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Home My WebLink About202-239 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc / g MfI'- ..( \J--.() r DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2022390 Well Name/No. PRUDHOE BAY UNIT 07-29B Operator BP EXPLORATION (ALASKA) INC y /=J,-Aù~> Sjlt-t¿,,lJ1 ~ 1Æ~ ~ API No. 50-029-21782-02-00 MD 12550"'-- TVD 8944- Completion Date 2/18/2003 Completion Status 1-01l Current Status P&A UIC N REQUIRED INFORMATION Mud log No Samples No Directional SUNe(~ ---~ DATA INFORMATION Types Electric or Other Logs Run: GR, MWD, CCl, Memory CNl Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from logs Portion of Master Well Data Maint) =- Log Log Run Scale Media No Interval OH / Start Stop CH -" Received Comments A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/9/2003. ~y>g- C I ! ue:~ C C IE[; C (ED C ""=-~. c/ ,.ED C Neutron Blu 10174 12533 Open 5/13/2003 An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 1/9/2003. Lis C1798 Gamma Ray Lis 1798 Gamma Ray 11725 Neutron I.-- I) 1201 0 D.iœGflomJrS'Ûrvey f~\ G ('2.... ~~ ~ 1)'\ k l S, 12010 Dire . ORatStJ'f'Véy FINAL 11133 12546 Case 6/16/2003 FINAL 11133 12546 Case 6/16/2003 10174 12533 Open 5/13/2003 25 11133 12337 Open GR Directional - MD, RWD = Recorded while - drilling. 25 11133 12337 Open GR Directional - TVD, RWD = Recorded while drilling. 25 11133 12337 Open 6/20/2003 GR Directional MD - RWD = Recorded while drilling. Blu FINAL 11133 12546 Case 6/20/2003 Blu FINAL 11133 12546 Case 6/20/2003 11889 12550 2/13/2004 11889 12550 2/13/2004 11889 12550 2/13/2004 ¡ Rpt C 12010 LIS Verification {Og r~~;: Gamma Ray . 'log Gamma Ray '~ 0 Asc Directional Survey VÉD D Pdf Directional Survey Rpt Directional Survey -- ----~ -------- DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2022390 Well Name/No. PRUDHOE BAY UNIT 07-29B MD 12550 _ te'D D Asc L/{vED D Pdt ~--- 1_.___ TVD 8944 Completion Date 2/18/2003 Directional Survey Directional Survey Directional Survey Well Cores/Samples Information: Name Interval Start Stop -~~ ADDITIONAL INFORMATION Well Cored? Y 1;) Chips Received? - Y J ~ ¿ Analysis Received? ~ Y / I-J - Comments: - ----~ ~ ---------- Compliance Reviewed By: -~ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21782-02-00 Completion Status 1-01L Current Status P&A UIC N 11130 12337 2/13/2004 PB1 11130 12337 2/13/2004 PB1 11130 12337 2/13/2004 PB1 Sample Set Sent Received Number Comments ....~./ Daily History Received? Û)N Q)N Formation Tops Date: CJ í ¡I~iL À...Ú<J;; --- .--- ') STATE OF ALASKA ALASKA ._.... AND GAS CONSERVATION COMrv: )ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 Zero Other 5. Date Comp., Susp., or Aband. 12/23/2003 I 6. Date Spudded fl . th 2t972003 /- 7. Date T.D. Reached 2/13/2003 8. KB Elevation (ft): KBE = 65' CASING, LINER AND CEMENTING RECORD ,CASING ", : ,,··..,:,i ", '.. i., .' .',. '." "..,:: '. ." .' ,il··.I" ;;~E;r[INq,:PE,~t~IMQ"i' :ßEfiINg")I;f'ìÅTVb~';I';,:8pÚ~ 1.1", "S, , Il.E,.',',',:" Ii" :"..~ W'·1">'PER Fr·"·" ,,",.. GRÄ:CE' ',,',: I,::; 1¡1:"O~I"".",:'B^T'''''O'M':''' Y·':'·I".II~n'''''.',.II'' ;,....,~...,·jII....M' ·,·'I':il'\SI~E:'II,I"'I. 1'1 I' .',,' ,1',,'1' , " , ',I, "":'11." '", I" ,I, "1"",1.1." ,~, ,.' I ' .~, ,i'L' "'I', ,',I,:,. ~~ " '," ,~,~.I,I'li,·,"", I 1.','''1',', ,Ii.,.¡ 'I,'" 20" 91.5# H-40 Surface 110' Surface 110' 30" 2568 # Poleset 13-3/8" 68# 172# K-55 I L-80 Surface 3767' Surface 3626' 17-1/2" 291 sx CS II, 3000 sx CS 11I,500 sx Class 'G' 9-518" 47# L-80 Surface 10591' Surface 8424' 12-1/4" 354 sx CS I, 700 sx Class 'G' 7" 29# L-80 10371' 11091' 8269' 8777' 8-1/2" 387 sx Class 'G' 3-3/16" 6.2# L-80 10363' 11129' 8263' 8802' 4-1/8" 123 sx Class 'G' 3-1/2" x 2-3/8" 8.81# 14.41# L-80 10305' 12546' 8221' 8944' 3" 61 sx Class 'G' 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 452' SNL, 327' WEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 75' NSL, 34' WEL, SEC. 21, T11N, R14E, UM Total Depth: 864' NSL, 714' EWL, SEC. 22, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675856 y- 5950465 Zone- ASP4 TPI: x- 676000 y- 5956277 Zone- ASP4 Total Depth: x- 676728 y- 5957083 Zone- ASP4 18. Directional Survey 0 Yes IBI No No. of Completions 21. Logs Run: CCL, GR, Memory CNL, MWD 22. MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested 9. Plug Back Depth (MD+ TVD) 12533 + 8944 10. Total Depth (MD+TVD) '12550 + 8944 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 202-239"/ 303-332 13. API Number / 50- 029-21782-02-00 14. Well Name and Number: PBU 07 -29B ,/ 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost ,/ 1900' (Approx.) -ï7í-Jl'~~J /!/¿4~~ ¡:', °Ó3' -rtf'þ (;,jt lJ4 "A'''','''' I¡'I! .'., 1y10,lJNI~' """'~~~L~è:o""" SIZE 4-1/2", 12.6#, L-80 TVD DEPTH SET (MD) 9820' - 10461' PACKER SET (MD) 10366' 45;.'" '1~8.~8,1~~ÇT~~~~q~MEN~ S99~~EF,ETC. " ,. i', DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9771' Set EZSV with Whipstock on top ./' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-Bsl PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ......... Oll-Bsl Press. 24-HoUR RATE""'" 27. GAs-McF W A TER-BSl 6' ,,~~ ..~ CHOKE SIZE GAS-Oil RATIO GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) CORE DATA Brief ~escriptio~ of ~ithology, por~~ity, f~actures, apparent dips and presence of oil, gas or water (att~ Ef(:,~M [;essary). Submit core chips; If none, state np~~::'·.",:::'""'~:~;',"': A~~'~ ~., ;;A:~:E"-' ! FEB 0 3 2004 None i ..g_:~~g] ~ ._...~-1b~:'--_:: 0 R \ G \ N A L "_,' . .c.,. ..',.",'.... ...., I."~" . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE Lf' Alaska Oil & Gas Cons. Commission Anchorage ~~BFl FEBO 2l\Di} 28. GEOLOGIC MARKERS ) 29. )RMA TION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Zone 1 B 11279' 8906' 8928' 8937' None Zone 1A 113N 11317' 13P 11337' RECEIVEr) FEB 0 3 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~ ~ PBU 07 -29B 202-239 303-332 Well Number Title Technical Assistant Date O~"'03 "OL( Permit No. I Approval No. INSTRUCTIONS Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 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 ORIGINAL ) ') Well: Field: API: Permit: 07 -29C Prudhoe Bay Unit 50-029-21782-03 203-192 Accept: Spud: Release: Rig: 12/21/03 12/25/03 01/05/04 Nabors 2ES THIS WORK OCCURRED AFTER COIL TUBING SIDETRACKED TO 07-298 AND PERF GUNS WERE LEFT DOWN HOLE 03/15/03 TAG WI 3.60" LIB AT 1015' SLM, TAP DOWN FALLING TO 1020' SLM, NO PICTURE ON LIB, HYDRATES ON TOOLS. 04/08/03 FLUID PACK IA WITH CRUDE. START WELL KILL WITH 2% KCL. CAUGHT FLUID AT 60 BBLS PUMPED (3947'). AT 97 BBLS PUMPED INJECTIVITY=.5 BPM @ 3300 PSI. UNABLE TO BULLHEAD KILL WELL. MU NOZZLE AND RIH TO 9900' CTM. CIRCULATE KILL WELL WITH 2% KCL, THEN LAY IN 10 BBLS FLOPRO FROM 9900'. POOH. WELL IS DEAD. FP FLOWLINE WITH 140 BBLS CRUDE. RIH WITH BAKER FISHING TOOLS WI 3" 'GH' SPEAR. TAGGED FISH AT 9958' CTMD. SEVERAL ATTEMPTS TO ENGAGE FISH WERE UNSUCCESSFUL. POOH. RECOVER PHENOLIC 3/4" BALL, GH TOOL SHEARED. REDRESS AND RIH WI SAME. LATCH FISH AT 9942' CTM. MAKE 1 UP AND 15 JAR LICKS DOWN (10-15K DOWN). ATTEMPT TO PUMP WITH WT DOWN AND PRESSURED UP. 04/09/03 CONTINUE JARRING DOWN ON FISH. MADE 23 LICKS (15-20K) DOWN. WENT TO ALTERNATING UID LICKS, AFTER THE FIRST DOWN JAR, PULLED FREE, WITH NO ADDITIONAL STRING WT. POOH TO INSPECT TOOLS. GH SHEARED. REDRESS AND RIH WI SAME. LATCH FISH AT 9945' CTM, ATTEMPT TO PUMP OFF BAKER GS BELOW 1200' OF 1" CS HYDRIL. POOH, NO FISH. RIH W/3" GS. LATCH AT 9935' CTM. PRESSURE UP CT WHILE PULLING LITE. POOH W/3K ADDITIONAL WEIGHT. NO FISH. REGROUP AND GATHER NEW TOOL STRING. 04/10/03 LATCH FISH AT 9942 (UP). JAR FOR 50 LICKS AT 32K OVER STRING WEIGHT. NO MOVEMENT SEEN. RELEASE FROM FISH AND POH. FREEZE PROTECT WELL TO 2000 WITH 60/40 MEOH AS POH. RDMO. 11/01/03 MADE DRIFT RUN WITH 3.50 LIB DOWN TO 9924' SLM. MADE SEVERAL BAILER RUNS WITH 3" PUMP BAILER, @ 9924' SLM. BLACK GEL LIKE SUBSTANCE. RUN 3.25" LIB. TO 9926' SLM. IMPRESSION OF 3-1/2" 'G' FISHNECK. RDMO. WELL LEFT SHUT IN. ,,_^_^,~,,_._~.~~~iB.^~~, ~o"e~ (),n .~7~29B, ~~.~ .C^<>'I1,t.i~':Ie,~, ~~t~l11P.t to_f!~h .~-:~!~~..,~~A,. ~~th()u~ ~~_c_~e~,~~ _ _, Accept: .. 11/06/03 Release: 11/11/03 Permit: 202-239 (SèErS~þaråte·Sul11mary) PRE-RIG WORK FOR NEW SIDETRACK (07-29C) 11/28/03 SET WIDDON CATCHER @ 9850./ PULL ST # 5 DUMMY VALVE @9367 MDI 9324 SLM./ PULL CATCHER. NOTIFY DSO OF WELL STATUS. 12/01/03 CHEMICAL CUTTER, STRING SHOT, TUBING PUNCH AND PLUG FOR PRE-RIG SIDETRACK. PLUG SET AT 9830'. TUBING PUNCH FROM 9770'-9772'. STRING SHOT FROM 9809'-9821'. CHEMICAL CUT AT 9820'. GOT STUCK WITH CUTTER AFTER SHOOTING, PRESSURED WELL TO 1000 PSI, CAME FREE, POOH. TAGGED FISH AT 9895' PRIOR TO SETTING PLUG. ANCHOR SUB HANGING ON WAY OOH, HAD TO PLAY WITH IT IN THE SSSV NIPPLE. ) ) BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task Code NPT Phase 2/5/2003 20:30 - 00:00 3.50 MOB N WAIT PRE 2/6/2003 00:00 - 06:00 6.00 MOB N WAIT PRE 06:00 - 00:00 18.00 MOB N WAIT PRE 2/7/2003 00:00 - 04:30 4.50 MOB P PRE 04:30 - 07:00 2.50 MOB P PRE 07:00 - 12:45 5.75 MOB P PRE 12:45 - 13:05 0.33 MOB P PRE 13:05 -15:15 2.17 MOB P PRE 15:15 - 18:00 2.75 MOB P PRE 18:00 - 18:30 0.50 MOB P PRE 18:30 - 21 :00 2.50 BOPSURP PRE 21 :00 - 00:00 3.00 BOPSUR P PRE 2/8/2003 00:00 - 02:00 2.00 BOPSURP PRE 02:00 - 04:00 2.00 KILL P DECaMP 04:00 - 04:45 0.75 KILL P DECaMP 04:45 - 06:00 1.25 STWHIP P WEXIT 06:00 - 09:00 3.00 STWHIP P WEXIT 09:00 - 10:30 1.50 STWHIP P WEXIT 10:30 - 12:00 1.50 STWHIP P WEXIT 12:00 - 13:46 1.77 STWHIPP WEXIT 13:46 - 15:50 2.07 STWHIP P WEXIT Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 Description of Operations Phase 2 Weather, drifting and blowing snow after six inches of new snow previous day, -50WC, Winds 30-50MPH. Wait on Weather prior to moving off 15-30. Phase 2, blowing and drifting snow. Ensure all transport to and from rig follows Phase 2 procedure (convoy, radio comms., notify supervisor, re-evaluate importance of travel & cancel if possible, plan for phase 3, arctic gear required) Continue waiting on weather for rig move. Replace bladders on Koomey. Troubleshoot frozen water line on rig. WOW down graded from phase 3 to phase 2 at 00:30 hours. Drill site maintenance to send blower to start clearing pads and roads. Move rig off well. Haul two truck loads to DS 7. Pull rig to edge of DS-15. Function test moving system on edge of pad. Not all wheels are in sync, some sort of electro-hydraulic control system problem, plan to change out one of the rear drive motors this AM. Still waiting on snow removal on DS-7. The drifts on DS-7 are very bad do to lots of equipment parked on the edge of the pad. DS 7 is ready for the rig. Still working on rear drive motor. PJSM on derrick up rig move from DS-15 to DS-7 with security and rig crew. Discuss escort procedure, ensuring radio