Bit balling on the NS29 was experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ~ The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. ~ Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. ~ Northstar is not a designated H2S pad. ~ CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 11 TREE: ABB-VGI S 1/8" Sksi ... WELLHEAD: ABB-VGI 13-S/8" ( Multibowl 5ksi 13 3/8" TAM Port Collar at +1-1600'MD 133/8", 68#/ft, L-80, BTC @ 3306' 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING ID: 3.958" CAPACITY: 0.01S22 BBLIFT 9-5/8" 47# L-80 BTM-C @ 11054' 4.5" X NIPPLE, @ 12481" 3.813" ID 4.5" X NIPPLE, @ 12506' 3.813" ID 4.5" XN NIPPLE, @ 12519' 3.725" ID 4.5" WLEG, @ 12534' 3.958" ID 7", 26#/ft L-80, BTC-M @ 12684' PBTD @ 13243' TD @ 13283' DATE 12/11/01 REV. BY JAS ,¡f(ìRIGINAL KB. ELEV = 55.9' ( -BF. ELEV = 40.2' CB. ELEV = 16.0' SSSV @ 2000' MD wi HXO SVLN nipple - 3.813" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (4296'MD) 4.S" GLM @ 4500' TVD (4939' MD) wi 3.833" I D NS14 - Proposed - 7" LINER TOP @ 10904' 4.5" Fiber Optic Transducer 3.958" ID - 7" PACKER,13 Cr @ 12491' 4.5" LINER TOP @ 12534' 4.5",12.6#, 13Cr Vam Ace Northstar ~ BP Exploration (Alaska) NS14 Schlumbørger Proposed Well Profile - Geodetic Report Report Date: December 11,2001 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 285.810° Field: Northstar 12/1 /01 Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF I NS14 eel TVD Reference Datum: KB Well: NS14 O¥ TVD Reference Elevation: 55.8 ft relative to MSL Borehole: NS14 APpr Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL UWUAPI#: 50-029- . Magnetic Declination: 26.562° Survey Name I Date: NS14 (P9) / December 11,2001 Total Field Strength: 57512.205 nT ~. Tort I AHD I DDII ERD ratio: 67.473° 16261.84 ft 15.696 / 0.554 Magnetic Dip: 80.929° , Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: January 20, 2002 Location Lat/Long: N 70.49110483, W 148.69329586 Magnetic Declination Model: BGGM 2001 Location Grid N/E YIX: N 6030951.560 flUS, E 659830.670 flUS North Reference: True North Grid Convergence Angle: +1.2317096]0 Total Corr Mag North -> True North: +26.562° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Grid Coordinates Geo ra hie Coordinates Station ID I MD Northing Easting Latitude Longitude ft ftUS ftUS. KB 0.00 6030951.56 659830.67 N 70.49110483 W 148.69329586 Ndg 1/100 400.00 6030951.56 659830.67 N 70.49110483 W 148.69329586 500.00 6030951.88 659831.48 N 70.49110565 W 148.69328916 600.00 6030952.82 659833.92 N 70.49110808 W 148.69326905 End Bid 700.00 6030954.41 659837.99 N 70.49111218 W 148.69323554 Drp 0.75/100 1200.00 3.00 70.00 1199.18 -27.59 11.64 31.97 0.00 6030963.88 659862.38 N 70.49113663 W 148.69303453 Top Permafrost 1205.60 2.96 70.00 1204.77 -27.83 11.74 32.24 0.75 6030963.99 659862.65 N 70.49113690 W 148.69303233 1300.00 2.25 70.00 1299.07 -31.30 13.20 36.27 0.75 6030965.54 659866.65 N 70.49114089 W 148.692999390-- 1400.00 1.50 70.00 1399.02 -33.96 14.32 39.35 0.75 6030966.72 659869.70 N 70.49114395 W 148.692974~ 1500.00 0.75 70.00 1499.00 -35.55 14.99 41.19 0.75 6030967.43 659871.53 N 70.49114578 W 148.69295917 Base Permafrost 1555.77 0.33 70.00 1554.77 -35.98 15.17 41.69 0.75 6030967.62 659872.02 N 70.49114627 W 148.69295508 End Drp 1600.00 0.00 70.00 1598.99 -36.08 15.22 41.81 0.75 6030967.67 659872.14 N 70.49114641 W 148.69295410 KOP Bid 1.5/100 1900.00 0.00 297.71 1898.99 -36.08 15.22 41.81 0.00 6030967.67 659872.14 N 70.49114641 W 148.69295410 Bid 2.5/100 2000.00 1.50 297.71 1998.98 -34.80 15.83 40.65 1.50 6030968.26 659870.97 N 70.49114807 W 148.69296358 2100.00 4.00 297.71 2098.86 -30.10 18.06 36.40 2.50 6030970.40 659866.67 N 70.49115417 W 148.69299832 2200.00 6.50 297.71 2198.43 -21.15 22.31 28.30 2.50 6030974.47 659858.48 N 70.49116578 W 148.69306453 2300.00 9.00 297.71 2297.51 -7.96 28.58 16.36 2.50 6030980.48 659846.41 N 70.49118291 W 148.69316213 2400.00 11.50 297.71 2395.91 9.45 36.86 0.61 2.50 6030988.42 659830.49 N 70.49120553 W 148.69329088 NS 14 (P9) report.xls Page 1 of 3 12/13/2001-8:04 AM Geographic Coordinates Station ID I MD I Incl I Azim I TVD I DLS I Northing I fasting I Latitude t Longitude ft 297.71 2493.43 2.50 6030998.26 659810.74 N 70.49123355 W 148.69345052 297.71 2589.91 2.50 6031009.98 659787.20 N 70.49126696 W 148.69364090 2700.00 19.00 297.71 2685.14 86.61 73.53 -69.20 2.50 6031023.58 659759.91 N 70.49130570 W 148.69386152 2800.00 21.50 297.71 2778.95 120.47 89.62 -99.83 2.50 6031039.01 659728.94 N 70.49134966 W 148.69411190 2900.00 24.00 297.71 2871.16 158.31 107.61 -134.07 2.50 6031056.26 659694.33 N 70.49139880 W 148.69439179 3000.00 26.50 297.71 2961.60 200.05 127.44 -171.83 2.50 6031075.27 659656.15 N 70.49145297 W 148.69470045 3100.00 29.00 297.71 3050.09 245.60 149.09 -213.04 2.50 6031096.03 659614.49 N 70.49151211 W 148.69503732 SV6 3117.96 29.45 297.71 3065.77 254.19 153.17 -220.81 2.50 6031099.94 659606.63 N 70.49152326 W 148.69510084 3200.00 31.50 297.71 3136.47 294.89 172.52 -257.64 2.50 6031118.49 659569.40 N 70.49157612 W 148.6954019- 3300.00 34.00 297.71 3220.57 347.82 197.68 -305.52 2.50 6031142.61 659520.99 N 70.49164485 W 148.6957933\. 13-3/8" Csg pt 3306.28 34.16 297.71 3225.77 351.27 199.31 -308.64 2.50 6031144.18 659517.84 N 70.49164930 W 148.69581880 3400.00 36.50 297.71 3302.22 404.29 224.52 -356.61 2.50 6031168.35 659469.34 N 70.49171816 W 148.69621094 SV5 3442.02 37.55 297.71 3335.77 429.05 236.28 -379.01 2.50 6031179.62 659446.70 N 70.49175029 W 148.69639405 End Bid 3499.09 38.98 297.71 3380.58 463.63 252.72 -410.30 2.50 6031195.38 659415.06 N 70.49179519 W 148.69664984 SV4 3853.08 38.98 297.71 3655.77 681.51 356.27 -607.42 0.00 6031294.67 659215.78 N 70.49207804 W 148.69826125 SV2 4367.62 38.98 297.71 4055.77 998.20 506.79 -893.94 0.00 6031438.98 658926.11 N 70.49248916 W 148.70060358 SV1 4882.16 38.98 297.71 4455.77 1314.89 657.31 -1180.46 0.00 6031583.30 658636.44 N 70.49290026 W 148.70294599 Top Ugnu 5358.10 38.98 297.71 4825.77 1607.82 796.53 -1445.49 0.00 6031716.78 658368.50 N 70.49328046 W 148.70511281 Top Schrader 7403.39 38.98 297.71 6415.77 2866.66 1394.84 -2584.41 0.00 6032290.43 657217.06 N 70.49491412 W 148.71442523 Cry 1/100 8215.79 38.98 297.71 7047.33 3366.68 1632.49 -3036.79 0.00 6032518.28 656759.71 N 70.49556288 W 148.71812455 Top Colville 8220.22 38.95 297.66 7050.77 3369.41 1633.78 -3039.26 1.00 6032519.52 656757.22 N 70.49556640 W 148.71814475 8300.00 38.51 296.59 7113.01 3418.35 1656.54 -3083.68 1.00 6032541.32 656712.32 N 70.49562853 W 148.71850801 8400.00 37.98 295.23 7191.54 3479.29 1683.59 -3139.36 1.00 6032567.16 656656.08 N 70.49570236 W 148.71896334 8500.00 37.46 293.83 7270.65 3539.75 1708.99 -3195.01 1.00 6032591.36 656599.90 N 70.49577169 W 148.7194184~, 8600.00 36.95 292.40 7350.30 3599.72 1732.74 -3250.61 1.00 6032613.90 656543.80 N 70.49583650 W 148.7198731 8700.00 36.47 290.94 7430.47 3659.18 1754.81 -3306.16 1.00 6032634.77 656487.80 N 70.49589673 W 148.72032736 8800.00 36.00 289.45 7511.14 3718.11 1775.22 -3361.62 1.00 6032653.99 656431.92 N 70.49595242 W 148.72078088 8900.00 35.55 287.92 7592.27 3776.49 1793.95 -3416.99 1.00 6032671.52 656376.16 N 70.49600352 W 148.72123366 9000.00 35.12 286.36 7673.85 3834.30 1810.99 -3472.25 1.00 6032687.37 656320.55 N 70.49605000 W 148.72168554 9100.00 34.71 284.76 7755.86 3891.53 1826.35 -3527.39 1.00 6032701.54 656265.10 N 70.49609189 W 148.72213644 9200.00 34.32 283.14 7838.25 3948.16 1840.01 -3582.37 1.00 6032714.01 656209.84 N 70.49612913 W 148.72258602 9300.00 33.96 281.48 7921.02 4004.17 1851.98 -3637.20 1.00 6032724.80 656154.77 N 70.49616176 W 148.72303437 9400.00 33.61 279.79 8004.14 4059.55 1862.24 -3691.85 1.00 6032733.88 656099.92 N 70.49618972 W 148.72348124 9500.00 33.29 278.07 8087.57 4114.27 1870.80 -3746.30 1.00 6032741 .27 656045.30 N 70.49621303 W 148.72392647 9600.00 33.00 276.32 8171.30 4168.33 1877.65 -3800.54 1.00 6032746.95 655990.93 N 70.49623167 W 148.72436998 NS14 (P9) report.xls Page 2 of 3 12/13/2001-8:04 AM Geo ra hie Coordinates Station ID I MD I Inel I Azim I TVD I VSee I NJ-S I EJ-W I UL~ I Nonnlng I latitude Longitude (ft\ (O\ {O\ {ft\ (ft\ (ft) (ft) (O /1000) (ftUS) N 70.49624563 W 148.72481160 N 70.49625493 W 148.72525125 