contact, review route. Jack up rig, start rolling. Security & Toolpusher in lead, Schlumberger TL following. Perfect weather for a move, nice and sunny, no wind. Beautiful Prudhoe by the bay. Nordic 2 at DS-7. Maneuver onto backside of pad and position rig, tight S-turn. Stop over well. Crew change PJSM. NU BOP. Test BOP. Continue to test BOP. BOP test witnessed by Jeff Jones AOGCC. Test went well had two gas detectors one in cellar and one on rig floor which needed to be recalibrated. He didn't wait on the electrician to recalibrate them but asked to be called back to witness a retest. Fill pits with 2% Bio. Monitor well. Well head 620 psi. Bleed off thru choke. No fluid returns. Fill well with 33 bbl. Shut in well build back to 37 psi in 20 minutes. Bleed off well flowing. MU Nozzle. Sting on to well. Bleed off pressure. Slight trickle. LD nozzle. Test MHA. PU Milling BHA. Stab onto well. RIH with wnidow milling assembly. IA=590, OA=375. Gas alarm. Shut in well, line up to take gas returns out to tiger tank. Cont RIH, circulating in new KCL with 2ppb Bio. 11150.9 tag pinch point, correct depth to top of whipstock. PU, ease into milling. RIJ:i wt= 13300Lbs, Freespin= 1490psi. Start milling at 11129.4: 1520psi / 1.6bpm Out MM not functioning. Milling 11,130.4 1725psi / 1.6bpm. Annulus pressures rising from wellbore heating, bleed IA and OA, IA=380psi, OA=239psi Milling 11,131.4 1800psi / 1.6/1.6 bpm Milling 11,132.4 1860psi / 1.6/1.6bpm PVT=288 Printed: 11/12/2003 11 :03: 17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 2/8/2003 15:50 -16:15 16:15 - 16:40 16:40 - 16:55 16:55 - 17:10 17:10 -18:00 18:00 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 2/9/2003 00:00 - 01 :30 01 :30 - 02:00 02:00 - 02:40 02:40 - 03:40 03:40 - 04:40 04:40 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 -10:15 10:15 - 12:26 12:26 - 13:00 13:00 - 14:00 0.42 STWHIP 0.42 STWHIP P 0.25 STWHIP P 0.25 STWHIP P 0.83 STWHIP P 3.00 STWHIP P 0.50 STWHIP P 2.50 STWHIP P 1.50 STWHIP P 0.50 STWHIP P 0.67 DRILL P 1.00 DRILL P 1.00 DRILL P 3.33 DRILL P 0.50 DRILL P 0.50 DRILL P 0.50 DRILL N 0.75 DRILL N 2.18 DRILL P 0.57 DRILL P 1.00 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Milling 11,133.5 See ROP increase. BOW? Milling 11,133.7 1835psi/1.6/1.6bpm. Sand in samples. Drilling break, call this bottom of window. TOW=11129.4, BOW=11 ,133.7 Unable to get clean vacs for swapping mud prior to POOH (9 trucks on S pad, 4 trucks on cement job). Plan to swap to FloPro with drilling bha on bottom. 11136.5, 1765psi 1.6/1.6 ROP=0.2fpm in OH. Let off break, mill formatiion to 11144.6 (10' past bottom of window) at 60fph. Still getting 1: 1 PU to backream, clean pickup, pick up wt = 30K Lbs. circ press off bottom=1760psi 1.6/1.6bpm See motor work at 11133.4, park, allow mill to work. PU thru window at .6fpm, 1780psi 1.6bpm. See small amts. of motor work at 11132.8, 11131.1,11129.4 Run back down thru window to 11139'. 1725psi, 1.6bpm, 0.9fpm, very little motor work. PU, backream up thru window at 0.5fpm, 1770psi, 1.6bpm. Run back down thru window. PU thru window backreaming a third time. Dry pass O.K. POH. Mills in gauge. Freeze protect coil with methanol. Cut coil connector, Install grapple in end of coil. Unable to get full engaugement of grapple. Pull tested to 2000#. Pull end of coil back to reel and secure. Continue to secure. Cut off grapple prep end of coil and cap coil. Lower the reel to trailer. Operation went well. Raise E line coil into reel house. Remove plug and grapple connector. Install grapple and tugger line. Need to look into grapple appears the grapple was for thinner wall pipe unable to get full engaugment. Pull coil over the pipe shed thru injector in ( 5 minutes) worked great. Cut off grapple. Megger cable. O.K. Install kendle eline coil connector. Pull test. Rehead. Reheading taking a bit longer than expected. Displace methanol from eline CT. IA=5, OA=35 PU Baker Inteq Eline BHA, 2.5deg Baker X-treme motor, Used Hycalog 2.67" x 3" bicenter(from Lisburne). BIT to GR= 26.74', to Survey=27.59', to CCL= 44.86', to NB INC. =12.84' Stab onto well, test eline tools, failed test. DFAL PROD1 Unstab, troubleshoot tools. Restab. SFAL PROD1 Electronic counter on injector not working, troubleshoot. Trouble swapping Anadrill's encoder with BHl's encoder. PROD1 RIH with BHA #2, open circ sub. Start sending Used Flo-Pro down while RIH, pump 35bbls, shut down pumps. Cont. RIH. CT Vol with eline=40.75bbl PROD1 Tie in. Start logging down at 1101 O'md at 3.2fpm. Still not pumping. Correct depth, subtract 29' to correct to Geology PDC. Yesterday we subtracted 20' to the pinch point on the whipstock. PROD1 Close Circ sub. Continue RIH pumps off. RIH wt=13500 Ibs above window. Bobble, briefly get back wt at 11130'md probably top of window, Tag TO at 11, 144'md. PU off bottom, Printed: 11/12/2003 11 :03: 17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 2/9/2003 13:00 - 14:00 1.00 DRILL P PROD1 start pumping. Freespin=2720psi at 1.55bpm. IA=100, OA=80psi (Weather upgraded to Phase 2, drifting again on the pad) Start drilling, 3100psi 1.6/1.6bpm ROP=25fph, WOB= 6501bs, Annular pressure=4300psi 14:00 - 14:25 0.42 DRILL N DFAL PROD1 Troubleshoot orientor, unable to hold TF. Likely in a bind across whipstock and 2.7" hole. 14:25 -15:15 0.83 DRILL P PROD1 Drilling, 11165'md. 3700psi, 1.7/1.7 30-40fph WOB=2300Ibs. [Traction motor on Mud pump unable to maintain constant rate when motor work increaes, acts like it is bogging down. Watch the rate drop 0.3-0.4 bpm on its own. Makes it tough to decipher what is going on and how much motor work we are getting. Ideally we would like to see constant rate from our mud pumps. (This same problem also made our window milling parameters less obvious yesterday.) Schlumberger/Nordic looking for a fix. This phenomena is more noticeable with 2" CT] Stall at 11170', PU. Resume drilling. 15:15 - 15:35 0.33 DRILL N DFAL PROD1 Pull up above whipstock to see if we can get orientor to respond inside 3-3/16". No good. 15:35 - 15:50 0.25 DRILL N SFAL PROD1 Trouble shoot mud pump controls with electician. 15:50 - 16:15 0.42 DRILL N DFAL PROD1 RBIH to one last time to see if we can get Orientor to respond. Orientor is completely out the window. 16:15 -18:00 1.75 DRILL N DFAL PROD1 POH for non-responsive orientor. EOP FLAG @ 10250'. Trouble shoot pumps as we poh. Try one more time at getting orientor to respond inside 4-1/2" liner, no good. Continue POH. 18:00 - 19:33 1.55 DRILL N DFAL PROD1 LD BHA and trouble shoot Orienter. Checked out OK at surface. Will send to shop where they can check torque output of orienter. 19:33 - 20:15 0.70 DRILL N DFAL PROD1 MU BHA #3 build assembly. New orienter and bit. Stab onto well 20: 15 - 22:20 2.08 DRILL N DFAL PROD1 RIH to flag. Correction -26'. Log to RA no additional correction. 21 :30 - 00:00 2.50 DRILL P PROD1 Directionally drill 1.62/1.68 @ 3450 psi. 3300 psi FS. DH annular pressure 4571 psi DH tubing pressure 5094 psi @ 8,786 TVD. drill to 11,208'. 2/10/2003 00:00 - 05:00 5.00 DRILL P PROD1 Directionally drill 1.66/1.66 bpm @ 3500 psi. FS 3300 psi. DH annular 4562 psi, DH tubing 5008 psi. 2K WOB, ROP 18. drill to 11245'. Drilling break ROP increased 40-60 ftlhr. Drill to 11,300'. 05:00 - 06:30 1.50 DRILL P PROD1 Directionally drill 1.64 /1.64 bpm at 3,500 psi 3,300 psi FS, DH annular 4,602 psi, DH tubing 5,234 psi. at 8,850' tvd, WOB 1 ,700#, ROP 46. 06:30 - 07:00 0.50 DRILL P PROD1 Tech limits/Safety meeting. Discuss plan forward, lessons learned, HSE issues. 07:00 - 09:00 2.00 DRILL P PROD1 Drilling 1.7/1.7bpm, 3420psi, 25-30fph, 2140lbs WOB, DH Annular=4610psi, ECD=10ppg. Drill build to 11392'md. ROP increasing at 11396'md. [IA=433, OA=122psi] Weather graded PHZ 3 on pad, PHZ 2 on main roads, discuss operational risks w/ drilling team, plan to keep pad access open with rig loader to manage risk. 09:00 - 11 :00 2.00 DRILL P PROD1 Drilling 1.7/1.7bpm, 3450psi, 50-60fph, 11 ,466'md. Wt transfer falling off. 11 :00 - 11: 15 0.25 DRILL P PROD1 100' short trip to improve wt. transfer. Printed: 11/12/2003 11:03:17 AM Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 2/10/2003 11 : 15 - 11: 30 0.25 DRILL P PROD1 Drilling, Land build at 11470'md, 90deg inc. 11:30 -13:00 1.50 DRILL P PROD1 POH to window at 1.7bpm, 20fpm conditioning hole. Hole in good condition. Open circ sub inside 3-3/16" liner. Continue POH to surface. 13:00 - 15:00 2.00 DRILL N WAIT PROD1 Wait for roads and pads and Nordic 2 loader to clear a path to the oxbow road prior to resuming operations. 15:00 - 15:15 0.25 DRILL P PROD1 Continue POH 15:15-15:30 0.25 DRILL P PROD1 PJSM prior to laying down tools. Discuss job roles and good communication. 15:30 - 16:15 0.75 DRILL P PROD1 Unstab, inspect build assembly. Adjust motor to 1.1 deg, PU new Hycalog DS100. 16:15 - 17:30 1.25 DRILL N DFAL PROD1 Find short in Eline BHA on surface test. Troubleshoot. Short in lower quick connect. Change out lower quick connect and flow sub on upper quick connect. 17:30 - 19:30 2.00 DRILL P PROD1 RIH with BHA #4 lateral assembly. 1.1 deg X-treme motor, new Hycalog DS 100 3" bicenter. 19:30 - 20:40 1.17 DRILL P PROD1 Tie-in to RA tag correction (+14'. Tag deep 40' had a Gamma ray spike that fooled us. Retied in -38') net -24'. 20:40 - 20:50 0.17 DRILL P PROD1 RIH tag 11,472'. 20:50 - 23:30 2.67 DRILL P PROD1 Directionally drill 1.7 / 1.7 bpm @3600 psi FS = 3300 psi Up 28,000# Dn 12,000# WOB 3K, ROP 27, HD annular pressure 4,632 psi DH tubing pressure 5,078 psi at 8891' TVD. Stacking mud .7 % solids. call for new mud. Drill to 11,620'. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip to window. No problems 2/11/2003 00:00 - 02:00 2.00 DRILL P PROD1 Directionally drill 1.65 / 1.68 bpm @ 3,666 psi 3,300 psi FS. Up 28,000# Dn 12,000# WOB 3K, ROP 40-60, DH annular pressure 4,672 psi DH tubing pressure 5,792 psi at 8891' TVD. Wiper tripped improved sliding greatly. drilled to 11,770'. Mud Swap. 02:00 - 02:30 0.50 DRILL P PROD1 Wiper to window. No problems smooth trip. 02:30 - 05:00 2.50 DRILL P PROD1 Continue to directionally drill 1.71 /1.71 bpm at 3,450 psi. FS 3,300 psi. Up 28,000# , DN 12,000#, WOB 4, ROP 60-80,DH annular pressure 4,600 psi, DH tubing pressure 5,279 psi. New mud improved weight transfer. Drill to 11,920' 05:00 - 05:40 0.67 DRILL P PROD1 Wiper to window. 05:40 - 06:30 0.83 DRILL P PROD1 Continue to directionally drill 1.71 /1.71 bpm at 3,450 psi. FS 3,300 psi. Up 28,000# , DN 12,000#, WOB 3-4, ROP 60-80. 06:30 - 08:45 2.25 DRILL P PROD1 Drilling, drop inclination to follow down dip as per geo. 1.7/1.7 bpm 3,400psi, Inc=89deg. FREESPIN= 3,250psi, DH tubing = 4,920, DH Annular = 4,615....305psi pressure drop across orientor, motor and bit, with new FloPro. Drill to 12,038' md. Start stacking wt. 08:45 - 09:05 0.33 DRILL P PROD1 Short trip, wiper to 11,947'. 