9900.00 32.26 270.93 8424.01 4326.32 1887.94 -3961.83 1.00 6032753.77 655829.46 N 70.49625955 W 148.72568877 10000.00 32.07 269.08 8508.66 4377.53 1887.95 -4015.05 1.00 6032752.64 655776.26 N 70.49625950 W 148.72612391 10100.00 31.90 267.22 8593.49 4428.00 1886.24 -4067.99 1.00 6032749.79 655723.37 N 70.49625475 W 148.72655675 10200.00 31.76 265.34 8678.45 4477.71 1882.83 -4120.62 1.00 6032745.25 655670.83 N 70.49624535 W 148.72698705 10300.00 31.65 263.45 8763.52 4526.63 1877.70 -4172.92 1.00 6032739.00 655618.66 N 70.49623126 W 148.72741465 Top HRZ 10337.87 31.62 262.73 8795.77 4544.96 1875.31 -4192.64 1.00 6032736.18 655599.00 N 70.49622470 W 148.72757587 10400.00 31.57 261.55 8848.69 4574.76 1870.86 -4224.88 1.00 6032731.04 655566.86 N 70.49621249 W 148.7278394,~, Base HRZ 10408.31 31.56 261.39 8855.77 4578.73 1870.22 -4229.18 1.00 6032730.31 655562.58 N 70.49621074 W 148.727874E End Cry 10465.36 31.53 260.31 8904.39 4605.79 1865.47 -4258.64 1.00 6032724.93 655533.23 N 70.49619771 W 148.72811546 Top Kuparuk 10490.44 31.53 260.31 8925.77 4617.62 1863.26 -4271.57 0.00 6032722.44 655520.35 N 70.49619166 W 148.72822116 Kuparuc C 10642.96 31.53 260.31 9055.77 4689.60 1849.83 -4350.19 0.00 6032707.32 655442.04 N 70.49615484 W 148.72886392 Top Miluveach 10936.25 31.53 260.31 9305.77 4828.03 1824.00 -4501.37 0.00 6032678.25 655291.46 N 70.49608403 W 148.73009987 9-5/8" Csg pt 11053.57 31.53 260.31 9405.77 4883.40 1813.67 -4561.84 0.00 6032666.63 655231.23 N 70.49605571 W 148.73059423 Top Kingak 11522.85 31.53 260.31 9805.77 5104.88 1772.35 -4803.73 0.00 6032620.12 654990.31 N 70.49594242 W 148.73257175 Target 1 11675.36 31.53 260.31 9935.77 5176.86 1758.92 -4882.35 0.00 6032605.00 654912.00 N 70.49590559 W 148.73321448 Top Sag River 12637.38 31.53 260.31 10755.77 5630.90 1674.20 -5378.23 0.00 6032509.65 654418.09 N 70.49567321 W 148.73726835 Target 2 12684.30 31.53 260.31 10795.77 5653.05 1670.07 -5402.42 0.00 6032505.00 654394.00 N 70.49566188 W 148.73746611 7" Csg pt 12684.31 31.53 260.31 10795.78 5653.06 1670.07 -5402.42 0.00 6032505.00 654394.00 N 70.49566188 W 148.73746611 Top Shublik 12754.69 31.53 260.31 10855.77 5686.27 1663.87 -5438.70 0.00 6032498.02 654357.86 N 70.49564487 W 148.73776269 Top Ivishak 12854.42 31.53 260.31 10940.77 5733.34 1655.09 -5490.10 0.00 6032488.14 654306.66 N 70.49562078 W 148.73818289 Top Kavik 13235.70 31.53 260.31 11265.77 5913.29 1621.51 -5686.64 0.00 6032450.35 654110.91 N 70.49552864 W 148.73978959 TO 14-1/2" Lnr pt 13282.63 31.53 260.31 11305.77 5935.44 1617.38 -5710.83 0.00 6032445.70 654086.81 N 70.49551731 W 148.73998734 .--- Leasl Descriotion: Surface: 1179 FSL 644 FEL S11 T13N R13E UM Target 1 : 2936 FSL 245 FEL S10 T13N R13E UM Target2: 2847 FSL 765 FEL S10 T13N R13E UM BHL: 2794 FSL 1074 FEL S10 T13N R13E UM Northina m rftUSl 6030951.56 6032605.00 6032505.00 6032445.70 Esstina IX} rftUSl 659830.67 654912.00 654394.00 654086.81 NS 14 (P9) report.xls Page 3 of 3 12/13/2001-8:04 AM ~ 0) ..- O)....J -C/) o~ a a 0) N > II 0 .c .5 co ~~ ..c:f'.: .....LC') Q.LC') 0)-- oce -~ co u.¡..: .- CD "ä3a: > ð; 0)- :::::IW ..... I- ( f ( bp VERTJ:CAL SECTJ:ON VJ:EW Client: BP Exploration Alaska Well: NS14 (P9) Field: Northstar Ichlu.b8Pg8r Structure: Northstar PF Section At: 285.81 deg Date: December 11, 2001 0 . -- i I ,_._--._-~.._.. .. ~dIlI/1~0~go~[)..4C1QTVD_.. --------- 0.00' 70.001 az 0 departure --------- End Bid 700MD 700 TVD -------- 3.00' 70.00; az .6 deperture .------ /' Drp 11100 1200 MD 1199 TVD , ~ 3.00' 70.¡'az -26 departure i ' ' -. ,(=-- -- .~. .- ~~,D.!iJ~~:1~.J~~~~~e- -. ..-: TõpPërmiifr""n2OtfMO-12IJ5tm - - -- .- ---! .-d~- -'-' -- .-- __I - - -- --. - --- ..-1 Biiaoì'erm;frošfl556MO 15551'TVD --- .- - --. .- -- : i---- KOP Bid 1.5/1001900 MD 1699 TVD I : 1 . 0.00' 297.71'az -36departuro: , I ~:......__._-,.....,...._........_-.-.,........._... .................,_.... -- .--' .. -- -- Bld2.~/10020ooMD 1999TVD i i 1.50'1297.71' az -35 departure I I . . I I . 13-318" C8I Pt3306 MD 3226 TVD: i I i ~ ~.16' 297.71'az 351 departure i i ; '\~' I I II =iÞ'~~~í~~ld~~7~;~~~~d:;rtU~:i~~:~::~~:~~~: :=¡= ~~. = :~~ :_= ~:. :.:: --I - .-1 -- -..-- --- --. -- --lsÎÏ4 3853Mb 36s6ïVo-- -! - ------ -- --- - --- 1 I I I I "::1" ..:.':::--":":' ::::._'::::'::ï~~~"~~~~~-4Õ~-~D-~"':::¡-:::---"':-._-':-- C--.":" '.-'--:: 1 I 1 I I - - - - ~ -1- - - - - - -1- - - - - --I --I ISVI 4862 MD 4456 TVD ! I -1------ -...-.----..1..---.-."---.------..-1--.--.------..------1 ! I Top Ugnu 5358 MD 4826 TVD i I. I I. : :! i Hold Angle 38,980 I i 1 I I ' 1 I . I 1 1 )... .... '--il I Cry 1/100 1 ¡ -- .--. 7 ã216-MD '"iO4:¡-TVO- - 1 -- - ---- - .... -. : / i 38.98' 297.71'az . I -" --- t-- ~--~7 .~~p~~ure__- .- !--- -- --- .-_. -. --- - I ! : I ¡Ii I End Cry I . 110465 M~ 8904 TVD I I 31.53' 260.31'az I I ¿"'.""--"'.'. -4600"(jepriturë""".' -. ..¡ I ! I :-.-- :::: :~-: =~ := ::: I =.:: =: -- -. == ::.: = ~.'- I =.::: ~~~ ~ ~O(FfV¡¡== I :::: ~--:.: =-~ = = =1::::: :~:: -- =:: ~=!=3i:53':2aô:31';Z :.:: .:.:: I --- -- --- -- --- ---- ¡.- --.. 'Þ~ ~ .-. .-.. --! - ::;:~~~~~e -. - --- i -- .-- -- -. -- . -- . -:::t::'- 11..~!5 ~.D .~936_,!"i:?- - i i ~ .-- 1'-' 31.53' 200.31' az I "'1"-...... .........._.-ISI7Tdep¡iit¡¡¡ë--m............-t 1 I': Hold Angle 31.,530 \.! ---- Ta.rget2/7"C.gp~l i . \>~ 12684MD 1O796.'lD ~~: ~~ == :: ~: ~~!:: -.. --.. - - ---- ~._; _: == =~~~~:$r ~ I I I . I "".-'-'-----'-'1.-'----.- --'-"bl-"'--------"--"--"-" 1 1 i , I I 1 TD I .---_. __.~m...n""'_'--"'-"--¡'~~~:3~~f6(j;~;~r-:[)..- ¡ 5935departura I 1 i i -.1 .-- --- .n - - -_.. 2000 I --1----'-------'- I ".1 -- -.-. -- --- -.-- --.. I _I .... .-. ..-- -. - ..- I 4000+-i.c:. -~-- ::.c-':':"":": ... j 1 I - --. .-. .... .-.- '- J-- - --- -.. .- -- 6000 '-1 I ! --- - -- --- ---. -- --~';p-Sciiradõi'7403MD eii61VQ -- --- -.. I i , 1 I . _._1..._._-.....----.---.--' :Top Colville 6220 MD 7051 TVD ' i ¡ I I , ' : j .--. 1-- .. - ....... 'i' ! I ! ' I ' ~=======~= I -- ..-... --- -.- --- - '-~OPMlfùVeBëli 10936~D '93oð-Jo- , I i ' - - - - - - _1- - - - - - -1- rropKlngak 11523MD 9806TVD, .¡.......-. ........ ........ '1 , ! 8000 ---. --- ...... ..--. -. .-... 10000 12000 I I i -. - :::: :.::::¡¡:c:ïë:§ai!;.1;\lyiij~1~:E;@9.J.'-¡¡Z~:;l!YD:'- - - -.. --'~g)JV~~h'1I!5irb'--I'~#ö' ...- I I - - - ... -~öPKavik 13236MD11266 TVD I --- , I 1 1 I --...j- i 1 -2000 0 2000 4000 6000 8000 Vertical Section Departure at 285.81 deg from (0.0, 0.0). (1 in = 2000 feet) PLAN VJ:EW Client: Well: Field: BP Exploration Alaska NS14 (P9) Northstar Northstar PF 1 in = 1000 ft 11-Dec-2001 Structure: Scale: Date: -6000 -4000 -2000 -5000 -3000 3000 ~ ~ ~ ~ - nun - n_n~ ~c----~ ~-----~ ~ __n_~ --- ~. -~ n_n~ ~-----~ ~ _C~n_nu -----~ ~ -----~-~ ~ nC n__n~ ~ ------~ ~ -- _n- --- ~ -- -,--- ~ ----- -- . ~ ~ ^ ^ ^ I I- a:: a z : ' 0 \-,\b\d AZ\rt1utn 260.~'\ 2000 TD . 13283 MD 11,006 lVD 31.53' 260.31' az 1617N 5711~ 1000 I l- => a (j) v v v . \}\~ 1() .()()o '(\o\Ò þJ-\{(\ ! 0 -1000 -6000 -5000 -3000 -2000 EAST »> -4000 «< WEST Ichl.bePUBP -1000 0 En!! Cry 10465 MD 8904 1VD Cry 11100 31$3" 260.31"az . 8216MD 7047lVD ' +186..~...~, 5 N 4259W --.~"'~' 38.98' 297.71" az ~--...~! . : 1632 N 3O37W ! 1~ ' ~~.~- ¡-n-- i ~---- -In--- ~""". \. ' -- . -- ! i j ; 9-518" Csg Pt ' 11054MD. 9406lVD 't 31.53' 200.31" az arget 1 1814 N 4582 W 11675 MD 9938lVD' - ---~--T-- --'¡:;';;t21T~C-- -¡;¡-~3 260.31 az----- ------i-- -------- - ----+-~-------- ----L . 12684MD 10~lVD F59N 4882W: -- ! 31.53' 260.31" az . 1670 N 5402 W End Bid - 3499 MD 33811VD -~-3ã.9s.-297.71'-aZ-- - 253N 410W\ ~:~;~761VD /'... 