09:05 - 10:05 1.00 DRILL P PROD1 Drilling, 3,450 - 3,500psi 1.7/1.7bpm. Drill to 12,083' md. 10:05-11:15 1.17 DRILL P PROD1 Wiper to window. 11 :15 - 12:00 0.75 DRILL P PROD1 Drilling, plan to stay horizontal and when we see GR coming up, start climbing with predicted dip. Drill to 12,127' md. 12:00 - 13:30 1.50 DRILL P PROD1 Drilling 1.7 / 1.7 bpm 3,500 psi, FS 3,200 psi. DH inner annulus pressure 4,595 psi, DH tubing pressure 5,340 psi UP 29,000# DN 13,000# WOB 2, ROP 45-60. 13:30 - 14:30 1.00 DRILL P PROD1 Wiper to window. 14:30 - 17:00 2.50 DRILL P PROD1 Drilling 1.6 / 1.6 bpm 3,650 psi, FS 3,200 psi. DH inner annulus Printed: 11/12/2003 11:03:17 AM ) EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 2111/2003 14:30 - 17:00 2.50 DRILL P PROD1 pressure 4,595 psi, DH tubing pressure 5,420 psi UP 29,000# DN 13,000# WOB 3-4, ROP 40-80. 17:00 - 18:45 1.75 DRILL C PROD1 Wait on decision from town regarding side track for geologic reasons. 18:45 - 20:45 2.00 DRILL C PROD1 POH for open hole side track geological sidetrack. 20:45 - 22:00 1.25 STKOH C PROD1 LD drilling BHA and PU open hole whipstock. 22:00 - 00:00 2.00 STKOH C PROD1 RIH to tie-in. 2/12/2003 00:00 - 00:30 0.50 STKOH C PROD1 RIH to 11,140' tie -in 00:30 - 00:50 0.33 STKOH C PROD1 Tie in (-28' correction) 00:50 - 01:10 0.33 STKOH C PROD1 RIH to 11,934. UP wt 30,000# SO 10,000#. Top of whipstock at 11,920'. Close EDC. Pressure to 5000 psi at .18 bpm. See no shears. PU to Set wt of 30,000. Slacked off to 2000#. Took weight. 01:10 - 03:00 1.83 STKOH C PROD1 POH. 03:00 - 04:00 1.00 STKOH C PROD1 LD whipstock running tool and PU drilling BHA#4. 04:00 - 05:45 1.75 STKOH C PROD1 RIH to tie in depth. No problem getting thru window with 2.76" bit. 05:45 - 07:45 2.00 STKOH X SFAL PROD1 Surface software troubles. Rebuild system. 07:45 - 08: 15 0.50 STKOH C PROD1 Log tie-in at RA. Correct depth (-25'). 08: 15 - 08:45 0.50 STKOH C PROD1 RIH and tag AI billet at 11,922' corrected. 08:45 - 10:15 1.50 STKOH C PROD1 Time mill first 1.5' (grabby getting started). Not getting TF updates. Confirm electronic failure in orienter. 10: 15 - 11 :45 1.50 STKOH C PROD1 Orienter started working again. Time mill to 11930'. 11:45 - 14:20 2.58 DRILL C PROD1 Drill ahead to revised 8,879 TVD target -- got there at 12,082' but not in sand here. 14:20 - 16:00 1.67 DRILL C PROD1 Wiper trip while WOO. 16:00 - 16:45 0.75 DRILL C PROD1 Drill 1.6/1.6 bpm at 3,350 psi FS = 3,300 psi Up wt 29,000#, DN wt 12,000#, WOB 2K, ROP 40-70. DH annulus pressure 4,590 psi. DH tubing pressure 5,300 psi. 16:45 - 19:00 2.25 DRILL C PROD1 Wiper to window. 12,180'. 19:00 - 21 :40 2.67 DRILL C PROD1 Drill 1.6/1.6 bpm at 3,350 psi FS = 3,300 psi Up wt 29,000#, DN wt 12,000#, WOB 2K, ROP 40-70. DH annulus pressure 4,611 psi. DH tubing pressure 4,955 ps. Drill to 12,250 Having trouble with weight transfer. Mud only .2% solids will bring lubtex from 3% to 4%. 21:40 - 22:40 1.00 DRILL C PROD1 Wiper to Window. 22:40 - 00:00 1.33 DRILL C PROD1 Attempting to drill Stacking. Drill 1.7/1.7 bpm at 3,380 psi FS = 3,100 psi Up wt 30,000#, DN wt 12,000#, WOB 1-2K, ROP 15-40. DH annulus pressure 4,630 psi. DH tubing pressure 5,400 psi. 2/13/2003 00:00 - 01 :00 1.00 DRILL C PROD1 Drill 1.7/1.7 bpm at 3,350 psi FS = 3,300 psi Up wt 30,000#, DN wt 12,000#, WOB 2-4K, ROP50-100. DH annulus pressure 4,630 psi. DH tubing pressure 5,400 psi. Drill to 12,344' stacked out. 01 :00 - 02:00 1.00 DRILL P PROD1 Wiper to window. Set down at 12,260' went thru on second attempt. Tag at 12,346'. 02:00 - 07:00 5.00 DRILL P PROD1 Stacking out. Work pipe. Drilling at 1.6 1 1.6 bpm at 3640 psi. UP Wt 30,000# DN WT 12,000#. WOB 2-3. ROP 50 -100. Stacking continues to be an issue but once we get drilling progress is good. Drill to 12536'. 07:00 - 08:00 1.00 DRILL P PROD1 Wiper to window. Hole in good shape on this up pass. 08:00 - 08:20 0.33 DRILL P PROD1 Log tie-in at RA. No correction. 08:20 - 09:15 0.92 DRILL P PROD1 RIH at 90R TF (drilled at 90L). Hole smooth up to 12230', then Printed: 11/12/2003 11:03:17 AM BP EXPLORATION Operations Summary Report Page 6 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 2/13/2003 08:20 - 09: 15 0.92 DRILL P PROD1 ratty weight and increase in CTP by about 25 psi. Hard set downs 12230', 12250', 12300' without any change in CTP. Swap TF to 90L and continue RIH with ratty weight. Sat down 12370', again with no bit work. RIH to TD. Tag 12532'. 09:15 - 10:15 1.00 DRILL P PROD1 RIH weight at TD = 10k. Try and get started -- stack, stack, stall. Very poor slide on bottom, then lose ground. Very high friction. Backream a couple times the length of the BHA. Drill to 12545'. Then lost ground again, losing BHA movement off bottom. Requires a higher running speed to get to bottom. 1 0: 15 - 11: 15 1.00 DRILL P PROD1 Wiper while mixing a 5% Flo-Lube pill (2 drums in 50 bbls mud -- which is currently at 4% lubetex). 11:15-12:00 0.75 DRILL P PROD1 Try drilling with pill on the backside -- no progress. Corrected TD 12546'. 12:00 - 14:30 2.50 DRILL P PROD1 Ream 12200' - 12350' at several different TF's. While there was little to no motor work, the area did clean-up (RIH wts lessy ratty and no set downs). Lay in new 25 bbl Flo-Pro pill on bottom (3% lubetex; 5% flo-Iube; otherewise same properties). 14:30 - 19:00 4.50 DRILL P PROD1 POOH at 2.0 BPM, circ sub open. Change over top well to KCL. Freeze protect coil. LD BHA. 19:00 - 20:00 1.00 CASE P COMP Cut off connector. The 1.75 grapple wouldn't stab replaced it with split grapple and install grapple in end of coil. O.K. 20:00 - 20:30 0.50 CASE P COMP PJSM pulling coil back. 20:30 - 21 :30 1.00 CASE P COMP Pull coil back and secure on reel. Release grapple. Plug coil. Set back injector. 21:30-22:10 0.67 CASE P COMP Rig up floor to run liner ( beginning of simultaneous operation with coil swap) 22: 10 - 22:30 0.33 CASE P COMP PJSM for running liner. 22:30 - 23:20 0.83 CASE P COMP PU liner drifting each connection. Taking initially 3.5 min per connection. 23:20 - 23:30 0.17 CASE P COMP PJSM with PEAK for coil swap out. 23:30 - 00:00 0.50 CASE P COMP Continue simultaneous operations. Liner running and coil Swap. Simultaneous operations terminated at midnight. Coil swap completed incident and accident free. 43 of 69 joints of 2-3/8 STL liner picked up by 23:59. 2/14/2003 00:00 - 03:00 3.00 CASE P COMP Continue to run liner. 03:00 - 03: 15 0.25 CASE P COMP PJSM pull coil to injector. 03:15-04:00 0.75 CASE P COMP Pull test grapple. Remove coil restraint. Pull coil to injector and stab into injector. 04:00 - 06:00 2.00 CASE P COMP Make up coil connector and pull & pressure test. Circulate out freeze protection from coil, pumping dart to check MM. Bump at 40.2 bbls (vs 41.4 theoretical). MU coil to CTLRT. 06:00 - 10:00 4.00 CASE P COMP RIH with liner. Wt check at 10250' -- 28k and 13k. 0.5; 1640 psi. RIH. Smooth until about 11800', then weight started getting ratty. From 11975' to TD slow going, making progress in 0' - 20' steps before reaching max negative weight and requiring PU. Unable to work past 12558' uncorrected. Can't work past this depth -- probably bottom. 32k up. Check circulation: 0.45/0.45 and 1850 psi. 10:00 - 10:30 0.50 CASE P COMP Stack to -10k. Drop 5/8" ball and pump to seat at 1.7/1.7; 4000 psi. Ball on seat at 32 bbls. Shear at 3700 psi. Pump at 0.5/0.5 BPM, 1870 psi. PU to make sure we are free. 21 k. Off liner. 10:30 - 12:30 2.00 CEMT P COMP Displace well to 2% KCL. Safety meeting with cementers. Printed: 11/12/2003 11:03:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 FrOm - To HoUrs Task CÒdé NPT Phäse 2/14/2003 2.00 CEMT P 10:30 - 12:30 COMP 12:30 -14:15 1.75 CEMT P COMP 14:15 - 16:15 2.00 CEMT P COMP 16:15 -16:30 0.25 CEMT P COMP 16:30 -17:00 0.50 CLEAN P COMP 17:00 - 18:30 1.50 CLEAN P COMP 18:30 - 20:45 2.25 CLEAN P COMP 20:45 - 00:00 3.25 CLEAN P COMP 2/15/2003 00:00 - 00:15 0.25 CLEAN P COMP 00:15 - 02:30 2.25 CLEAN P COMP 02:30 - 03:00 0.50 EVAL P COMP 03:00 - 03:30 0.50 EVAL P COMP 03:30 - 03:45 0.25 EVAL P COMP 03:45 - 05:00 1.25 EVAL P COMP 05:00 - 06:45 1.75 EVAL P COMP 06:45 - 08:00 1.25 EVAL P COMP 08:00 - 09: 15 1.25 EVAL P COMP 09:15 - 09:30 0.25 CEMT P COMP 09:30 - 10:15 0.75 EVAL P COMP 10:15 - 12:00 1.75 EVAL P COMP 12:00-12:15 0.25 EVAL P COMP 12:15 - 12:45 0.50 EVAL P COMP 12:45 - 17:30 4.75 BOPSURP COMP 17:30 - 18:30 1.00 PERF P COMP 18:30 - 19:00 0.50 PERF P COMP 19:00 - 21 :20 2.33 PERF P COMP 21 :20 - 22:15 0.92 PERF P COMP 22: 15 - 22:30 0.25 PERF P COMP Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 DescriptiOrf öfOþeratiÓns Seeing some losses: 1.7/1.4; 3950 psi CTP final circ conditions. Lower rate to check losses -- 1.12/.86; 1860 psi. Mix cement. At weight -- 12:45. PT lines to 4000 psi with KCL water. Load 12.5 bbls of 15.8 ppg Class G cement into the coil. Load and launch coil dart, verify it's gone. Chase cement with 30 bbls of 1.5 ppb biowater using rig pump. Displace cement at 1.8/1.4 initial, 1.7/1.5 when cement turned the corner. Reduce rate to 1.0/0.9 BPM about 2 bbls before latch-up. Latch up at 40.0 bbls, shear LWPat 4000 psi. Chase LWP to latch collar at 0.8/0.7 and 4000 psi initial, but losses increased gradually to 0.82/0.25 and 4000 psi final. Bump plug at 48.5 bbls right on the money. Pressure to 4400 psi. Bleed to check floats. LOST 3.2 BBLS CEMENT TO FORMATION DURING JOB. Pressure CT to 500 psi. Unsting. POOH, laying in remainder of the bio water at < 0.5 BPM. POOH, maintaining a trickle of returns. LD liner running tool. Safety meeting. MU 36 stands + one single of 1" CSH on motor/mill. RIH to 12,562'. No motor work smooth sailing all the way. POH circulating at 1.1 bpm 55 fph until returns cleanup. Return density as high as 8.9 ppg . POH. Continue to POH, diverting contaminated cement to cuttings tank. Drop ball open circulation sub. Stand back 1" CSH. LD BHA. Clear floor. PU logging tools. PJSM for installing radioactive source. RIH with 1" CSH. Stab injector and RIH. Log down at 60 FPM starting at 10200'. Sat down twice at top of liner 10343'. Work thru. Log down to PBTD at 12552' uncorrected depth. Log out of hole at 60 FPM, laying in 15 bbls of new high vis Flo-Pro mud in liner. POOH to 7000'. Cement check: lab sample at 2500 psi. Pressure test hole to 2100 psi. Cement check: lab sample at 2500 psi. Pressure test hole to 2100 psi. lAP = 300; OAP = 100. Good flatline test -- bled 20 psi in 15 minutes. POOH. Standback 19 stands CSH; LD remaining 35 joints in singles. Safety meeting. LD logging tools, clear floor. Download data -- some CNL data missing/noisy. GRlCCL log looks good. Fax to Stephan. CORRECTED LINER TOP = 10304'. CORRECTED PBTD = 12535' . Pressure test BOPE. Witness waived by AOGCC's John Spaulding. RU floor to run perforating guns. Tech Limits and PJSM for picking up perforating guns. PU perforating guns. PU 19 stands of 1" CSH. Stab injector on to well and test reel valve. Printed: 1111212003 11 :03: 17 AM Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 Date From"OTo Hours Task 2/15/2003 2/16/2003 22:30 - 00:00 00:00 - 00:30 00:30 - 00:50 1.50 PERF P 0.50 PERF P 0.33 PERF P COMP COMP COMP 00:50 - 03:00 2.17 PERF N STUC COMP 03:00 - 04:30 1.50 PERF N STUC COMP 04:30 - 05:00 0.50 PERF N STUC COMP 05:00 - 05:30 0.50 PERF N STUC COMP 05:30 - 07:30 2.00 PERF N STUC COMP 07:30 - 08:30 1.00 PERF N STUC COMP 08:30 - 09:45 1.25 PERF N STUC COMP 09:45 - 11 :45 2.00 PERF N STUC COMP 11:45 - 12:30 0.75 PERF N STUC COMP 12:30 - 14:00 1.50 PERF N SFAL COMP 14:00 - 14:30 0.50 PERF N STUC COMP 14:30 - 15:00 0.50 PERF N SFAL COMP 15:00 - 17:00 2.00 PERF N STUC COMP 17:00 - 19:00 2.00 PERF N STUC COMP 19:00 - 20:30 1.50 PERF N STUC COMP 20:30 - 21 :00 0.50 PERF N STUC COMP 21 :00 - 22:30 1.50 PERF N STUC COMP 22:30 - 00:00 1.50 PERF N STUC COMP 2/17/2003 00:00 - 00:30 0.50 PERF N STUC COMP 00:30 - 02:00 1.50 PERF N STUC COMP RIH. Tag at 12,535 (corrected) PU 15' and drop .5" ball. UP wt 30K DN wt 13 K. Circulate ball to firing head at 1.8 bpm. Slow pump to .9 bpm. @ 1,060 psi. Pressure to 3000 psi. Guns appeared to fire. Stuck! Pull to max 30K over with and without circulation. Slack off to -9K NO GO. Hold 30K over wait 10 min -- NO GO. Discuss options with town. Discuss fishing options with BOT. Smallest jars on slope are 2-1/8" O.D. Mix 6% Lubtex pill in 30 bbl pill and circulate to annulus. Pull 60K (30 over) and hold. No go. Shut in backside and pressure to 1000 psi. Shut down bleed off to formation slow. Thick Flo Pro perf pill probably the cause for slow bleed off. SO to zero weight. Bleed off pressure fast. No Go. Contact Anchorage discuss options. Will disconnect above preforating guns and lay in lub pill prior to POH for fishing assy. Drop 5/8" ball to disconnect. Chase ball with lub pill to lay in above fish. Disconnect from perf gun fish. POH. Stand back CSH. LD top half of CSH. MU hyd spear and 18 stands CSH. Check/tighten all middle tool joints. MU 2-1/4" jars, two weight bars, accelerators, MHA. RIH. SD pumps in liner to keep slick pill in place. 28k up; 16k down. Latch fish at 11,400'. Jar pipe up for 18 hits setting max of 48k for jar licks (limit on jars) -- kind-of weak hits, and jars going off early most of the time at about 42k. No movement. Line up on backside to bullhead the slick lube pill down around guns and to perfs (we hope there are some perfs). Unable to pump down kill line -- frozen. PU above pill. Bullhead 4 bbls pill into perfs via coil: breakdown at 2050 psi, then inject at stable 0.57 BPM; 1600 psi for 3.5 bbls; then pressure climbed back to 2000 psi as we were finishing up the 4.0 bbls. SD and bleed. RIH. Latch FN at 11390' (took a few tags to latch). Jar 5 more times and something shucked loose. No weight change. Try to latch up about 6 more times. Couldn't. Want to POOH filling so we don't lose any clues what might be hanging on. Thaw kill line. POOH filling through kill line. Unstab inj. LD jars. Standback CSH. Lower disconnect sheared. Wait on fishing tools, Cut coil, PJSM change out BHA. Run 18 stands of 1" CSH. Check middle connections on all stands. Stab on to well with injector. Pump 30 bbl pill into coil while running in hole. Continue to RIH with out pump to top of fish. (Pill = 30bbl + 2drums lubtex + 2 buckets Flo-vis) Continue to RIH to top of fish. Tag at 11,406' Up wt 30K, Dn Wt 9K. Spot 20 bbl of pill in annulus. Tag latch onto fish 11,406 DN . Shut-in backside bullhead .5 bpm pressure ramped up to 2600 psi and broke back to 2000 psi jar Printed: 11/12/2003 11 :03: 17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 FrOm-TO Hours Task CodeNPT Phase 2/17/2003 00:30 - 02:00 1.50 PERF N STUC CaMP 02:00 - 04:00 04:00 - 04: 15 04: 15 - 06:00 06:00 - 07:00 2.00 PERF N 0.25 PERF N 1.75 PERF N 1.00 PERF N STUC CaMP STUC CaMP STUC CaMP STUC CaMP 07:00 - 08:00 1.00 PERF N STUC CaMP 08:00 - 09:00 STUC CaMP 1.00 PERF N 09:00 - 13:30 4.50 PERF N STUC CaMP 13:30 - 15:30 15:30 - 18:00 STUC CaMP STUC CaMP 2.00 PERF N 2.50 PERF N 18:00 - 21 :00 STUC CaMP 3.00 PERF N Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 Description Of Operations down -6K. Jar 6 licks No results. Jar up while continue to bull head. Not seeing alot of jar action. Jars firing fast. After bullheading 20 bbl. Bleed off wellhead pressure (1200 psi) fast while continuing jarring. NO GO. Up jarring progressed from 20K over incrementally increasing to 30K over. Fishing neck of disconnect is limiting factor on overpull to 30K over. NO sign of any movement. Total of 23 lick up 9 down. Will save some coil life for jarring with N2. Wait on N2. Holding 28K over. PJSM addressing RU issues for N2 job. RU hardlines to N2 unit. PJSM pumping N2, Reviewed Muster Areas, PT, Flow back tank RU, Compressed gases hazards, N2 gas leaking response. This job has NO time critical issues. We can shut it down any time. Bullhead 30,000 SCF N2 down kill line at 1000 SCF/min. 1850 psi WHP initial; 2100 psi WHP final. Tank shows 422 gallons pumped, which doesn't jive with the 30,000 number. Also, SICTP = 1300 psi; SIWHP = 1950. The difference between these numbers also doesn't jive with the 422 SCF or 30,000 SCF. Bleed WHP to flowback tank while jarring down -- didn't get any jar hits, at some point we must have released from fish. WHP bled down quickly and smoothly to 100 psi-- hatch covers on flowback tank did a little fluttering, otherwise noneventful. Latch back up with fish. Regroup, crunch numbers, and revise plan. Keep bind on fish for all circulating. Bullhead N2 down kill line again in stages, checking SICTP and SIWHP at each step to determine BS fluid level. Bullhead 150,000 SCF (1100 gallons) down kill line. 1800 psi SI differential. SICTP and SIWHP suggests fluid level about 4300'. Bleed WHP to zero (and bleed CTP to keep differential off hyd spear -- to keep it latched in) to flow back tank. Jar down once, PU and jars went off on up, RIH and jar down once again, PU not latched, RIH and jar down 4 more times (able to cock jars even though we are not latched) and guns broke free. Push guns to bottom easily -- about 15'. Unable to latch up FN after numerous times. SI WHP built to 550 psi. Circulate kill well on choke. Attempt to latch fish -- can't get it. Start POOH to check fishing tools. Must have something on, started seeing ratty weight 11 ,200ish, then pulled heavy to 60k at 11,120'. Drag heavy, with a few jar hits up, to 11,092' (spear depth). Unable to work up past here with several jar hits up. Try to work free going down. Move it down to 11094' -- then no more progress. Jar down over 30 times -- no progress. Jar up a couple of times -- got it moving again. Pull to 11,060' and hung up here. -- got it moving again. NOTE: HITTING TIGHT SPOTS EVERY 30' (PULLING THROUGH LINER TOOL JOINTS??). Pull to 11,030' and hung up here. Hold 23k over while circulating to warm coil. Continue jarring up and down. Pressure up backside to 2200 psi. Shut down pump holding pressure. Jar down. Free down. Unable to pull up. Printed: 11/12/2003 11 :03: 17 AM BP EXPLORATION Operations Summary Report STUC COMP Retry losing ground. Lost total of 56'. Attempt to circulate no returns. Packed off. Attempt to release hydraulic GS to circulate sweep. Pumping down coil at 4300 psi @ .9 bpm. Pick up. Pressure dropped to 800 psi rate increased to 1.2 bpm. Attempted to relatch set down. Seen presure increase to 3090 psi but unable to relatch. Something is broken. STUC COMP Circulate high vis sweep. Prior to POH to CSH. Injected 3 bbls at .5 bpm at 2250 psi. POH. STUC COMP Un sting from well. Set back injector. STUC COMP Found upper hydraulic disconnect released. Most probable cause jarring weakened pins. Total length of Fish = 2,258' (1133' guns,Lower dicsonnect, Baker GS shear ,XC, 1120' 1" CSH,XO,XO, Lower Hydraulic disconnect) with top of fish at 9,955' CTD. STUC COMP Reviewed fishing options. 1) Wait on special built 0 ring seal sub leaving us with 2 hydraulic disconnects in the bha with uncertainies regarding which would release first or 2) Latch fish and pull to failure. Weak point is the fishing neck on the lower disconnect. Discussed with CTD manager. Decided to terminate fishing operations. RIH with nozzle to freeze protect to 2000'. Methanol trailer valving frozen. Thaw valve Freeze protect well to 2000' and reel with 60/40 methanol while pulling out of hole. 60/40 methanol is 40/60 according to the MM. Called for more 60/40. Freeze protect well to 2000' with 60/40. POOH. Rig down. Unstab coil and pull//secure to reel, nipple down BOPE, NU and PT tree cap, change out reel, start cleaning pits. Waiting on vac truck to finish cleaning pits. Clean mud pits. Rig Released at 20:30 hrs 2-18-2003 Move rig from 7-33 to 7-29. Derrick up. SPot rig over well. Accept rig at 1900 h rs 11/6/03 NU coil BOPS. Load pits with 400 bbls 2% KCL with 1/2# bio and 6% lubtex. RU comms & power to rig camp. Pressure BOP equipment. Witness waived by L. Grimaldi with AOGCC. Inspect chains on injector. Continue to test BOPs. Complete test. No failures. MU nozzle assembly. Test same. Complete hooking up IA & OA pressure sensors. 0 psi OA, 525 psi lA, 380 psi WHP. Intial WHP 1300psi. Quickly bled off to 350psi. (fluid packed). RIH holding 350-400 psi WHP. Take returns to tiger tank. Diesel, crude in returns. RIH to 9940'. From 9940' displace wellbore to 2% KCL then hi-vis spacer pill followed by 2% KCL with 1/2# bio and 6% Lube-tex. RIH and wash-up on top of fish at 9964.5' (uncorrected) correct to 9955'. Shut down and observe well. Seeing some gas. Continue circulating and gas alarm went off. Re-route to gas buster and continue circulation. Keeping IAlOA bled off below 400psi. Stop oberve well. No gas slight amount of oil. STUC COMP TOH. Paint EOP flag at 9505'. Continue TOH. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 COde' NPT Phase 2/17/2003 18:00 - 21 :00 3.00 PERF N 21 :00 - 23:30 2.50 PERF N 2/18/2003 23:30 - 00:00 00:00 - 00: 15 0.50 PERF N 0.25 PERF N 00:15 - 01:00 0.75 PERF N 11/6/2003 01 :00 - 03:20 2.33 WHSUR N WAIT COMP 03:20 - 04:30 1.17 WHSUR N WAIT COMP 04:30 - 05:30 1.00 WHSUR P COMP 05:30 - 06:30 1.00 RIGD P POST 06:30 - 15:00 8.50 RIGD P POST 15:00 - 17:30 2.50 RIGD N WAIT POST 17:30 - 20:30 3.00 RIGD N POST 16:30 - 19:00 2.50 MOB N STUC PRE 19:00 - 22:00 3.00 BOPSURN STUC PRE 22:00 - 00:00 2.00 BOPSUR N STUC PRE 00:00 - 02:00 2.00 BOPSURN STUC PRE 02:00 - 04:00 2.00 KILL N STUC COMP 04:00 - 06:25 2.42 KILL N STUC COMP 06:25 - 10:45 4.33 KILL N STUC COMP 11/7/2003 10:45 - 12:30 1.75 KILL N Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 Printed: 11/12/2003 11 :03: 17 AM Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 HOurs Task 11/7/2003 12:30 -13:30 1.00 KILL N STUC COMP 13:30 - 15:50 2.33 FISH N STUC COMP 15:50 - 17:45 1.92 FISH N STUC COMP 17:45 - 18:30 0.75 FISH N STUC COMP 18:30 - 20:00 STUC COMP 1.50 FISH N 20:00 - 20:30 0.50 FISH STUC COMP N 20:30 - 21 :30 21 :30 - 22:00 1.00 FISH 0.50 FISH STUC COMP STUC COMP N N 22:00 - 23:00 1.00 FISH N STUC COMP 23:00 - 00:00 1.00 FISH N COMP 11/8/2003 00:00 - 00:30 0.50 FISH N STUC COMP 00:30 - 02:30 2.00 FISH N STUC COMP 02:30 - 04:30 2.00 FISH N SFAL COMP 04:30 - 05:00 0.50 FISH N SFAL COMP 05:00 - 06:00 1.00 FISH N SFAL COMP 06:00 - 06:30 0.50 FISH N SFAL COMP 06:30 - 08:15 1.75 FISH N SFAL COMP LID nozzle. P/U Andergauge BHA (AG-itator range 40-140gpm) RIH to 1000'. Bring on pump. Vary pump rates f/ 1.4 to 2.5 bpm. Do not think we need to rattle it harder than 2.5 hanging in tubing, could lose something from BHA. RIH correct to flag -6'. Check wts at 9660' w/wo pump PUW/SOW 26.1k/14.8k with pump no significant changes. RIH at min rate to top of fish at 9955'. With varying pump rates starting at 1.6bpm through 2.7bpm pushing down. Slowly increasing "wob" f/ 2k-6k. Maybe in "lock-up" on 1" CSH. Seem to have some movement with 4-5k then stopped. Only slight movement <1'. SO pump p/u and straighten out everything again. Pump at 1.8 and 3-4k wob. It appears to give back weight working at this weight but it maybe just compressing the 1". Slowly increase wob to 6-7k... SO pump. P/U to 38k 9943' and pump at 1.8bpm. Maintain 38k while pumping increasing pull to 50k seeing some movement up. Possibly just getting all the stretch out. Maintaining 50k. Increase to 2bpm. slow to 1.8 seeing better action on weight indicator here. Set down wt to 14K. Shut down pump. Pull up to 51 K#. No movement. Shut in choke. Increase WHP to 1800 psi. Open choke. Repeat three times. No movement. Pressure well down kill line to 500 psi.. Bleed coil to zero. Dump whp to coil. Repeat at 1000 psi, 1500 psi, 2000 psi whp. No movement. Resume circulation through vibrator tool pulling 57K# up wt. Shut down pump. Set down to 13K# to cock jars. Begin jaring with 56K# up wt. Jar several times. No movement. Up wt drops 4K# when jars activate. Circulate to vibrate again at 1.5 to 2.5 bpm. Pulling 55K#. Jar again 3 times at 58k# up wt. Top of fish now at 9925'. Cannot tell if footage gained is due to coil stretch or fish movement. Set down and pump at 2.5 bpm to release GS spear. POOH. Notice several gouges in pipe while tripping. Stop to investigate. Chain block had a small piece of metal jammed into surface, causing shallow dings in pipe (approx 1/16" deep, 1/4" wide). Discuss with SLB cell lead. Decide to continue. Continue to POOH. LD vibrator tool assembly. Inspect injector blocks for damage. MU hiptripper tool assembly with GS spear and redressed FA disconnect & check valves. RIH. Stop several times to inspect coil dings. Several long gouges near 9750' , .20" deep, .25" wide, 12" to 18" long. Major pipe damage!!! Paint yellow flag at damaged area. POOH to change reels. LD BHA. Prep to blow down reel with N2. Reel has 61 OK running feet and will be junked. Crew change. Safety meeting dicuss blowdown procedures. Thaw out blowdown line. Get on N2 and blowdown reel to tiger tank. Printed: 11/12/2003 11:03:17 AM BP EXPLORATION Operations Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 Cöde..NPT 11/8/2003 08:15 -10:30 2.25 FISH N SFAL caMP 10:30 - 12:00 1.50 FISH N SFAL caMP 12:00 - 23:00 11.00 FISH N SFAL caMP 23:00 - 00:00 1.00 FISH N SFAL caMP 00:00 - 01 :00 1.00 FISH N SFAL caMP 01 :00 - 02:00 1.00 FISH N SFAL caMP 02:00 - 03:00 1.00 FISH N SFAL caMP 03:00 - 05:45 2.75 FISH N SFAL caMP 05:45 - 06:00 0.25 FISH P caMP 06:00 - 10:45 4.75 FISH N DPRB caMP 11/9/2003 10:45 - 13:15 13:15-14:15 2.50 FISH 1.00 FISH DPRB caMP DPRB caMP N N 14:15 - 18:00 3.75 FISH DPRB caMP N 18:00 - 20:00 2.00 FISH N DPRB caMP 20:00 - 21 :30 1.50 FISH N DPRB caMP 21 :30 - 23:30 2.00 FISH N DPRB caMP Unstab coil from injector and secure to reel. Swap reels and secure in place. Inspect injector. Replace chains. Replace reel bushings. MU hardline inside reel. Stab pipe in injector. Continue to stab pipe into injector. Install Baker coil connector. Pump dart through coil. 40.6 bbls, (41.2 calculated). Cut off coil connector. Fluid falling out of coil. Small amount of solids on top of dart MU hiptripper bha with up jars & gs spear. RIH with fishing bha. Stop often to adjust weight indicator and to check injector/chains. Instructed not to pump by Baker rep to preserve "life" of hiptripper. Tag fish at 9961' (uncorrecetd). 28k# up, 13k# dn wt. Latch fish p/u to 35k confirm latch. Setdown and start pump to hiptrip down. Coil pressured up after pumping +/- 2bbls. Plugged off. Unable to pump down coil. Unable to disenage GS spear. Working coil. Pressure up annulus and hold at 1500psi. Pressure up coil to 3000psi and dump through choke trying to possibly trip the check valve and backflush - not working.. Varying coil pull weights from neutral to 10k +/- trying to move some fluid through coil to release GS. Safe to say the jars are not working. Have spent 2 hrs cycling pumps etc. Mobilizing equipment to protect coil from further freeze-up and equipment to cut coil at surface. Hold PJSM with crews and discuss situatuion and plans forward. Install split type heater hose on coil betweeen reel house and gooseneck +/- 95'. Will warm up coil prior to attempting maximum pull to shear weakest link within the fish. This is the SLB 1.69 disconnect below 1" CSH. 1.69" disconnect neck below the 1" CSH rated at 30k. Wait on coil the thaw between reel house and gooseneck. Pull to 63k max allowable with 2" coil. Work tension down and hold. Nothing happening. Jars not working either. Load and launch .625" ball. Rapidly pumping up to max pressure (4800) to move ball over reel wraps. This could take awhile but just might work. We can hear ball rolling couple wraps each time. Work to last wrap. Having hard time getting it over the gooseneck, rolls back into reel house. Call for SLB pump truck. Try surging coil to 5000 psi with 55k# up wt, then running in hole. Can still hear ball roll back down towards reel. Continue to try surging ball several times. RU SLB pump truck. Hold PJSM with crews. Discuss fluid handling issues. Pressure test lines to 8000 psi. Surge coil to 5000 psi with pump truck. Never heard ball come back into reel. Surge again to 7500 psi. Bleed off. Surge again to 5000 psi and listen for ball. No trace. Should be over goose neck. Allow ball to fall for 50 minutes. Pressure coil to 7500 psi several times. Put pipe in tension and surge to 7500 psi. Put pipe in compression and surge to 7500 psi. Made a total of about 15 presuure surges. No release from fish. Printed: 11/12/2003 11 :03: 17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2003 Rig Release: 11/7/2003 Rig Number: Spud Date: 2/14/1988 End: 11/11/2003 11/9/2003 23:30 - 00:00 0.50 FISH N DPRB CaMP Get all tools & equipment together on floor for chemical cut operation. 11/10/2003 00:00 - 00:30 0.50 FISH N DPRB COMP Hold PJSM with all crews in ops cab. Review coil cutting procedure line by line. 00:30 - 03: 15 2.75 FISH N DPRB CaMP Pull to 21 K# (5K# over string wt). Close upper pipe/slip rams close manual locks. Pull test to 30k#, push to 5k#. Slips holding ok. Strip up over pipe with injector. Hot tap coil. Cut and dress coil stub. Install Baker slip type connector pull test to 35k, full opening valve,Y side pumpin sub with valves, pack-off. 03:15 - 04:30 1.25 FISH N DPRB CaMP Spot e-line unit. RU SLB e-line equipment. Bring tools to floor. 04:30 - 05:00 0.50 FISH N DPRB CaMP Hold PJSM with all crews in ops cab. Discuss safe areas, minimal personnel on floor, fall protection, radio silence and more. 05:00 - 06:00 1.00 FISH N DPRB CaMP R/U SWS equipment. 06:00 - 09:00 3.00 FISH N DPRB COMP RIH to 9850'. Did not attempt to tag top of fish or set down with chem cutter. Fire cutter with good surface indication of cut. TOH to 200'. 09:00 - 09: 15 0.25 FISH N DPRB COMP PSJM review I/d procedures for chemical cutter. 09: 15 - 09:45 0.50 FISH N DPRB CaMP LID cutter and rId sheave. 09:45 - 10:05 0.33 FISH N DPRB CaMP PJSM. Review operational steps to confirm chemical cut. Spaceout and installation of cold roll CTC. 10:05 - 10:35 0.50 FISH N DPRB CaMP P/U on coil to 21 k. Unlock manuallockdown on stack open combi's. P/U on coil 20' with continuous 26k up wt confirm cut. Setback down to working height for install of CTC. Close combi's and lockdowns. 10:35 - 10:50 0.25 FISH N DPRB CaMP Finish clearing floor of SWS equipment. 10:50 - 12:00 1.17 FISH N DPRB CaMP P/U injector. Dress injector coil end and install cold roll CTC. 12:00 - 14:00 2.00 FISH N DPRB COMP Veco rig up 10' scaffolding 14:00 - 14:30 0.50 FISH N DPRB CaMP PJSM review plan forward for cut and dressing of coil looking up. Review hazards of working at heights with scaffolding. 14:30 - 16:00 1.50 FISH N DPRB CaMP Realign injector tugger attachment point to aid in stabbing CTC. Check for pressure on coil. Remove 2" valve. Cut and dress coil for CTC. Called AOGCC for 24hr notice of BOP testing on 2-29. Also dicussed our recent problems and plans forward with this well. 16:00 - 16:30 0.50 FISH N DPRB CaMP Rig down scaffolding. Review plans to lower injector. 16:30 - 18:30 2.00 FISH N DPRB CaMP Lower injector to position CTC in middle of chains and apply chain tension. Open manuallockdowns and combi rams. Make anouncement over rig phone stay clear of rig floor. TOH 18:30 - 21 :00 2.50 DEMOB P POST At surface. PU injector to locate end of coil. RU to unstab pipe. Spool coil back to reel and secure same. 21 :00 - 21: 15 0.25 DEMOB P POST Hold PJSM with Peak to review reel drop procedures. Hold PJSM with Hot Oil crew to discuss freeze protection of tbg. 21 :15 - 22:30 1.25 DEMOB P POST Drop 2" reel onto trailer. RU Hot Oil and circulate 40 bbls of diesel/60/40 down inner annulus. 400 psi@ 1.5 bpm. Take returns from tbg until mud switched to crude. Shut in well. 22:30 - 00:00 1.50 DEMOB P POST Clean pits. Prep pipe shed to LD derrick. 11/11/2003 00:00 - 11:45 11.75 DEMOB POST Blow down BOP stack. Pull & LD BOP riser. ND BOPS. NU tree cap. Test tree to 5000 psi. Warm up moving system hydraulics. Haul several loads to DS 2 with loader. Rig released at 0600hrs 11-11-2003. Rig left DS 7 at 1145 hrs 11/11/03. Printed: 11/12/2003 11:03:17 AM ') ) BPEX:PLORA TION Opetati!QAS.