34.16' 297.71'az 199N 3O9W Bid 2.51100 . - ^' 2000 Me 1999 lVD ~'" . /1.50' 297.71' az £>..... I 6 N 4 I E _u_---_u_--------~----------------_u_----------------_u- -------------- --------~--------_u- -::~~Õioo-lV.' -";/7-~/- - _no. \- - ~OPBldl.5I100 0.00' 70'()()' az 1900 MD 1899lVD ON OE 0,00' 297.71'az EndBlit 15N 42E 700 MD 700 1VD 3.00" 70.00' az 3N 7E DIp 1/1 00 1200MD 1199lVD " .: 3.00' 70,00' az --------+----------------------i-------------------- -,------------------- --~------------------ uT---------- ---_U- - -----'2N'3TE- -- True North Mag Dec ( E 26.56° ) ~_. End Drp 1600MD 1599lVD 0,00- 70.00' az 15N 42E -1000 0 3000 -~ 2000 1000 ~-- 0 -1000 ( Schlumberger Anticollision Report ( Company: BP Amoco Field: Northstar Reference Site: Northstar PF Reference Well: NS14 ReferenceWellpatb: Plan NS14 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Metbod: MD Interval: 50.00 ft Depth Range: 40.20 to 13282.63 ft Maximum Radius: 2000.00 ft Date: 12/11/2001 Time: 16:34:05 Page: 1 Co-ordinate(NE) Reference: Vertical (fVD) Reference: Well: NS14, True North N33E 55.8 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 10/18/2000 Validated: No Planned From To Survey ft ft 40.20 2400.00 2400.00 13282.63 Version: Toolcode 8 Tool Name Planned: Plan #9 V1 Planned: Plan #9 V1 GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points 3306.28 3225.77 13.375 16.000 13 3/8" 11053.83 9405.77 9.625 12.250 95/8" 12684.59 1 0795.77 7.000 8.500 7" 13282.63 11305.52 4.500 6.000 41/2" Summary Northstar PF NS09 Plan NS09 V8 Plan: Pia 1849.73 1850.00 65.37 29.87 35.52 Pass: Major Risk Northstar PF NS10 NS10 V17 699.21 700.00 29.04 10.89 18.25 Pass: Major Risk Northstar PF NS13 NS13 V12 599.84 600.00 13.77 10.18 3.59 Pass: Major Risk Northstar PF NS26 NS26 V22 1350.80 1350.00 118.31 20.82 97.49 Pass: Major Risk Northstar PF NS27 NS27 V29 2389.22 2400.00 82.57 33.35 49.35 Pass: Major Risk Northstar PF NS29 NS29 V22 399.99 400.00 150.76 7.25 143.51 Pass: Major Risk Northstar PF NS31 NS31 V14 2249.12 2250.00 159.93 34.10 125.87 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 2874.94 2850.00 302.15 45.30 257.14 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 2832.55 2800.00 293.55 43.69 250.15 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 2832.10 2800.00 293.20 41.36 252.13 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 2623.96 2650.00 245.42 43.46 202.12 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1600.90 1600.00 387.39 26.92 360.51 Pass: Major Risk Target: NS 14 King Tgt Site: Northstar PF ( Drilling Target Conf.: 99% Centre Location: Map Northing: 6032605.00 ft Map Basting: 654912.00 ft Latitude: 70o29'45.260N Shape: Circle ,j!!' t ell: NS14 Based on: Planned Program Vertical Depth: 9880.00 ft below Mean Sea Level Local +N/-S: 1758.12 ft Local +E/-W: -4882.63 ft Longitude: 148°43'59.572W Radius: 300 ft I >' § W 'i' 2300 ! 2200 !' . ",.., i 2100 "',' 1 ! 2000 , 1900 , ., 1800 :-+-- IlOO ..,.. 14-00 1500 1500 ..""",..,..""".., ","" 1300 ~ CJ CJ CJ 0 0 CJ CJ CJ CJ CJ 0 § CJ 0 0 CJ 0 0 CJ CJ CJ CJ 0 / (í) N - 0 u OJ I LD Ln J (I) 0 Lfl Lfl Lfl Lfl J J -=I- -=I- -=I- -=I- J ~ / I I I I I I I I I I I / § ~ Site: Northstar PF ( Drilling Target Conf.: 99% Centre Location: Map Northing: 6032505.00 ft Map Basting: 654394.00 ft Latitude: 70o29'44.383N Shape: Circle Target: NS14 Sag Tgt :( 'ell: NS14 Based on: Planned Program Vertical Depth: 10740.00 ft below Mean Sea Level Local +N/-S: 1669.18 ft Local +E/-W: -5402.68 ft Longitude: l48°44'14.878W Radius: 400 ft ~ ' : ! ! I ! ! i ~ /1 ~ "'l' ,. " I I I. ~ 0 / / CJ CJ OJ LJ) I CJ CJ LO LJ) I ,-+:- ì .,j.... ..-.. "..",.,'.. CJ CJ J LJ) I CJ CJ N LJ) I ....,.. ,.., 0 0 CJ Lfl I CJ CJ OJ J I 2500 24-00 2200 I ! ! 2000 1800 1500 14-00 I I I I 1200 1000 D D LO -=t- I i . t\\ ~ ~'" ~ .~\;.,~ \ ü ~), \ '" .'\ \-, '\ "'-> s:;,\ e- . ( C\>c¡\\cc()<L ~~ ,,\~~~~Cj -~ \- -\-~ \tcQ s; ,\<e ,- N<D-\-\ ~ l~S\ J ,,-~CJ +) \ ((- Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Request for Diverter Waiver-- MC 25.035 (c) Northstar 14-(NS 14, 201-118) Dear Mr. Hernandez: On May 31, 2001, the Commission received your application requesting waiver of the requirements at 20 MC 25.035 (c). This section requires that all wells be equipped with a high capacity flow diverter system before drilling below the conductor casing. 20 MC 25.035 (h) (2) provides the Commission with the discretion to approve a variance ITom the requirements of ( c) if drilling experience in the near vicinity indicates that a diverter system is not necessary. Commission staff reviewed the information provided with the application and a determination was made that the information was sufficient to support granting a waiver of the diverter requirements at 20 MC 25.035 (c). However, the Commission's approval was for each individual well, with BP required to submit current drilling information from the most recent surface hole. BP submitted the surface hole information for NS..13 via email on June 18. Commission staff has examined the provided information. It is the opinion of the Commission staff that the presented information supports waiving the diverter requirements for the surface hole ofNS..14. Your request for waiver of the requirements at 20 AAC 25.035 (c) is granted for the surface hole section of North star 14 (NS 14). Camile O. Taylor, Chair Commissioner Daniel T. Seamount, Jr. Commissioner Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this day of June, 2001 ]cÆnclosures ~' ~~!A\1JŒ (ffi~ !A\~!A\~[(!A\ ~. AlAS KA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage AK 99519 Re: Northstar Unit NS14 BP Exploration (Alaska) Inc. Permit No: 201-118 Sur Loc: 1179' NSL, 644' WEL, SEC. 11, TI3N, RI3E, UM Btmhole Loc. 4654' NSL, 2976' WEL, SEC. 10. TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Northstar Unit NSI4. 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 ofBOPE 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. Sincerely, JuLW M, Heu~y Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this J 5'Pj day of June 2001. jjc/Enc1osures cc: Department of Fish & Game, Habitat Section w/o encl. DepartmenJ..of Environmental Conservation w/o encl. NS14 Permit to Drill I ', Subject: NS14 Permit to Drill Date: Wed, 13 Jun 2001 14:08:49 -0500 From: IIKrieger, Andy GII <KriegeAG@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> CC: "Hernandez, Floyd" <HernanF1 @BP .com> Tom, You will be receiving the Permit to Drill package for NS14 later today. We are submitting this package as contingency in the event that we are not given approval to penetrate the Kuparuk interval on NS13. In the event that we do not receive the approval, we would appreciate your help in expediting the NS14 Permit given that we will be in a position to spud the well in +/- 8 days. If approval is given to drill into the Kuparuk on NS13, we will not need to permit NS14 and request that you dismiss the application. In this scenario, we will plan on re-submitting the application next year when we actually drill the well. If you have any questions please contact me and we can discuss further. Thanks Andy Krieger Operations Drilling Engineer Office: 564..5390 Cell: 240-8061 1 of 1 ,~,,' 6/14/01 2:53 Pfv1 ( STATE OF ALASKA ALASKA oil. .NO GAS CONSERVATION COMMIS!.N PERMIT TO DRILL 20 AAC 25.005 ~/I~ 0 Exploratory 0 Stratigraphic Test iii Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 55.77' Northstar Unit 6. Property Designation ADL 312799 7. Unit or Property Name Northstar Unit 8. Well Number NS14 9. Approximate spud date 06/21/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14586' MD /11294' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 470 I Maximum surface 4106 psig, At total depth (TVD) 11238' / 5230 psig Setting Depth TaD Bottom MD TVD MD TVD Surface Surface 199' 199' Driven Surface Surface 3493' 3225' 175 sx PF 'L', 470 sx Class 'G'. 1705 sx PF 'E' Surface Surface 12480' 9470' 814 sx Econolite, 497 Class 'G' 12330' 9341' 14045' 10825' 306 sx Class 'G' 13895' 10695' 14586' 11294' 108 sx Class 'G' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work iii Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1179' NSL, 644' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 4534' NSL, 2715' WEL, SEC. 10, T13N, R13E, UM At total depth 4654' NSL, 2976' WEL, SEC. 10, T13N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 312798, 5822' MD NS13 is 11.23' away at 700' MD 16. To be completed for deviated wells Kick Off Depth 1500' MD Maximum Hole Angle 18. Casin~ Program Ht..~ c.(t~ Specifications Size Casino Weioht Grade CouDIin< 20" 169# X-56 WELD 13-3/8" 68# L-80 BTC 9-5/8" 47# L-80 BTC-Mod 7" 26# L -80 BTC-Mod 4-1/2" 12.6# 13Cr Vam Ace 1 b. Type of well Number 2S 100302630-277 Hole 20" 16" 12-1/4" 8-1/2" 6-1/8" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEiVED JUN 1 3 2001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee--------Q Property plãf--- -0i30PSketch -- n__- --0 Diverter Sketch a Drilling Program iii Drilling Fluid Program 0 Time vs'Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Andy Krieger, 564-5390 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct tó the best of my knowledge Signed Floyd Hernand~~"ç. ~...~._.......... Title Senior Drilling Engineer Permit Number 201- /) Conditions of Approval: API Number 50- 0 ."2.. 9 - ;;2.-. "3 ð:z. {; Samples Required 0 Yes 2g No Hydrogen Sulfide Measures EI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: ORIGINAl, SIG~lED ~'Y -1 /)/l::;¡t) Dtte Mud L6g Required Directional Survey Required D4K J(5K D10K D15K See cover letter for other requirements 0 Yes 181 No 181 Yes 0 No 0 3.5K psi for CTU Rev. 12-01-85 Commissioner by order of the commission Date ORTGINAL bp I"- ~. l ~. .,. ,\If."'. .......~ ~.... ~~- --:...~ *~ ¡:..-. .'I'~~I\. ". BP Alaska Exploration P.O, Box 196612 Anchorage. AK 99519-6612 June 13, 2001 Mr. Tom Maunder, P.E. State of Alaska Alaska Oil & Gas Conservation Commission Reference: Dispensation for 20 AAC 25.035 (c) for Northstar Development Dear Mr. Maunder, Alaska Drilling and Wells / Northstar Development requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) II Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements" based upon development well drilling histories. Five development wells drilled through the Northstar upper stratagraphic intervals have not experienced any difficulty with shallow gas prior to running and cementing of surface casing, typically set at 3,170' tvdss depth. Each shoe has been set in the competent shale horizon below the base of the SV6. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. Additionally, the well mudlogs indicate an absence of any shallow gas hazard. Attached are the surface 1VD mud logs for development wells NS10, NS26, NS27, NS29 and NS31. A thorough review of the shallow seismic was presented to members of the AOGCC and MMS and no shallow features indicative of a gas hazard were identified above the SV5 marker. It is understood that the diverter waiver will only be in effect as long as the surface shoe remains within the shale interval above the SV5 marker. If a deeper shoe depth is requested, another review and dispensation will be required. Sincerely, ~- ¿,\ - ..,.,."", -- :::;::r:.-=?> d -~-_._"..... Floyd Hernandez Northstar Sr. Drilling Engineer NS14 Permit to Drill ( í ~ ¡Well Name: NS14 I Well Plan Summary l.!ïPe of Well (producer or injector): I Producer I Northstar Slot: NS14 Surface Location: 1179' FSL,644' FEL,Sec. 11,T13N, R13E, UM X = 659831 Y = 6030952 Target: 4534'FSL,2715'FEL,Sec.10,T13N,R13E,UM 400' Radius X = 652407 Y = 6034152 10796' TVDrkb Bottom Hole Location: 46541 FSL, 29761 FEL, Sec. 10, T13N, R13E, UM X = 652143 Y = 6034266 11294' TVDrkb I AFE Number: I 831310 I I Estimated Start Date: I June 21, I 2001 lB!9.:J Nabors 33E I Operating days to complete: 135 I RKB/Surface Elevation: (a.m.s.l.) 55.7T / 15.67' I MD 114586' I I TVDrkb: 111294' I I Well Desi9.!!...(conventional, slim hole, etc.)~ Modified Big Bore I ~ective: Ivishak Producer I Mud Program: Surf S .t S d Mud 16" Hole S . . From Surface to -3493' MD /3225' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel API FL pH (ppg) (seconds) 10 sec Initial 8.8- 9.0 200 - 300 45 - 70 >9 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 >7 15 - 25 4-10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 -100 20 - 35 >7 1 0 - 25 4 -10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Inhibited KCI 12-1/4" Hole Section From Surface Casing Shoe to 12480' MD / 9470' TVD (-top Miluveach). Interval Density (ppg) PV YP Tauo APII pH HTTP FL Initial 9.0- 9.5 1 0 - 25 20 - 28 4-7 6-10 8.5 - 9.5 Top HAl 9.6 1 0 - 25 20 - 25 4-7 4-6/<10 8.5 - 9.5 Top Kuparuk 9.8 1 0 - 25 20 - 25 4-7 4-6/<10 8.5 -9.5 to Miluveach 1 NS14 Permit to Drill ( "' ~ Drilling Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 14045' MD / 10826' TVD (top of Sag) Interval Densi PV YP Tauo APIFL H Miluveach & 11.3 1 0 - 25 20 - 25 4-7 4-6/<10 8.5 - 9.5 Kingak to top of Sa Production Hole Mud Properties: Seawater/Barite/CaCO3 Drill-In Fluid 6-1/8" Hole Section From Intermediate Casing Shoe to 14586' MD /11294' TVD Interval Density (PPQ) PV YP Tauo APIFL pH Initial/Final 9.3 1 0 - 25 20 - 25 4-7 4-6 8.5 - 9.5 Di rectional: (P7) KOP: :1:15001 MD Cantenary curve 2.0°/100' build Maximum Hole Angle: :1:46.73° - Slant Well Close Approach Well: Surface- 10' well spacing with NS13- 11.23' displacement at 700' MD. Gyro will be used for initial surveys and kickoff Survey Program: Gyros as required from surface to +/- 1500'. Standard MWD surveys from +/- 1000' to TD. Logging Program: 16" Section: Drilling: GR/Directional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals), CFM (connection flow monitorinç:) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Res, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals down to 8820' TVDrkb; thereafter, 40' intervals - 20' intervals at shows), Geochem samples from 88200' TVDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitorinq) Open Hole: Quad Combo (GR/RES/NEU/DEN/Dipole Sonic), RFT pressures only Cased Hole: None 8-1/2" Section: Drilling: GR/Directional, Res, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitorinq) Open Hole: None Cased Hole: None 6-1/8" Section: GR/Directional, Res, PWD Drilling: None Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: Quad Combo (GR/Res/Den/Neu/Sonic), RFT pressures only Cased Hole: None 2 NS14 Permit to Drill ( ( Formation Markers: Formation Tops MD TVDss Pore EMW (ppg) Comments Pressure (psi) Top Permafrost 1206 1149 517 8.65 Base Permafrost 1556 1499 674 8.65 SV6 3260 3009 1354 8.65 Set surface casing 150' tvd below top of SV6... ~ be!.. ~ ,- - - - SV5 3664 3286 1478 8.65 - .,.",. I Jr7' d';:> SV4 4125 3602 1620 8.65 SV2 4681 3983 1792 8.65 SV1 5266 4384 1972 8.65 Top Ugnu (UG4A) TMBK 5784 4739 2132 8.65 Top Schrader 8089 6319 2842 8.65 Top Seabee (CM3) 8965 6919 3112 8.65 Colville Shales Top HRl 11438 8614 3875 8.65 Base H Rl 11540 8684 3906 8.65 Top Kuparuk 11656 8764 4235 9.29 Top Kuparuk C 11922 8952 4333 9.31 Top Miluveach 12306 9264 4395 9.12 Set intermediate casing into the top of the Miluveach .A- ......, t'.-...' C"'L.....'" Top Kinqak 12855 9739 4690 9.26 -- ,«7 "'~-. '" ,- Top Sag River 13962 10698 4777 8.95 Set drilling liner into the top of the Sag River tQ., cover up the Kingak Top Shublik 14072 10793 5023 8.95 -- \ '-\ C> "" S"' I "0 ~ ':).. ç- Top Ivishak 14164 10873 5060 8.95 Top Kavik 14540 11198 5212 8.95 Proposed TD 14856 11238 5230 8.95 Top Lisburne 14967 11278 5249 8.95 c 8 /Tub8 p aslng In 9 Hole Size Csgl WtlFt Grade Conn Casing Casing Top Hole Btm Tbg C.D. Length MDITVDrkb M DITVDrkb 20" 20" 169# X-56 WELD 159' Surface 199'/199' 16" 13 3/8" 68# L-80 BTC 3437' Su rface 3493'/3225' 12 1/4" 9 5/8" 47# L-80 BTC-Mod 12424' Su rface 12480'/9470' 8 Y2" 7" 26# L-80 BTC-Mod 1715' 12330'/9341' 14045'/10825' 6-1/8" 4-1 /2" 12.6# 13Cr Vam Ace 691' 13895'/10695' 14586'/11294' Tubing 4-1/2" 12.6# 13Cr Yam Ace 13840' Surface 13895'/10695' 3 NS14 Permit to Drill _'I ~. Cement Calculations: (' The followin cement calculations are based upon a two stage job using a stage tool. Casin 13-3/8" Surface Basis: Stage 1 : Lead: Based on 1145' of 16" open hole x 13 3/8 " csg. with 50% excess. Lead TOC: -1600' Tail: Based on 750' of 16" open hole x 13 3/8" csg. with 50% excess + 80' shoe joint. Tail TOC: At -2495' MD (2495' TVD Stage 2: Lead: Based on 1600' of 16" open hole x 13-3/8" csg. with 250% excess + csg capacity. Lead TOC: Surface Staae 1: Total Cement / Spacer The followin cement calculations are based u on a single stage cement job. Casin 9-5/8" Intermediate Basis: Stage 1 : Lead: Based on 6475' of 12 1/4" open hole x 95/8" csg with 30% excess Lead TOC: At -4681' MD (4039' TVD) ail: Based on 1324' of 12 W' open hole x 9 5/8" csg with 30% excess + 80' shoe joint. ail TOC: At -11156' MD 8477' TVD Sta e 1: Total Cement / S acer Preflush Spacer Lead cement calculations are based upon a single stage cement job. 17" Drilling Liner Stage 1 : 'ail: Based on 1565' of 8 1/2" open hole x 7" csg with 30% excess + 150' 9 5/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe above TOL + 80' shoe joint. ail TOC: At -12130' MD 9171' TVD Staae 1: Total Cement / S acer Preflush Spacer Tail cement calculations are based u on a single stage cement job. 4-1/2" Prod Liner Stage 1 : ail: Based on 541' of 61/8" open hole x 41/2" csg with 50% excess + 150' 7" csg x 41/2" csg liner lap + 200' 7" Icsg x 4" drillpipe above TOL + 80' shoe joint. ail TOC: At -13695' MD 10514' TVD Sta e 1: Total Cement / S acer Preflush Spacer Tail Preflush Spacer Lead Tail Preflush Spacer Lead Tail The followin Casin Basis: The followin Casin Basis: 10 bbl sea water 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 129 bbl I 175 sx of 10.9 ppg Type 'L' Permafrost Cement. 