··.Summary 'Report Page 1 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Spud Date: 2/14/1988 End: 1/5/2004 Date From - To · Hours Task Qoqe NPT PfjÇîse ..Q~$çriþtic)n...of·o.pørati()n$ 12/18/2003 17:30 - 00:00 6.50 MOB P PRE Rig Down Rig Floor And Can-Rig Top Drive - Lay down Mast. Load up Pit Complex and Satellite Camp. Load up Truck Shop. Ready the Sub for move to DS 7 -29C 12/19/2003 00:00 - 03:30 3.50 MOB P PRE Move the Pit Complex and the Satellite Camp over to DS 07-29C. 03:30 - 05:00 1.50 MOB P PRE Move the 2ES Substructure from S-27B to DS 07-29C. 05:00 - 17:00 12.00 MOB P PRE Rig moving system front, inside tire locked up at the S pad turnoff. Get replacement parts, motor and clutch, off of 3S and fix 2ES. Test moving system. Begin travelling down the road @ 1700 hrs. 17:00 - 21 :00 4.00 MOB P PRE Begin moving from the S pad turnoff to J pad. 21 :00 - 00:00 3.00 MOB N WAIT PRE CPS was to measure the max height of the rig at J pad to assure themselves that there would be no contact made with the overhead lines. At 2100, when the rig got to J pad, the winds had picked up to greater than 20 mph and it was deemed unsafe to use the manlift. At this time, the rig was stopped from moving to wait for the weather to break. Currently the rig is sitting on the Spine Road next to J pad. As of 11 :45pm, the field has gone to a Phase 2 condition. Note: On Standby Waiting on Weather as of 210012/19/2003 12/20/2003 00:00 - 08:00 8.00 MOB N WAIT PRE Continue standby waiting on weather (with full crews) to break so CPS can measure the height of the rig and allow it to pass under the power lines. Changeout the double gate ram bodies on the BOP stack while waiting on weather. As of 0300, the main roads are Phase 1 and the access roads and pads are Phase 2. 08:00 - 15:30 7.50 MOB P PRE Wind speed reduced to less than 20 mph - Phase 1. CPS measured the height of the rig and the rig was allowed to continue from J pad to DS 7. Note: Total Rig standby time (with full crews) - 11 hours. 15:30 - 17:30 2.00 RIGU P PRE Set Herculite. Spot Sub Base over well 7 -29C. 17:30 - 00:00 6.50 RIGU P PRE Work on Mud Pump #2 installation. Hold PJSM, raise and pin the derrick. Spot the pits, cuttings tank, Mud and Geo shacks. Spot the camp, truck and welding shops. Berm in the rig and start taking on seawater. 12/21/2003 00:00 - 07:00 7.00 RIGU P PRE Hang Bridle lines and continue to rig up and install #2 mud pump. Roll the pump with seawater to test - good. Accept Rig 070012/21/2003 07:00 - 07:30 0.50 RIGU P DECOMP Hold Rig Pre-spud safety meeting and review the Pre-spud Checklist. 07:30 - 09:00 1.50 WHSUR P DECOMP Rig up to displace out the diesel freeze protection fluid. Pull BPV with lubricator - 0 psi on tubing and annulus. 09:00 - 13:30 4.50 KILL P DECOMP Reverse circulate out the diesel through the choke to the cuttings tank @ 3bpm. Pump 40 bbl Safe-Clean pill to surface the long way @ 9bpm until fluid was clean. Monitor the well and blow down lines. Well static. 13:30 - 14:30 1.00 WHSUR P DECaMP Install BPV. Test from below to 1000psi for 10 minutes. 14:30 - 16:30 2.00 WHSUR P DECOMP Nipple down the tree and adapter flange. Install Blanking plug. Send off tree and adapter for inspection and possible reuse on this well. 16:30 - 22:00 5.50 BOPSUR P DECOMP Nipple up the BOP's. Check and tighten all flanges. Install top 3.5"x6" variable rams and blind/shear rams. Install mousehole. Load pipeshed Printed: 2/212004 11 :21: 13 AM ) ) SF> EXPLORATION Operatiøns Summary Report Page 2. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Spud Date: 2/14/1988 End: 1/5/2004 Date Fröh'l-To Hours Task Code NPT Phase Description of' Operations 12/21/2003 22:00 - 00:00 2.00 BOPSURP DECOMP Test BOP's and all related valves to 250 psi low and 3,500 psi high. Note: Called AOGCC Rep John Crisp who waived the witnessing of the test. 12/22/2003 00:00 - 02:00 2.00 BOPSUR P DECOMP Continue testing BOP's to 250 psi low and 3,500 psi high. 02:00 - 03:00 1.00 WHSUR P DECOMP Pull Blanking Plug with FMC. Rig up DSM Lubricator to pull BPV. Bring tubing handling equipment to the floor. 03:00 - 04:00 1.00 WHSUR P DECOMP Pull BPV with Lubricator - no pressure seen. Rig down the lubricator and clear the floor. Attach crossover to landing joint. Changeout elevators, pick up landing joint and screw into 9" LH ACME threads with 6-1/2 turns. 04:00 - 05:00 1.00 PULL P DECOMP POH with Tubing Hanger. P/U - 130K with no over pull. Cut appears to be clean. Lay down the tubing hanger and clear the floor. Rig up Camco to spool up 2 control lines. 05:00 - 09:00 4.00 PULL P DECOMP Rig up Camco control line spooling unit and lay down 4.5" tubing to SSSV (tubing cut estimated to be 9820'). Rig down spooling unit and clear the floor. Retrieved 73 of 74 bands. 09:00 - 18:30 9.50 PULL P DECOMP Lay down 4.5", 12.6 # L-80 tubing from 7,597' to surface. 311 jts of tubing + 4.27' of the next joint, 5 GLM's, 1 SSSV pulled out of the hole. 18:30 - 19:30 1.00 PULL P DECOMP Rig down tubing handling equipment and clear the floor. 19:30 - 21:00 1.50 PULL P DECOMP Test BOP's with 4" HT -40 Test jt. Install wear ring. 21 :00 - 22:00 1.00 PULL P DECOMP PJSM with Schlumerger. Rig up Schlumberger. 22:00 - 00:00 2.00 PULL P DECOMP RIH with CCUJB and 8.5" GR. Tag up at 9,771' WLM. Pull up 200 ft and try 2 more times. Each time, same result. 12/23/2003 00:00 - 01 :30 1.50 PULL P DECOMP POH with E-line. Confer with town to ensure okay to set EZSV @ 9,771' WLM - below the Top of the HRZ. Confer with Baker hand that EZSV @ 9,771' would be okay to mill the window. Estimate that EZSV would be -8' above the next casing collar having seen one @ 9,737' WLM. Plan forward to set EZSV at 9,771'. 01 :30 - 03:15 1.75 PULL P DECOMP RIH with EZSV 9,77 'MD. Set EZSV. Top of whipstock calculates out t , Ell-ow next collar seen on logs at 9,737'. 03:15 - 04:30 1.25 PULL P DECOMP POH with Schlumberger. RID Schlumberger. Clear the floor. 04:30 - 05:30 1.00 PULL P DECOMP Pressure test the 9-5/8" casing to 3500 psi and hold for 30 minutes - good test. Bleed off pressure. 05:30 - 08:00 2.50 STWHIP P WEXIT PJSM. M/U BHA. Upload and Surface test MWD. M/U Whipstock assembly. 08:00 - 10:30 2.50 STWHIP P WEXIT P/U 9 Drill Collars and 18 jts of HWDP. 10:30 - 17:00 6.50 STWHIP P WEXIT Single in the hole with Whipstock BHA on 4" Drill Pipe to 6,552'. Fill the pipe and test MWD every 3,000'. 17:00 - 18:00 1.00 STWHIP P WEXIT Cut and slip drilling line - cut 115'. 18:00 - 22:30 4.50 STWHIP P WEXIT RIH with Whipstock BHA from 6,552' to 9,729'. Break circulation and orient whipstock to 24 degrees LHS. P/U- 200K, S/O - 160K 22:30 - 23:00 0.50 STWHIP P WEXIT RIH and tag bottom @ 9769'. Set down 20K to set the anchor. Surface indication that anchor is set. P/U 5K to verify anchor is set. Set down 45K to shear bolt. Surface indication bolt sheared. P/U to neutral - top of whipstock and chain the brake handle down. Whipstock set at 24 degrees LHS. 23:00 - 00:00 1.00 STWHIP P WEXIT Swap over fluids to 10.8 ppg LSND fluid - 500 gpm @ 1700 psi 12124/2003 00:00 - 07:30 7.50 STWHIP P WEXIT Mill window and 20' of new hole from 9,746' to 9,778'. Bit weight - 9-20K, TQ - 6-12K. ROP - 3-5 ftIhr. 500 - 525 gpm, Printed: 21212004 11: 21 : 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP EXPLORATION Operations Summary' Report Page 3. 07 -29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Spud Date: 2/14/1988 End: 1/5/2004 From - To Hours Task Code NPT Phase Descriptipnof OpØrc:niol1s 12/24/2003 00:00 - 07:30 07:30 - 08:30 08:30 - 09:30 09:30 - 14:30 14:30 - 16:00 16:00 - 18:30 18:30 - 23:00 23:00 - 00:00 12/25/2003 00:00 - 11 :30 11 :30 -12:30 12:30 - 16:30 16:30 - 18:30 18:30 -19:30 19:30 - 20:00 20:00 - 23:30 23:30 - 00:00 12/26/2003 00:00 - 04:00 04:00 - 07:00 07:00 - 09:30 09:30 - 10:00 10:00 - 16:00 16:00 - 16:30 16:30 - 17:30 7.50 SlWHIP P 1.00 SlWHIP P 1.00 SlWHIP P 5.00 SlWHIP P 1.50 SlWHIP P 2.50 DRILL P 4.50 DRILL P 1.00 DRILL P 11.50 DRILL P 1.00 DRILL P 4.00 DRILL P 2.00 DRILL P 1.00 DRILL P 0.50 DRILL P 3.50 DRILL P 0.50 DRILL P 4.00 DRILL P 3.00 BOPSURP 2.50 CASE P 0.50 CASE P 6.00 CASE P 0.50 CASE P WEXIT WEXIT WEXIT WEXIT WEXIT INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 2,600 psi. TOW - 9,746', BOW - 9,762'. P/U -195K, S/O- 150K, Rot - 165K. Recovered 35# of metal. Circ sweep. Stand back one stand of 4" drillpipe. Perform FIT to 12.0 ppg EMW and hold for 10 minutes POH with Milling BHA from 9,778'. UD UBHO, Bumper Sub and Mills. Clear floor. Pull Wear Ring. Flush stack. Function test rams. Install Wear Ring. PJSM. P/U Drilling BHA. Orient MWD. Shallow Pulse Test MWD - 500 gpm @ 950 psi. RIH to 9,559' filling pipe and testing MWD every 3,000'. Install blower hose. Break Circulation - 500 gpm, 2900 psi. Orient MWD to ...30 LHS. RIH to 9,636'. LWD from 9,636' to 9,736'. Check orientation. P/U - 190K, 5/0 -150K Complete orientation. RIH through window and drill directionally to TD - 10,522'. P/U - 205K, 5/0 - 150K, Rot- 175K, TQ - 11 K, 520 gpm, 3,410 psi. Lost circulation @ 10,522'. Open Kill lines and fill an Loss of 135 bbls. POH into the casing @ 9,650'. Monitor the well. Blow down the top drive and iface equipment. Fill across the top to establish s rate. Hole stable. Build mud volume. Service To rive. Mix 100 bbl LCM pill at 30#/bbl. RIH to 10,522' without problem. reak circulation. Stage up pumps to 4 bpm @ 850 psi spot LCM pill. POH into casing @ 9,65 '. No problems tripping to shoe. Monitor well. Static. Pump dry job an op 2-3/8" rabbit. POH from 9,6 to 1,064'. No losses. UD 5" H to 877' UD re ming BHA. Down load and flush MWD. Clear the flo stall 7" rams in the upper set. Pull wear ring. Install test plug and test to 3500 psi. Re-install wear ring. RU casing handling equipment. PJ5M. PU 7", 29# N5CC Liner. RIH. PU hanger/packer assembly. Pump liner volume @ 3 bpm and 120 psi. Rig down casing handling equipment and clear the floor. RIH with liner on 4" drill pipe from the derrick to 9,740'. Fill pipe every 10 stands. No losses. Circ at TOW - 9,740'. No losses. Run in open hole. PU -187K, SO -127K. MU cement head on single and RIH. Tag bottom @ 10,522'. Break circ and stage up to 4 bpm without losses. PJSM. PT lines to 4500 psi. Pump 26.8 bbls 12ppg Mudpush spacer, 42.7 bbls 15.8 ppg Class G cement, displace with 126 bbls of 10.8 ppg LSND fluid @ 4 bpm. No losses. Bump plug on calculated volume. Cement in place @ 19: 15. Pressure up to 3500 psi and set the HMC hanger. Release from the hanger and circulate cement returns up the hole. Set weight down to set the ZXP packer. Rotate down to ensure set. Printed: 21212004 11:21:13AM ,., ) ') To: Winton Aubert - AOGCC Date: November 11, 2003 From: Rob Tirpack - BPXA GPB Rotary Drilling Subject: 7-29B Application for Sundry Approval- P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well 7-29B. This well is currently shut-in due to a fish in the hole. The well bore is providing no production or value to the field. The proposed work will utilize a bridge plug in the 9-5/8" casing to provide isolation to the existing perforations. Addition isolation will come from the 9-5/8" X 7" liner lap, which will be fully cemented. 