4.15 dIsk, BHST 60° / BHCT 55°, TT = 6.0 hrs 96 bbl /470 sk of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 60° I BHCT 55°, TT = 3.0 hrs None 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 659 bbl* I 1705 sk of 12.2 ppg Type 'E' Permafrost Cement 2.17 cf/sk, BHST 60° I BHCT 55°, TT = 6.0 hrs * 2 aal Cement dve in 151 5 bbls 10 bbls sea water 50 bbl Alpha Spacer weighted to 1.0 1470 bbl I 814 sk of 11.2 ppg Econolite. 3.24 cf/sk, BHST 195° I BHCT 135°, TT = 4.0 hrs 102 bbl I 497 sk of 15.9 ppg Premium 'G'. 1.15 dIsk, BHST 195° I BHCT 135°, TT = 4.0 hrs over mud MW 4 NS14 Permit to Drill ( (' Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 5000 psi. BOPE and drilling fluid system schematics on file with AOGCC. Intermediate Section: . Maximum anticipated BHP: 4333 psi @ 8952' TVDss - Kuparuk . Maximum surface pressure: 3438 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) Drilling Liner Section: . Maximum anticipated BHP: 4997 psi @ 10698' TVDss - Sag River . Maximum surface pressure: 3927 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) Production Section: . Maximum anticipated BHP: 5230 psi @ 11238' TVDss - Total Depth . Maximum surface pressure: 4106 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 250/5000 psi (annular to 3500 psi) 8.5 ppg Seawater /6.8 ppg Diesel . Dri II i ng Hazards/Conti ngencies: HYDROGEN SULFIDE - H2S . Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A-03 exploration/appraisal wells. No H2S was detected while drilling the NS10 waste disposal well, NS27,NS29 or NS31. Reference: 1) Northstar/Nabors 33E H2S contingency plan - on file with AOGCC. 2) Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03 - on file with AOGCC. DRilliNG CLOSE APPROACH: . No close approach issues exist while drilling NS14 except for surface proximity to NS13. NS13 has 11.23' of separation at 700' MD. NS14 passes anticollision criteria with all other wells identified as a "major risk." Gyros will be run from surface to -1500' MD or until reliable MWD surveys can be taken. 5 NS14 Permit to Drill ,I' , I( SURFACE HOLE SECTION: . Mudloggers will be rigged up throughout the entire section. . No significant drilling problems have been identified in the surface hole interval (0-3225' TVD) based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. . Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. . Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre as required prior to penetrating sand intervals. . Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. . Hole stabilization in the shallow unconsolidated intervals can be problematic if mud properties are relaxed. Hi viscosities as used elsewhere on the North Slope should be sufficient to control any potential running gravels. . Gas hydrates may be present near the base of the permafrost. NS10, NS26, NS27, NS29 and NS31 have not experienced hydrates. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. INTERMEDIATE SECTION: . Mudloggers will be rigged up throughout the entire section. . Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling NS10, NS27, NS29 or NS31. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. . The shallow intervals beneath Northstar are not interpreted to be faulted. However, if faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. . Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become underbalanced. . Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. . The kick tolerance for the 12 1/4" open hole section would be 71 bbls assuming an influx from the Kuparuk interval at -11922' MD / 9008' TVD. This is the worst case scenario based on a 9.81 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (based on a FIT) of 12.5 ppg at the 13-3/8" shoe, and 9.8 ppg mud in the hole. 6 NS14 Permit to Drill ( ( DRilliNG liNER SECTION: . Mudloggers will be rigged up throughout the entire section. . The directional targets have been defined to avoid drilling into faults in this hole section. So, faults are not expected. However, if faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. . Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become underbalanced. . Full returns were lost while weighting up the mud system from 11.3 ppg to 11.6 ppg on NS27. PWD indicated an on bottom ECD of 11.8 ppg when the losses occurred. The mud program will target a maximum mud weight of 11.3 ppg initially. With the 9-5/8" casing set into the top of the Miluveach, this should allow higher mud weights to be used (as required) in this hole section. . Gas in the SAG is possible. Circulate as required. According to Geology, the top of the SAG is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. . The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval at -13962' MD / 10754' TVD. This is the worst case scenario based on a 9.45 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" shoe, and 11.3 ppg mud in the hole. PRODUCTION SECTION: . Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. The drilling liner shoe will be drilled out with the 11.3 ppg mud. The mud will then be displaced with a 9.3 ppg drill-in fluid. Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. Losses are not expected but calcium carbonate (CaCO3) will be maintained in the system. Severe lost circulation was encountered on the NS29. The LCM Decision Tree will be in place on the rig. The well is not planned to penetrate the Lisburne limestone. On offset wells, losses have been encountered in the Lisburne. The project Geologist will be in charge of picking the base of the Ivishak and only rathole sufficient to bury the open hole logs will be drilled. However, if the Lisburne is penetrated, the LCM Decision Tree will be in place on the rig. The kick tolerance for the 6-1/8" open hole section is infinite (due to the limited amount of open hole) assuming an influx from TD at -14586' MD / 11294' TVD. This scenario is based on a 9.45 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient of 11.3 ppg (based on FIT) at the 7" shoe, and 9.3 ppg mud in the hole. . . . . . Disposal: . There will be no annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS10 Class I Waste Disposal Well. . Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS1 0 Class I Waste Disposal Well. 7 NS14 Permit to Drill (' ( SUMMARY DRilliNG OPERATIONS Pre-Ria Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. 2. Install 7' x 7' cellar and polyshield same. Ria Operations: 1. MIRU Nabors 33E. 2. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3493' MD /3225' TVD (+/-150' TVD below the top of the SV6 marker). POOH. 3. Run 13-3/8", 68# surface casing. Cement the casing to surface in 2 stages using a stage tool at +/- 1600' MD. 4. NU casing / tubing head. NU BOPE and test to 250/5000 psi. 5. MU 12-1/4" directional assembly and RIH to stage tool closing plug. Pressure test the casing to 1000 psi for 5 min. Drill plug and RIH to float collar. Test the 13-3/8" casing to 2500 psi for 30 min. 6. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to 12.5 ppg. (FIT/LOT procedure on file with AOGCC). 7. Drill 12-1/4" intermediate hole to casing point at approximately 12480' MD / 9470' TVD (into the Miluveach). Minimum mud weight of 9.6 ppg at the top of HRl and 9.8 ppg at the top of Kuparuk. POOH. 8. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic;RFT). POOH and RD Schlumberger. 9. Run 9-5/8", 47# intermediate casing. Cement the casing to +/- 4681' MD (top SV2 sand) in a single stage. Pack off the casing hanger. Perform a downsqueeze on the 9-5/8" x 13-3/8" annulus with 1 annular volume of mud immediately following the cement job. Downsqueeze diesel to 1800' MD for freeze protection after WOC. 10. MU 8-1/2" directional assembly and RIH to float collar. Pressure test the 9-5/8" casing to 3000 psi for 30 min. 11. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a Leak Off Test. (FIT/LOT procedure on file with AOGCC). 12. Weight up to 11.3 ppg prior to drilling ahead. Drill the drilling liner hole to 14045' MD / 10826' TVD (top of Sag). POOH. 13. Run and cement a 7" 26# drilling liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting string. 14. RIH w/ 6-1/8" directional assembly and clean out to the landing collar. Pressure test the liner to a minimum of 500 psi over the leak off pressure established in Step 11 above. 15. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe with 11.3 ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.3 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.3 ppg drill-in fluid. 16. Drill 6-1/8" production interval to TD at approximately 14586' MD / 11294' TVD. POOH. 17. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic;RFT). POOH and RD Schlumberger. 18. Make a clean out run, if required, and condition the hole for a liner. POOH. 19. Run and cement the 4-1/2" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting tool. 20. RIH with 3-3/4" cleanout assembly. Clean out to PBTD. Pressure test to 3450 psi for 30 minutes with a 9.3 ppg fluid to confirm the system integrity. 21. Displace well to 8.5 ppg seawater and monitor. POOH. 22. Run the 4-1/2", 12.6#, 13Cr Vam Ace completion assembly to the top of the 4-1/2" liner at +/-13895' MD. Run a GLM at 3000' MD and a SSSV at 2000' MD. 23. Land the tubing hanger. 24. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 8 NS14 Permit to Drill (' f 25. Displace annulus with inhibited seawater. 26. Set the packer. Pressure test the tubing and annulus to 4200 psi for 30 minutes. Shear the RP Shear Valve in the GLM. FP with diesel to +/-3000'. U-tube diesel to tbg. side. 27. Install BPV. Rig down and move off. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'XN' nipple below the new production packer. 2. Pull the shear valve in the GLM and replace with a dummy valve. 3. Perforate interval based on PE recommendation. Estimated Spud Date: 6/21/01 Andy Krieger Operations Drilling Engineer 564-5390 9 NS14 Permit to Drill { ( NS14 RiQsite Summary of Drillin~ Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. ~ Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. ~ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in NS10, NS27, NS29 or NS31. Mudloggers will be used continuously on NS14 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. ~ Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The intermediate casing is being set prior to weighting up the mud (for the Kingak). To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. ~ Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick-up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. ~ Bit balling on the NS29 was experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ~ The Kingak shale, in the offset wells, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight (11.3 ppg) and low angle (30 deg) will help with hole conditions. ~ Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig. ~ Northstar is not a designated H2S pad. CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 10 KB Bid 1/100 Drp 1/100 Top Permafrost Report Date: Client: FIeld: Structure I Slot: Well: Borehole: UWIIAPII: Survey Name I Date: Tort I AHD I DOli ERD ratio: Grid Coordinate System: I.oc8tIon LatILong: Location Grid HIE yæ Grid Convergence Angle: Grid Seale Factor: NS14 SChlulberger Proposed Well Profile - Geodetic Report June 11, 2001 BPXA Northstar NorthstarPF/NS14 d a APprove NS14 (P7) I June 11, 2001 73.484° 18373.77 ft/5.900 I 0.741 NAD27 Alaska State Planes, Zone 04, US Feel N 70 29 27.977, W 148 41 35.~ N 6030951.560 ftUS, E 659830.670 ftUS +1.23170967° 0.99992902 Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical SectIon Azimuth: 289.330° VerUcal SectIon Origin: N 0.000 ft, E 0.000 ft TW Reference Datum: KB TW Reference Elevation: 55.77 ft relative to MSL Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL Magnetic Declination: 26.756° Total FIeld Strength: 57504.227 nT Magnetic DIp: 80.921° Declination Date: June 28, 2001 Magnetic Declination Model: BGGM 2001 North Reference: True North Talal Corr Mag North -> True North: +26.756° Local Coordinates Referenced To: Well Head '--'- 06/1 01 GrId Coordlnltel Ie Coordinates TVD NorthIng Eattlng latitude Longitude 'ft S flUS 280.00 0.00 6030951.56 659830.67 N 702927.977 W 14841 35.865 280.00 500.00 6030951.56 659830.67 N 70 29 27.977 W 14841 35.865 280.00 599.99 6030951.69 659829.81 N 702927.979 W 148 41 35.890 280.00 699.96 6030952.10 659827.22 N 702927.983 W 14841 35.966 280.00 799.86 6030952.75 659822.91 N 702927.991 W 148 41 36.093 900.00 4.00 280.00 899.68 13.77 2.42 -13.74 1.00 6030953.68 659816.88 N 702928.001 W 14841 36.269 1000.00 5.00 280.00 999.37 21.51 3.79 -21.47 1.00 6030954.89 659809.13 N 702928.015 W 14841 36.497 1100.00 4.00 280.00 1099.06 29.26 5.15 -29.20 1.00 6030956.08 659801.37 N 702928.028 W 14841 36.724 1200.00 3.00 280.00 1198.87 35.28 6.21 -35.21 1.00 6030957.01 659795.34 N 70 29 28.038 W 148 41 36.901 1205.91 2.94 280.00 1204.77 35.58 6.26 -35.51 1.00 6030957.06 659795.04 N 702928.039 W 14841 36.910 .--'-, 1300.00 2.00 280.00 1298.77 39.58 6.97 -39.51 1.00 6030957.68 659791.02 N 702928.046 W 14841 37.028 1400.00 1.00 280.00 1398.74 42.17 7.42 -42.08 1.00 6030958.07 659788.44 N 702928.050 W 14841 37.103 1500.00 0.00 280.00 1498.73 43.03 7.57 -42.94 1.00 6030958.21 659787.58 N 702928.052 W 14841 37.129 1556.04 0.56 289.39 1554.77 43.30 7.66 -43.20 1.00 6030958.29 659787.32 N 70 29 28.053 W 14841 37.136 1600.00 1.00 289.39 1598.73 43.90 7.86 -43.77 1.00 6030958.48 659786.74 N 702928.055 W 14841 37.153 1700.00 3.00 289.44 1698.66 47.39 9.02 -47.06 2.00 6030959.57 659783.43 N 702928.066 W 14841 37.250 1750.00 4.00 289.45 1748.57 50.44 10.04 -49.94 2.00 6030960.52 659780.53 N 702928.076 W 14841 37.335 StatIon 10 End Drp I KOP 1/100 Base permafrost Bid 2/100 Bid 3/100 NS14 (P7) report.xls Page 1 of 3 6/12/2001-10:45 AM Station 10 I (ft, I (O' I (O' I (ft) I (ft) I (ft) I (ft) I (0/100m..j (ftUS) L-J!!Y!L...J , N 702928.090 W 14841 37.449 N 702928.135 W 14841 37.781 N 70 29 28.201 W 148 41 38.252 2100.00 14.49 293.53 2093.54 106.47 31.64 -101.73 3.00 6030981.00 659728.29 N 70 29 28.289 W 148 41 38.859 2200.00 17.49 293.80 2189.66 133.92 42.70 -126.95 3.00 6030991.52 659702.84 N 70 29 28.397 W 14841 39.601 2300.00 20.48 293.99 2284.21 166.35 55.88 -156.68 3.00 6031004.06 659672.84 N 70 29 28.527 W 14841 40.476 2400.00 23.48 294.14 2376.93 203.65 71.14 -190.86 3.00 6031018.58 659638.34 N 70 29 28.677 W 14841 41.482 2500.00 26.48 294.25 2467.56 245.73 88.45 -229.38 3.00 6031035.05 659599.46 N 70 29 28.847 W 14841 42.615 2600.00 29.48 294.35 2555.86 292.47 107.76 -272.14 3.00 6031053.44 659556.30 N 70 29 29.037 W 14841 43.873 2700.00 32.48 294.42 2641.59 343.74 129.02 -319.02 3.00 6031073.68 659508.97 N 70 29 29.246 W 14841 45.253 2800.00 35.48 294.49 2724.50 399.41 152.16 -369.89 3.00 6031095.72 659457.62 N 70 29 29.474 W 14841 46.750 ---c 2900.00 38.48 294.55 2804.37 459.31 177.12 -424.62 3.00 6031119.50 659402.37 N 70 29 29.719 W 14841 48.361 3000.00 41.48 294.60 2880.98 523.29 203.83 -483.05 3.00 6031144.95 659343.39 N 70 29 29.982 W 148 41 50.080 3100.00 44.48 294.64 2954.13 591.17 232.23 -545.02 3.00 6031172.01 659280.82 N 70 29 30.261 W 14841 51.904 End Bid 3175.03 46.73 294.67 3006.62 644.55 254.60 -593.75 3.00 6031193.32 659231.63 N 70 29 30.481 W 14841 53.338 SV6 3259.88 46.73 294.67 3064.77 706.06 280.38 -649.89 0.00 6031217.89 659174.95 N 702930.735 W 14841 54.990 13-3/8" Csg Pt 3493.32 46.73 294.67 3224.77 875.31 351.33 -804.36 0.00 6031285.49 659019.00 N 702931.432 W 14841 59.536 SV5 3664.02 46.73 294.67 3341.77 999.07 403.22 -917.31 0.00 6031334.94 658904.97 N 702931.942 W 148422.860 SV4 4125.07 46.73 294.67 3657.77 1333.33 543.34 -1222.39 0.00 6031468.46 658596.97 N 70 29 33.320 W 148 42 11.839 SV2 4680.95 46.73 294.67 4038.77 1736.35 712.29 -1590.22 0.00 6031629.45 658225.62 N 70 29 34.981 W 1484222.665 SV1 5266.01 46.73 294.67 4439.77 2160.53 890.11 -1977.36 0.00 6031798.90 657834.78 N 702936.729 W 1484234.060 Top Ugnu 5783.96 46.73 294.67 4794.77 2536.04 1047.53 -2320.09 0.00 6031948.90 657488.77 N 702938.276 W 1484244.148 Base Ugnu 8089.19 46.73 294.67 6374.77 4207.36 1748.16 -3845.48 0.00 6032616.53 655948.78 N 70 29 45.160 W 1484329.053 Top Colville 8964.60 46.73 294.67 6974.77 4842.04 2014.23 -4424.74 0.00 6032870.07 655363.98 N 70 29 47.774 W 1484346.107 Top HRZ 11437.61 46.73 294.67 8669.77 6635.00 2765.85 -6061.16 0.00 6033586.29 653711.90 N 70 2955.154 W 1484434.293 Base HRZ 11539.74 46.73 294.67 8739.77 6709.04 2796.89 -6128.74 0.00 6033615.87 653643.68 N 70 29 55.459 W 1484436.284 Top Kuparuk 11656.47 46.73 294.67 8819.77 6793.66 2832.37 -6205.97 0.00 6033649.68 653565.71 N 70 29 55.807 W 1484438.558 ---~. Drp 3/100 11743.02 46.73 294.67 8879.10 6856.42 2858.68 -6263.25 0.00 6033674.75 653507.88 N 702956.066 W 1484440.245 11800.00 45.02 294.67 8918.76 6897.14 2875.75 -6300.41 3.00 6033691.01 653470.36 N 702956.233 W 14844 41.339 11900.00 42.02 294.67 8991.26 6965.70 2904.49 -6362.99 3.00 6033718.40 653407.19 N702956.515 W1484443.182 Kuparuk C 11922.11 41.36 294.67 9007.77 6980.34 2910.62 -6376.35 3.00 6033724.24 653393.70 N 70 29 56.576 W 1484443.576 12000.00 39.02 294.67 9067.27 7030.39 2931.60 -6422.03 3.00 6033744.23 653347.58 N 70 29 56.782 W 1484444.921 12100.00 36.02 294.67 9146.57 7091.03 2957.02 -6477.37 3.00 6033768.46 653291.71 N 702957.031 W 1484446.551 12200.00 33.02 294.67 9228.95 7147.45 2980.68 -6528.87 3.00 6033791.00 653239.72 N 70 29 57.263 W 1484448.067 12300.00 30.02 294.67 9314.18 7199.50 3002.50 -6576.37 3.00 6033811.79 653191.76 N 70 29 57.478 W 1484449.466 NS 14 (P7) report.xls Page 2 of 3 6/11/2001-3:04 PM StaUon ID I MD I Inel I Azlm I TVD I VSee E/.W oft ft End Orp 12300.79 30.00 294.67 9314.87 7199.90 -6576.73 3.00 6033811.95 653191.40 N 70 29 57.479 W 1484449.477 Top Miluveach 12306.45 30.00 294.67 9319.77 7202.71 -6579.31 0.00 6033813.08 653188.80 N 70 29 57.491 W 1484449.553 9-5/8" Csg Pt 12479.66 30.00 294.67 9469.77 7288.94 -6658.00 0.00 6033847.52 653109.35 N 70 2957.846 W 1484451.870 Top Kingak 12854.94 30.00 294.67 9794.77 7475.77 3118.31 -6828.52 0.00 6033922.15 652937.20 N 70 29 58.614 W 1484456.892 Top Sag River 13962.30 30.00 294.67 10753.77 8027.04 3349.41 -7331.66 0.00 6034142.36 652429.25 N 70 30 0.882 W 1484511.711 Target 14010.79 30.00 294.67 10795.77 8051.19 3359.53 -7353.70 0.00 6034152.01 652407.00 N 70 30 0.982 W 1484512.360 7" Csg Pt 14045.43 30.00 294.67 10825.77 8068.43 3366.76 -7369.43 0.00 6034158.90 652391.12 N 70 301.053 W 1484512.824 Top Shublik 14071.99 30.00 294.67 10848.77 8081.65 3372.31 -7381.50 0.00 6034164.19 652378.93 N 70 30 1.107 W 148 45 13.179 Top Ivishak 14164.37 30.00 294.67 10928.77 8127.64 3391.58 -7423.47 0.00 6034182.55 652336.56 N 70 301.296 W 1484514.415 Top Kavik 14539.65 30.00 294.67 11253.77 8314.46 3469.90 -7593.99 0.00 6034257.18 652164.41 N 70 30 2.065 W 1484519.438 TO 14-1/2" Lnr Pt 14585.83 30.00 294.67 11293.77 8337.46 3479.54 -7614.97 0.00 6034266.37 652143.23 N 70 30 2.159 W 1484520.056 "-"--- Legal Description: Surface: 1179 FSL 644 FEL S11 T13N R13E UM Target: 4534 FSL 2715 FEL S10 T13N R13E UM BHL: 4654 FSL 2976 FEL S10 T13N R13E UM Northing (Y) fftUSl 6030951.56 6034152.01 6034266.37 Easting {X) fftUSl 659830.67 652407.00 652143.22 ~- NS14 (P7) report.xls Page 3 of 3 6/11/2001-3:04 PM f ( valflCAL Client: Well: Field: Structure: Section At: S8C'1'IOR nn BPXA NS14 (P7) Northstar Northstar PF 289.33 deg June 11, 2001 lehloDlberDer Date: 0 !lid 1/1 ISOO MD ISOO 1VO ----- 0.00" .00" 8Z 0 departure -- Orp111 1000MO 9981VO ------------ 5.00" 2 0.00' IZ 22 depaIIure End Drp KOP 111001500 MO 1499 NO - -- -- -0 - -. - ~-o 00'" .00'"8%""43 dwpIrture -- -. -------- . -- ----- ~-::_-=-=- -..cf111 1800'MIr 1m TV[) 1.00' 28 ,39' az 44 departure ....... o~~'Bíëïil1'--17SÔMë"--1¡;¡iïVD--'-'-'--"-'" 4.00' 2 D.45' 8Z 50 departure E 81c13178 MO 3007 NO ------ 4 ,73' 2e4.87' 8Z 845 departure .....-' -~-- ---- ~ ;a.~?~.~.IZ.D._3.. 8.M.~.O..d....ep.~.."ertu...5=i... O..~..~.... ....~.-..-...S.=.V.'.. 6..~...~..3.~..2.-.6...0.~. -. M.. -.'-1.. .~...9....6.J...T..=. V" .~...~. =. = =.'...:. ..~.-... := ~~ =.' -- -.. ,... -. - .~~- SV5 3664 M 3342TVD .. -. ..-- -.... -.-1 -- -. -.. -- -. -- .--- --. -- -- .- -- 8\14- 4125-1\11- 365-8 TVD """"""""""""""""""""""""""""""'oc:"""""="""',-,-",-"",="""-""""".",,,,-,..,=...,,,.1--"""',.0..:""--- :-.:'" - - SV2 4681 M 4039 TVD - -- - .- .-- - - - - - - - -, - - - - - - :~:;;~:~~~1t2:~:6~:Õ_1~~:5T~D-- -. .- -- 2000 Z" 0) - O)..J ~cn g:E 0 0) C\I > II .8 c: CO ;:..;e .1::.1': -LC) c.LC) 0)- Ceo -~ CO (J1t-: .- 0) i~ > ã> 0)- 2W ~ ,- -- --" --, .-- ,_... .._, 4000 .- ....- -.., -..' -...- -------------------- _.. --- ...- - -- -,- - -- - - ,- --- -> - -. ~~~u5~n6u~~~4~~~~TVD- -I - - - - 6000 Hold Angle 46.73° -~äse Ugnu 8089 -MÕr 63'75- TYb --- - - - - - - - - - -- -- --- -"!õp ëõIViile-896Çr"v1 ------------------------- 6975 TVD Drp 3Iroo 11743 MO 8879 NO 48,73' 2e4.87' ez 8858departure 8000 End Drp 12301 MO D3151VO / 30,00' 2e4,87' ez 7200 departure ,-- j$~~@~' Kup~~rê 11922 M ,..!.. -- ..- - - -. -- Top Miluveach 1230 I ,'. _.=.,'~. ,..:1àp.l<¡'ngãk~j.285[.M~~...:9Z9s.jÿ[.--=--.--==.. ..= =3====::= D ,...- - --. - -> -. -- - -- .._, -,_. .-., - .._, --- -- - - -- .-, - - f)'t;~ --- Do1I/8" CaD PI124BO MD e470 NO ,.~._. ""30.00' 2"D4,87'"z 72BDdepørture .- -..-- - --, - -, -, --- -,- --- Hold Angle 30.00° t ~,Target 14011 MD 107981VD --..----~ 30,00' 294,67' IIZ 8051 depørture ,,/ 10000 -.---.----.,---- -. = -::::--. r Ceg PI 14045 MO 10826 rYO 30.00' 294.67' "z BoeB departure ,.= ::: ::: :::+~ 8:aaiffiiwr;¡:;1,39 ¡fOP 1V'i!mä~ 1'm4=' Top Kãvik 14540 MD1 f1254 TVD - - ======:"'---- -------- - - -- {)tJ " 12000 TO 140112" Lnr PI 14588MO 11294ND -..-.........,..--.....,......,.---...............,......."....."."""+""""""""'-'30~""294;67' az B337 depørture 0 2000 4000 6000 8000 Vertical Section Departure at 289.33 deg from (0.0, 0,0). (1 in = 2000 feet) -10000 P LAN VJ: EW Client: BPXA Well: NS14 (P7) Field: Northstar Structure: Scale: Date: Northstar PF 1 in = 2000 ft ll-Jun-2001 -8000 -6000 -4000 6000 , -. -- . -~._--- . ----~---¡-----~------! -~------ ____n__+__w__n_____--- ^ ^ ^ J: ~ 0 Z rCsgPt ! 14045 Me 10s26lVD 30.00' 294.eriaz 3367N7369' Tt)401lTLNPt i 14586MD 11294lVD! 30.00' 294.67" az 3480 N 1615 W 4000 2000 J: t- ::> 0 (/) V V V 0 -2000 -10000 -c----- -------_. T8I'8t , 14011 MD 10196~ 30.00' 294.87" az I 3360 N 7354 W' End DIp ; 12301 Me 9315lVD ¡ - -~_. --3O.000-29.ï:6raz--'--T 3003 N 6511 W DIp 3/100 : 11743MD 887!ilVD 46.73' 294.61' ÎIZ 2859 N 6263 vi I-tO/(j -'k. : - "'<II't7lJII) <. ¡ '9r4.6)'O --------- ------ -8000 -6000 «< WEST -4000 -2000 EAST »> Schlumbepuep -2000 0 2000 ¡~ Ii.:,.' r-n'R p.....¡- "V' i i NIr Csg PI - ¡ -- -'24scfMO 94701'.lD- - ¡ 30.00" 294.67" az 3040 N 665S W - 130311" Csg PI - 3493 MO -- 322'5lVD 46.73° 294.61' az 351 N SO4W \ i BlcIlI1oo \ i 500 MD 500 lVD : 0.00' 28O.lX)" az ! \ ¡ ION OE ' i~!VDrpll1ao ¡ : 'i I000MD GDIIlVO i- --~ .. ¡ L . 5.00" 280.00' az ! EndJIcI--/ -- _1- \~ ~:D::OP1I11 3115~D 3OO~lVD !\ 1500MD 1499lVD 46.13".",.;. 294.67 az / : \ 0.00' 280.00" 8Z i 255Ni 594W 8N 43W i . : i , B1c13/1oo ¡ BIcI2I100 . . 1150 MD 1149lVD i 1800 MD 1599lVD 4.00' 289.45° az 1.00' 289.39" az ION SOW ; 8N 44W True Borth Mag Dee ( E 26.760 ) ~ 0 2000 6000 .-°- 4000 2000 0 .----~. -2000 ( Schlum berger Anticollision Report (' I. COID,..y: ,BP Amoco "Datê:èJ11~1 ' Pa.: ÐL."". ..~... ','",,', ,'"",,".' , r_. ._u- ' ',' ' ,ReferellœSJte:, NorthstårPF , ~;i(~ weD: NS~4.True North Ref'er'ebœ WeD: NS14Vertkal(1'VDl~~ ~E 55.8 Retereaœ Wellpatb:PlanNS14 ' 'Db: Sybase J ---, NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM i i Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse ! I Depth Range: 40.20 to 14660.87 ft Scan Method: Tray Cylinder North ' \ Maximum Radius: 10000.00 ft Error Suñace: Ellipse + Casing I Survey Program for Definitive Wellpath i Date: 10/18/2000 Validated: No Version: 2 [Planned From To Survey Toolcode Tool Name ft ft , 40.20 1500.00 Planned: Plan #7 V1 GYD-GC-SS Gyrodata gyro single shots 1500.00 14585.83 Planned: Plan #7 V1 MWD MWD - Standard ---, I I _l Casing Points 3493.30 3224.77 13.375 16.000 133/8" 12479.24 9469.77 9.625 12.250 9 5/8" 14045.02 10825.77 7.000 8.500 7" 14585.42 11293.77 4.500 6.000 4 1/2" --- --.---- Summary -------'-' Northstar PF NS10 NS10 V17 699.49 700.00 27.26 10.87 16.46 Pass: Major Risk Northstar PF NS13 Plan NS13 V7 Plan: Pia 699.85 700.00 11.23 13.40 -2.17 FAIL: Major Risk Northstar PF NS26 NS26 V22 1501.19 1500.00 123.67 22.01 101.67 Pass: Major Risk Northstar PF NS27 NS27 V29 898.65 900.00 130.77 16.78 114.00 Pass: Major Risk Northstar PF NS29 NS29 V20 399.98 400.00 150.82 8.26 142.56 Pass: Major Risk Northstar PF NS31 NS31 V13 999.14 1000.00 170.29 18.09 152.21 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 2301.88 2300.00 360.04 38.52 321.82 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 2307.07 2300.00 346.38 36.81 309.85 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 2306.83 2300.00 346.53 35.10 311.71 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 2281.10 2300.00 331.39 38.01 293.71 Pass: Major Risk Seal Island SEAL-A-O4 SEAL-A-04 V4 1703.69 1700.00 405.18 27.55 377.65 Pass: Major Risk ------------,,-----, (' I( 320 300 200 100 0270 ,..-.,100 "-200 -JOO 320 NS 14/Plan NS 14 lvS29 avS29) 90 z rJ). tV -......1 Z rJ). 120 ~ d u> ~ ~1-. ~ ~ NS1O (NS1O) ~ravelling Cylinder Azimuth (TFO+ AZI) [deg] vs Centre to Centre Separation [ft """"","""""""""",""""","""""""""","",, NSI0 (NSI0) NS26 (NS26) NS29 (NS29) SEAL-A-O 1 (SEAL-A-O 1) SEAL-A-O2 (SEAL-A-O2A) SEAL-A-O4 (SEAL-A-O4) NS13 (Plan NS13) NS27 (NS27) NS31 (NS31) SEAL-A-O2 (SEAL-A-O2) SEAL-A-O3 (SEAL-A-O3) ~,,-,,".g-~ Site: Northstar PF Drilling Target Conf.: 95% Centre Location: S 14 Map Northing: 6034152.00 ft Map Easting : 652407.00 ft Latitude: 70030'OO.982N Shape: Circle ( Target: NS14 w~. 'TSI4 Ba( n: Planned Program VertIcal Depth: 10740.00 ft below Mean Sea Level Local +N/-S: 3358.32 ft Local +E/-W: -7354.23 ft Longitude: 148°45'12.36OW Radius: 400 ft /~-- .--/-- // // I ",,---- /' / '----"---' / / -" "" / """- --- ~------- ~~ '\ ~~~ / ~~~ / ""rf> ~ / ~ cyCY / ~~~ /X> <:o\)~ /«3 ~a °0 ~& (/0 ~~ <?6: B' <?O ~oo ~OO ------------- {/ °q; ~&oo ~ôoo /ý TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8", 68#/ft, L-80, BTC @ 3493' 4.5", 12.6#/ft, 13-Cr, Vam Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLIFT 9-5/8" 47# L-80 BTC-M @ 12480' 4.5" X NIPPLE, @ 13838" 3.813" ID 4.5" X NIPPLE, @ 13878' 3.813" ID 4.5" XN NIPPLE, @ 13888' 3.725" ID 4.5" WLEG, @ 13898' 3.958" ID 7", 26#/ft L-80, BTC-M @ 14045' PBTD @ 14506' TD @ 14586' DATE 6/12/01 REV. BY AGK ( NS14 O~Jr,INAL KB. ELEV = 55.77' B( .EV = 40.2' CB. ELEV = 15.57' SSSV @ 2000' MO wi HXO SVLN nipple - 3.813" 10 6.8PPG DIESEL FREEZE PROTECTION AT +1- 2000 4.5" GLM @ 3000' MD wi 3.833" ID - 7" LINER TOP @ 12330' - 7" PACKER, 13 Cr @ 13858' COMMENTS 4.5" LINER TOP @ 13895' 4.5", 12.6#, 13Cr Vam Ace Northstar WELL:NS14 ~ BP Exploration (Alaska) ( { DATE 06/04/01 CHECK NO. 00191145 H 191145 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA . NET 00 060101~CK060101A PYMT OMMENTS: HANDL NG INST: 100.00 100.00 PERMIT TO DRILL ~EE S/H 1- TERRIE HUBBLE X4628 "--Y5l~ rHE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ " FIRST NATIONAL BANK OF. ASHLAND ," " ANAFFILIATEOF NATIÓNAL CITY BANK CLEVELAND, OHIO , . , CONSOLIDAiED, COMMÈRCIAL ACCOUNT , " BP EXPLORATION, (ALASKA)INC; P.O. BOX 196612 ANCHORAGE, ALASKA99519-6612 56-389 412 '00191145 PAY D~,~"HUNÎlRED :8t 00 [lOG~~*"*"*************~**t~~~*~~********** uå, DS,~LAR , ", , " """"",': ,:""',,'" ":':"" ", ',',' ' :",,: To The ORDER Of """',"',', III . q ~ .... 5 III I: 0'" . 2 0 ~ 8 g 5 I: 0 0 8 ...... . g III ~ ,,',", " :" ',""" ':.: ' " i, ')DATE; 'AMOUNT [, ,: ~~V o4i 0 1+ ",¡.it'i 00 .:Q:O, j " ,,;: <, ,,' ' ,;" " , "' ' ,'" ,', , :," ,,' '" ' , NQT)/ALID ÁFrER fgO DAYS ", ~;i,;;"::,',".,,:,:,:,',,,:;, ,', """",'~: ",','~\,';,::"~"--";""'",'., \il~~(!//14. ~ -^-:::::':::\~~("':!:/;:-""';""~ ,. ..- ( ¡ TRANSMIT AL LETTER CHECK LIST CIR CLE APPRO PRIA TE LETIERJP ARA GRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER ¡1/$ ~ / t/ WELL NAME Tht~\~ 0. r-~ ,~tJt. ~q ~ <:",~o-"'~Cè ~'" ~~. t> \ ~ It Ç" ~ '" '-I.j C..\ '\ -V ~ \" 't. ~ \'00\ ~ ~ c?J 6-@. ~ CHECK 1 ST AND ARD LETTER DEVELOPMENT CHECK WHAT APPLIFS ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) / DEVELOPMENT RED RILL PILOT HOLE (PH) EXPLORATION INJECTION WELL ANNULAR DISPOSAL <----> YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, . API No. .' . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER I Please note that an disposal of fluids generated. '. . ANNULUS L-J YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company ~ame) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY FIELD & POOL 5£}0 //:i') INIT CLASS ADMINISTRA TION 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 wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . ApPR DATE 12. Permit can.be issued without administrative approval.. . . . . ,~ z;Z¡) ,. . I. -D. 13. Can pennit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . .. . . . . . . . . . 15. Surface casing proteds all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on condudor & suñ csg. . . . . 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive hoñzons. . . . . '. . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-dñll, has a 10-403 for abandonment been approved. . . 22. Adequate well bore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . .~. . . . DATE 26. BOPE press rating appropñate; test to psig. \;) ~I . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . GEOLOGY. 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. Y ~ 31. Data presented on potential overpressure zones. . . . ~. . Y N . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . .' Y N AP. R DATE, 33. Seabed condition survey (If off-shore). . . . . . . . . . . . Y N 1/ z . UJ .01 34. Contact name/phone for weekly progress reports [explo ry only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; .. . . (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:.. UIC/Annular COMMISSION: ~þ~ ~m' ~ wr:l----- . -8~s ~ TE~\:JI;. ~ JM" ENGINEERING APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) saN well bore seg ann. disposal para req UNIT# O//:::;J¿;>¿J ON/OFF SHORE O¡cç 0 0 0 Z 0 -t ~ ~ ( -t m - Z -t . .:I: - Y N Y N b~~~oc:..:.û.\ \~~O c...\o.~~ ~ ~~-\O en :Þ ~ m :Þ ( Com ments/lnstructions: '2.{::L~1 0\ WELL PERMIT CHECKLIST COMPANY .D f./ WELL NAME /7' FIELD & POOL S9G / ó CJ INIT CLASS {)e.J/ / -ò,' / , ADMINISTRATION 1. Permittee 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.. . . . . . . . . . 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. . . . . . . . . . 'ò . . . . 26. BOPE press rating appropriate; test to 5e:û psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdöwn. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. .. . . . . . . . . . . ÃfiR J?~::rE) 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~ ~I 34. Contact name/phone for weekly progress reports [exploratory onJtJ Y ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. " to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) 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 GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~þ¡tl!¿ ~~ ~~. f./~r:---..., 9gs ~ R 1J?/c °/ ENGINEERING DATE (. ILI-..f GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) - PROGRAM: exp - dev 2:S..- redrll GEOL AREA 1) 9 0 . Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~i; . ~ ~ ~iI<>\'I,,~ ct ~ I "O ~~ ~\ \: ~~ -> ~ .f. ~ c--..... N i> \t>'O<t c:... ~~ '" '\ èk !:j.\\"'I' N \~Cl.~ ~'\~Q, ~~~"f N . N ...~ ' N \)\ -\-\ ~\Q: ~~~ w:~"^O.~ .<: ~\O<o ~\ . N Y)Ä.. . Y QiJ ~: \~,.o\ \c.~~" <: ~to\-" ~~~ R.'\"~ ~~\ ~~ ~( s.tf'SC~ ~~ Y N Y Y/N N N serv well bore seg _ann. disposal para req - /! S CJ C) ON/OFF SHORE UNIT# c 0 Z 0 -4 ~ ::0 ( - a~~ -4 m - Z -f ::I: - CA » ::0 m » .( , Y N Y N ~o ~~~\o.~~~so.\. ~'ì \ \ ù,,>~ ~~ \t:J ~ \Cl"~ r Commentsllnstructions: ,,' ¡5/ 0)