7 -29B is horizontal Ivishak Zone 1 A sidetrack producer that was drilled by CTD Rig Nordic #2 in February 2003. There has been zero production since the CTD sidetrack. During completion operations, perforation guns became stuck. All indications were that the guns went off, and become stuck while pulling out of the production liner. Multiple fishing attempts have all proved unsuccessful. The proposed rotary horizontal sidetrack will target the Zone 1 A reserves left behind by the failed coil sidetrack. 7-29C is planned as a 2600' MD sidetrack with a fully cemented 4-1/2" liner. The 7-29C sidetrack is currently scheduled for Nabors 2ES beginning around 12/22/03, after completing the S-27B sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Scope Pre-Ria Work: 1. Drift the 4-1/2" tubing to the top of fish @ -9850' MD. / 2. Chemical cut the 4-1/2", 12.6#, L-80 BTC-M tubing at -9820' MD. 3. Fluid pack T X IA with seawater and freeze protect same with diesel. / 4. Test the 9-5/8" pack-off to 5000 psi and tubing hanger seals to 3000 psi. 5. Function all lock-down screws. Repair or replace as needed. "" 6. Bleed casing and annulus pressures to zero. 7. Set a BPV in tubing hanger. Secure well. 8. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. T ~ ~ i 0 - tfo ~ ~\~r f }1:.J\/ &...- (. 7-29B Application for Sundry ) ) Ria Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from above pre-rig cut. 5. RU e-line. Run GR/JB for 9-5/8", 47# casing to top of tubing stub. 6. MU 9-5/8", 47# bridge plug on e-line with CCL. RIH and set at 9800' MD, set as needed to avoid cutting a casing collar. 7. Pressure test casing to 3500 psi for 30 minutes. 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Swap over to 10.8 ppg milling fluid. 10. Mill window in 9-5/8" casing at 9800' MD, plus 20' past middle of window. Perform FIT. POOH. 11. MU 8-1/2" drilling assembly with Dir/GR and RIH. Kick off and drill the 8-1/2" intermediate interval, building and turning at 5°/100' to a 43° hold angle. 12. Drill ahead to casing point at Top Sag River to an estimated depth of 10,505' MD. 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 9,650' MD. Displace cement with mud. POOH. 14. MU 6-1/8" BHA with Dir/GR/Den/Neu and RIH to the landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. 16. Drill shoe track. Swap over to 8.6 ppg mud and drill 20' of new formation. Perform FIT. 17. Drill the 6-1/8" production interval building at 10°/100' to horizontal, targeting Z1A Ivishak. Drill ahead to an estimated TD of 13,112' MD. 18. Run and cement a 4-1/2" liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to 10,355' MD. 19. Displace well to clean seawater. 20. Run 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. 21. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 22. Set and test TWC. 23. ND BOPE. NU and test the tree to 5000 psi. 24. Freeze protect the well to -2200' and secure the well. 25. RDMO Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-rig Start Date: 11/24/03 Estimated Spud Date: 12/22/03 Rob Tirpack Operations Drilling Engineer 564-4166 7-298 Application for Sundry "\ ¡NGÂ- II ( r,:> I ¿oc¡'š .D IS [t//3/3 ~ /11'3 ) STATE OF ALASKA \ ALASKA OIL AND GAS CONSERVATION COMrv'.vSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: a Abandon o Alter Casing o Channe Approved ProQram 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): o Suspend 0 Operation Shutdown 0 Perforate o Repair Well a Plug Perforations 0 Stimulate o Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: iii Development 0 Exploratory o Stratigraphic 0 Service 8. Property Designation: I ~ I . ,i;"'1 I"''''! "",;'1,,;"'; Total Depth MD (ft): 12550 Casing· Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool , ...:'" .8'ó:E· ······S··· ·1:;:t..I;r)A1E' Lli.t?bK.1 nl.T,·'Q. ...·rI1IIS:.U·····p).....'.ilX!D:VI!."....,i.ii....'!,·,.·.. .... ¡"r¡;I,'.'~ "" I' I~I~:,~,';:I:'::,,!:~:,J',,' ":""'~: ':V~'~I~;~:":'I,~I:",;", ,',il.:~,'I,,' '", ",..:i~~:.,~.yl~~~:·'~\":., :,:I;:,~:: :'::,1,",',',,1-: ':':::1' : Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12533 8944 None 99519-6612 KBE = 65' ADL 028306 " ,,':,:<:, I" "~II Total Depth TVD (ft): 8944 Length Junk (measured): 9955 . COllápse 110 20" 3767' 13-3/8" 10591' 9-5/8" 720' 7" 766' 3-3/16" 2241' 3-1/2" x 2-3/8" Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 11400' - 12520' 8953' - 8943' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker DB packer; 4-1/2" Otis 'HRQ' SSSV Nipple 12. Attachments: iii Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program ·i4. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Signature ?). AA ~. ~.... Phone 564-5521 Date \\ J j I J 0.3 Commission Use Only z~ November~, 2003 Date: o Variance o Time Extension o Annular Disposal 5. Permit To Drill Number 202-239/' 6. API Number: ./' 50- 029-21782-02-00 o Other 9. Well Name and Number: PBU 07 -29B ,/ 110' 3767' 1 0591 ' 110' 3626' 3450 1950 8424' 6870 4750 8269' - 8777' 8160 7020 8263' - 8802' 8221' - 8944' 10371' - 11091' 10363' - 11129' 10305' - 12546' Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 10366' 2223' Tubing MD (ft): 10461' 13. Well Class after proposed work: o Exploratory iii Development 0 Service 15. Well Status after proposed work: DOil o Gas o WAG 0 GINJ o Plugged DWINJ a Abandoned o WDSPL Contact Rob Tirpack, 564-4166 / Prepared By Name/Number: Terrie Hubble, 564-4628 Sundry Number: ,)03 v j,3:J-- o Plug Integrity o BOP Test Conditions of approval: Notify Commission so that a representative may witness o Location Clearance RECEIVED : ."\/ 1 ~2003 Alaska Oil & Gas Cons. Commission Anchorage 11 J } ~ I r/} Submit In Duplicate Other: Subsequent form required 10- '-101 ~ Approved By: ~ Form 10-403 Revised 2/~ f8*S BFl o Mechanical Integrity Test BY ORDER OF THE COMMISSION Date Or.....t~~~~A' J r< ¡l47 [, t \l;- ' · TREE =' 4-1/8" FMC WELLHEAD = FMC ) ÄëTÙATÕR;"Ax'Ei~SÕN 'ks.äEV';" .."...... ... "'65;' BF. ELEV = ................. ............" "..,,,.,,......,,. KOP = 2600' MaxÄngie;;' 'gä@'1200S' 'ÖaturŸÙ"1Ö";"M..O,,o"'^11"22Ö' 'ÖatUmTv 0; .. "säoo' šS" 07 -298/ SAFEr1TES: ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 83 @ 11400' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-1/2" 4 11400-11695 0 02/15/03 1-1/2" 4 11735 - 12030 0 02/15/03 1-1/2" 4 12090 - 12200 0 02/15/03 1-1/2" 4 12310 - 12335 0 02/15/03 1-1/2" 4 12385 - 12520 0 02/15/03 NOT CONRRMED; GUNS LEFT DOWN HOLE I 2-3/8" LNR, 4.41#, L-80, .0036 bpf, ID = 1.92" l-f 12546' 1 3-3/16" LNR, 6.2#, L-80, .0076 bpr, ID = 2.786" H 12815' ~ - 113-3/8" CSG, 72#, K-55, ID = 12.347" H 3767' ~ Minimum ID = 1.91" @ 10325' 3-1/2" X 2-3/8" XO " Top of Fish @ 9850'~ · TOP OF 3-3/16" LNR, 6.2#, ID = 2.786" l-f 10368' 19-5/8" x 7" LNR HGR 1-1 1 0371' ~ III/O.WII \ 4-1/2"TBG, 12.6#, L-80, .0152 bpf,ID=3.958" 1-1 10460' 1 I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-f 7" LNR, 29#, L-80, .0372 bpf, ID = 6.184" l-f 11470' I TOP OF WHIPSTOCK 1-1 11130' c ~ DATE 03/07/88 12/25/98 02/19/03 02/23/03 06/05/03 09/10/03 REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK (07-29A) DAC/KK CTD SIDETRACK (07-29B) DAClKK GLV C/O CMO/TLP MAX ANGLE CMO/TLP DATUM MD CORRECTION DATE REV BY 2223' l-f 4-1/2" OTIS HRQ SSSVN, ID = 3.813" GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LA TCH PORT DATE 1 2811 2804 13 TGPD DOME TG 16 02/23/03 ~ 2 5260 4623 46 TGPD SO TG 20 02/23/03 3 7052 5885 46 TGPD DMY TG 06/19/02 4 8378 6803 46 TGPD DMY TG 06/21/88 5 9367 7503 44 TGPD DMY TG 06/21/88 6 9889 7894 38 TGPD DMY TG 12/30/98 7 10191 8133 39 TGPD DMY TG 11/05/98 8 10281 8203 41 TGPD DMY TG 06/19/02 i 10305' l-f 3.70" BKR DEPLOYMENT SLY, ID = 3.0" i 10320' l-f 3-1/2" HES XN NIP, ID = 2.75" 1 I 10325' 1-1 3-1/2" X 2-3/8" XO, ID = 1.91" 1 ~ 10365' 1- TOP OF BKR LOC SEAL ASSY (BEHIND CT LNR) ;':':'.~ " 10366' 1- 9-5/8" X 4-1/2" BKR DB PKR, ID = 4.750" (BEHIND CT LNR) 10377' 1- BTM OF 4-1/2" BKR SEAL ASSY (BEHIND CT LNR) 10379' 1- BTM OF BKR SBE, ID = 4.750" (BEHIND CT LNR) 10449' l-f 4-1/2" OTIS XN NIP, ID = 3.8" (MILLED OUT) 1 10461' l-f 4-1/2" WLEG (BEHIND LNR) 1 L MILLOUT WINDOW 11129' - 11133' FISH (SEE WELL FILE FOR DETAILS) 12533' 1-1 PBTD 1 COMMENTS PRUDHOE BAY UNIT WELL: 07 -29B ÆRMIT No: 2022390 API No: 50-029-21782-02 SEC 33, T11 N, R14E, 452' FNL & 327' FEL BP Exploration (Alaska) 7 -¿AS Pre-Rig '..'York ~ L ~ TREE = 4-1/8" FMC WELLHEAD = FMC ÃCTUÂTOR = AXELSON ..".. .............. ......."...""""... KB. ELEV = 65' ŠÞ:ECË'i ~. kQ'p;,·····,,·""··260Öì' .. ..".........,..,..........".."............. Max Angle = 9.6 ~1~g05' Öatum'MÖ; ..... .. ... ..., , 11220' 'DatÙïiï"T\ib'''; .... i~8'6ö'ï"SS (I) ~ ~- Tubing Cut @ 9,820' ., Top of Fish @ 9,850' -:.....: Top of Deployment Sleeve @ 10,305' ~ ~.I.,....:.'!.jj.! a _ - ! l ~ ~. c IBI A Date 11-11-03 Rev By Comments RBT Proposed Pre-Rig Work PRUDHOE BAY UNIT WELL: 7-29B API NO: Permit NO: GPB Rotary Drilling ·~ 7-29C P,Loposed Co~hpletion 3767' ~ ~ 13-3/8", 72#, K-55 TRæ = 4-1/8" FMC WELLHEAD = FMC ÄCiÜÄrOR; . AXElSÖN ......."""""........,......,.....,..,,,.,,,, KB. ELEV = 65' BF. ELEV = 'kóÞ"~""'" ... .. ....", .............. ........2'fj'(jÖï "~~.~.,..~,~.~~~".~ 96 @ 12005' Datum MD = . """"""'1'1220;' "OaiÜïi1TVÖ;';;"8SÒÓi§S ~ 4-1/2", 12.6#, L-80, IBT-M Tubing I Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 9,650' 9-5/8" X 7" Liner Hanger with ZXP Liner Top Packer GLM Design: #4 - 3150' TVD - 4-1/2" X 1" - SV #3 - 5000' TVD - 4-1/2" X 1" - DV #2 - 6500' TVD - 4-1/2" X 1" - DV #1 - 8000' TVD - 4-1/2" X 1" - DV 9,800' --- 9,820' 9,850'- 10,305' -.; . . - 7" X 4-1/2" Packer @ 10,300' , ~ 10,591' .~ } 11,470'~ 7", 29#, L-80~ 7" X 4-1/2" Liner Hanger with ZXP Liner Top Packer @ 10,355' ~ ~ ;.:..... 9-5/8" 47# L -80 ~ " 7", 29#, L-80, BTC-M @ 10,505' 12,546' ~ 2-3/8", 4.4#, L-80 12,815' ~ 3-3/16",6.2#, L-80 Date Rev By Comments 4-1/2",12.6#, L-80, IBT-M @ 13,132' 10-27-03 RBT Proposed Completion PRUDHOE BAY UNIT WELL: 7-29B API NO: Permit NO: GPB Rotary Drilling ) Transmittal Form t)Of) -839 ,&¡. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 7-29BPB1 ~_.._-_._---.-...-.._---_._- -" -_.~. --- ----."..-.. --.-~ _.._.------_._---.-.~-- ---"----------- - -. ----- - - --- .. -, - - -...-.. ... Contains the following: 1 LDWG Compact Disc- .:#- JaO 10 (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR-Directional Measured Depth Log 1 blueline - GR - Directional TVD Log LAC Job#: 428189 Sent By: Glen Horel Received By: {;21-j~ XJ. f:H~"-1 ' ~-Ëðe\l~ Date: JUN 2 0 2003 A1aska Oil & Gas Cons. Commieeim PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ~URNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~~\~~ i-'---·--------·----~--·,-~· : [~~~~~~~~~~~~~~~~~] I.., ,....,......,.... ,............. .."".'. , . . .. ~ ,. '~ ----...--- ) Transmittal Form ') I '&1. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 7-29B II Contains the following: 11 LDWG Compact Disc l \ î C¡ B I (Includes Graphic Image files) It 1 LDWG lister summary ¡ 1 blueline - MPR Measured Depth Log 11 blueline - MPR TVD Log I! Ii II I , II II LAC J ob#: 428189 I· __ -'-,--------------------- Sent By: Glen Horel Received By: Q:.LIL 0.fu'LPd- --..-......-..--.. -'-:"_-'--"1' I! II II i! II II II ¡ I II I' __ ~...__.__._,_._. n____u_.,..____....___ i [~~~';;'~Ml¡ T~~] . ·······~·.;.;:~:;¡';l:;.:~·;..;;·-"'·· .......... .._-"...'...... A1aIka Oit & Gas Coni. Commiseicn : . " PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & ID..~ING ' ' " ~ OR FAXING YOUR COPY FAX: (907) 267-6623 1 \ l4 B '...~... Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ! I I ___==-----..-,-----'1 ~;;2.~ ~ .3 CJ Date: RE~!NfED Date: JUN 1 G 2003 ,----,.--. ~ Schlumberger NO. 2772 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 05108/03 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ReœiV~~ Color Well Job # Log Description Date Blueline Prints E-02A 1<1 í-I:J Î MEMORY PROD PROFILE 03/15/03 1 E-31A ~rn-J 7 ~ MEMORY PROD PROFILE 08/08/02 1 M-29A ~~ tJ~'19 PDC & TEMPERATURE 04/15/03 1 F-04A ~ ¡Joe 23097 MCNL 03/02/03 1 H·21 I ?fO- ] 23074 RST-SIGMA 01/30/03 1 D.S. 1-32A I~-"'- I f. 23083 MCNUBORAX 02/02103 1 D.S. 5-06A Æ 5 '-( 23056 RST-SIGMA 01/23/03 1 D.S.7-29B ,~~~q 23096 MCNL 02/15/03 1 D.S. 15-38A ,:9.. 0 - J 23089 LINER TOP TIE-IN MGRlCCL 02110/03 1 D.S. 15-48Aç~D<c~no 5 23098 MCNL 02/19/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ V t-""" ' ~ ~K' . r.~r. !\. Þ=~ !' . , iF"" V t: ~ > 1- L..J _ .. s..~ Date Delivered: 'I .., 1"'f'\t'\J... MA' 1.j LvV..; I J ': C'" !-"t.,,-":. ,-, :'\ ~ r':o....!r"firn~~n i~'",,¡t!·oS' \.~I· ':I. ,...,~s WIiS. V~11,,~II;;;1iKoJ. ;-.<::",nç. '-'1 V'. "" And'lC1 !ga CD 1 1 1 1 1 1 1 -.....,./ ',~ '.. ') ) STATE OF ALASKA j ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ".; ';'::,;'::~i'~;i~] 1. Status of Well':¡""<;;!;'i~~~: "'~;,_ Classification of Service Well 2. :~~ of o~e::r 0 Suspended 0 Abandoned 0 Service ¡\~'.~;~.·:4¡: 7. Permit Number BP Exploration (Alaska) Inc. L',:.·,,:'~:;'~~~: 202-239 3. Address L,j"'i J 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 .~. JR,-.!?--.,·· 50-029-21782-02 4. Location of well at surface';J~i · 9. Unit or Lease Name 452' SNL, 32T WEL, SEC. 33, T11 N, R14E, UM C"-'~:X::::;:,:675856, Y = 5950465 Prudhoe Bay Unit At top of productive interval 75' NSL, 34' WEL, SEC. 21, T11N, R14E, UM X = 676000, Y = 5956277 10. Well Number At total depth 864' NSL, 714' EWL, SEC. 22, T11 N, R14E, UM X = 676728, Y = 5957083 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field 1 Prudhoe Bay Pool RKB = 65' ADL 028306 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 2/9/2003 2/13/2003 2/18/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12550 8944 FT 12533 8944 FT 181 Yes 0 No 22. Type Electric or Other Logs Run eCL, GR, Memory CNL, MWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 110' 30" 2568 # Poleset 13-3/8" 68#172# K-55/L-80 Surface 3767' 17-1/2" 291sxCSII,3000sxCSIII,600sxClass'G' 9-5/8" 47# L-80 Surface 10591' 12-1/4" 7" 29# L-80 10371' 11091' 8-1/2" 3-3/16" 6.2# L-80 10363' 11129' 4-1/8" 3·1/2' x 2·318' 8.81 # 1 4.41 # L -80 10305' 12546' 3" 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 1.56 Gun Diameter, 4 spf MD TVD 11400' - 11695' 8953' - 8953' 11735' - 12030' 8953' - 8945' 12090' - 12200' 8944' - 8942' 12310' -12335' 8945' - 8946' 12385' - 12520' 8947' - 8943' 07 -29B 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2223' MD 1900' (Approx.) AMOUNT PULLED 354 sx CS I, 700 sx Class 'G' 387 sx Class 'G' 123 sx Class 'G' 61 sx Class 'G' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 10461' PACKER SET (MD) 10366' MD TVD 26. ACID, FRACTURE, CEMENT S~UEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9955' - 12217' Perfing BHA left in hole 2000' Freeze Protected with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 22, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 3/26/2003 12.1 TEST PERIOD 14 6,004 -0- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 279 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbmt~i:~=.= ~ V~ "~-'.. f'). '''''::\.11::1 t:Ll No core samples were taken. CHOKE SIZE 70° GAS-OIL RATIO 99,999 OIL GRAVITY-API (CORR) t~' I··....", t~,:,: A P ~( U 1. ) U¡ 1'1" i ,_ u ~ '.l"'" r.' ~ E. ¡ -~ ) '\ ¡ , . : \ ( \1 , ,> L . ~ .., ¡ \ i Alaska 011 & Gas Gor~. CCfJ¡m1SSlOn .A:1C~':~!~ Form 10-407 Rev. 07-01-80 RBDMS 8Fl APR 4 2nOJ Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 1 B 11279' 8906' Zone 1A 113N 11317' 8928' 13P 11337' 8937' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin.g is true and correct to the best of my knowledge Signed TerrieHubble ~e.A/lt1. tiLMee Title Technical Assistant Date O"'i-DI.O:; 07 -29B 202-239 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Dan Kara, 564-5667 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). I;EM 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 , l ) ) BPEXPLORAT10N Oþetatiol1s$Ul11rn ªryRepo rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date From-To Hoürs Task CödëN PT 2/5/2003 20:30 - 00:00 3.50 MOB N WAIT PRE 2/6/2003 00:00 - 06:00 6.00 MOB N WAIT PRE 06:00 - 00:00 18.00 MOB N WAIT PRE 2/7/2003 00:00 - 04:30 4.50 MOB P PRE 04:30 - 07:00 2.50 MOB P PRE 07:00 - 12:45 5.75 MOB P PRE 12:45 - 13:05 0.33 MOB P PRE 13:05-15:15 2.17 MOB P PRE 15:15 - 18:00 2.75 MOB P PRE 18:00 - 18:30 0.50 MOB P PRE 18:30 - 21 :00 2.50 BOPSUR P PRE 21 :00 - 00:00 3.00 BOPSURP PRE 2/8/2003 00:00 - 02:00 2.00 BOPSUR P PRE 02:00 - 04:00 2.00 KILL P DECaMP 04:00 - 04:45 0.75 KILL P DECaMP 04:45 - 06:00 1.25 STWHIP P WEXIT 06:00 - 09:00 3.00 STWHIP P WEXIT 09:00 - 10:30 1.50 STWHIP P WEXIT 10:30 - 12:00 1.50 STWHIP P WEXIT 12:00 - 13:46 1.77 STWHIP P WEXIT 13:46 - 15:50 2.07 STWHIP P WEXIT Phase 2 Weather, drifting and blowing snow after six inches of new snow previous day, -50WC, Winds 30-50MPH. Wait on Weather prior to moving off 15-30. Phase 2, blowing and drifting snow. Ensure all transport to and from rig follows Phase 2 procedure (convoy, radio comms., notify supervisor, re-evaluate importance of travel & cancel if possible, plan for phase 3, arctic gear required) Continue waiting on weather for rig move. Replace bladders on Koomey. Troubleshoot frozen water line on rig. WOW down graded from phase 3 to phase 2 at 00:30 hours. Drill site maintenance to send blower to start clearing pads and roads. Move rig off well. Haul two truck loads to OS 7. Pull rig to edge of OS-15. Function test moving system on edge of pad. Not all wheels are in sync, some sort of electro-hydraulic control system problem, plan to change out one of the rear drive motors this AM. Still waiting on snow removal on OS-7. The drifts on OS-7 are very bad do to lots of equipment parked on the edge of the pad. OS 7 is ready for the rig. Still working on rear drive motor. PJSM on derrick up rig move from OS-15 to OS-7 with security and rig crew. Discuss escort procedure, ensuring radio contact, review route. Jack up rig, start rolling. Security & Toolpusher in lead, Schlumberger TL following. Perfect weather for a move, nice and sunny, no wind. Beautiful Prudhoe by the bay. Nordic 2 at OS-7. Maneuver onto backside of pad and position rig, tight S-turn. Stop over well. Crew change PJSM. NU BOP. Test BOP. Continue to test BOP. BOP test witnessed by Jeff Jones AOGCC. Test went well had two gas detectors one in cellar and one on rig floor which needed to be recalibrated. He didn't wait on the electrician to recalibrate them but asked to be called back to witness a retest. Fill pits with 2% Bio. Monitor well. Well head 620 psi. Bleed off thru choke. No fluid returns. Fill well with 33 bbl. Shut in well build back to 37 psi in 20 minutes. Bleed off well flowing. MU Nozzle. Sting on to well. Bleed off pressure. Slight trickle. LO nozzle. Test MHA. PU Milling BHA. Stab onto well. RIH with wnidow milling assembly. IA=590, OA=375. Gas alarm. Shut in well, line up to take gas returns out to tiger tank. Cont RIH, circulating in new KCL with 2ppb Bio. 11150.9 tag pinch point, correct depth to top of whipstock. PU, ease into milling. RIH wt= 13300Lbs, Freespin= 1490psi. Start milling at 11129.4, 1520psi / 1.6bpm Out MM not functioning. Milling 11,130.4 1725psi / 1.6bpm. Annulus pressures rising from wellbore heating, bleed IA and OA, IA=380psi, OA=239psi Milling 11,131.4 1800psi / 1.6/1.6 bpm Milling 11,132.4 1860psi / 1.6/1.6bpm PVT=288 Printed: 2/24/2003 10:31 :23 AM · . ') ) BPEXPLORATION o perationsSurnrnª ry Røpo rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date Frorn- To HoUrs Task Code NPT 2/8/2003 15:50 - 16:15 0.42 STWHIP WEXIT 16:15 - 16:40 0.42 STWHIP P WEXIT Stab onto well, test eline tools, failed test. Unstab, troubleshoot tools. Restab. Electronic counter on injector not working, troubleshoot. Trouble swapping Anadrill's encoder with BHl's encoder. RIH with BHA #2, open circ sub. Start sending Used Flo-Pro down while RIH, pump 35bbls, shut down pumps. Cant. RIH. CT Vol with eline=40.75bbl Tie in. Start logging down at 1101 O'md at 3.2fpm. Still not pumping. Correct depth, subtract 29' to correct to Geology PDC. Yesterday we subtracted 20' to the pinch point on the whipstock. PROD1 Close Circ sub. Continue RIH pumps off. RIH wt=13500 Ibs above window. Bobble, briefly get back wt at 11130'md probably top of window, Tag TD at 11, 144'md. PU off bottom, 16:40 - 16:55 0.25 STWHIP P WEXIT 16:55 - 17:10 0.25 STWHIP P WEXIT 17:10 - 18:00 0.83 STWHIP P WEXIT 18:00 - 21 :00 3.00 STWHIP P WEXIT 21 :00 - 21 :30 0.50 STWHIP P WEXIT 21 :30 - 00:00 2.50 STWHIP P WEXIT 2/9/2003 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 02:00 0.50 STWHIP P WEXIT 02:00 - 02:40 0.67 DRILL P PROD1 02:40 - 03:40 1.00 DRILL P PROD1 03:40 - 04:40 1.00 DRILL P PROD1 04:40 - 08:00 3.33 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 09:30 0.50 DRILL N DFAL PROD1 09:30 - 10:15 0.75 DRILL N SFAL PROD1 10:15 - 12:26 2.18 DRILL P PROD1 12:26 - 13:00 0.57 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P Milling 11,133.5 See ROP increase. BOW? Milling 11,133.7 1835psi/1.6/1.6bpm. Sand in samples. Drilling break, call this bottom of window. TOW=11129.4, BOW=11, 133.7 Unable to get clean vacs for swapping mud prior to POOH (9 trucks on S pad, 4 trucks on cement job). Plan to swap to FloPro with drilling bha on bottom. 11136.5, 1765psi 1.6/1.6 ROP=0.2fpm in OH. Let off break, mill formatiion to 11144.6 (10' past bottom of window) at 60fph. Still getting 1: 1 PU to backream, clean pickup, pick up wt = 30K Lbs. circ press off bottom=1760psi 1.6/1.6bpm See motor work at 11133.4, park, allow mill to work. PU thru window at .6fpm, 1780psi 1.6bpm. See small amts. of motor work at 11132.8, 11131.1,11129.4 Run back down thru window to 11139'. 1725psi, 1.6bpm, 0.9fpm, very little motor work. PU, backream up thru window at 0.5fpm, 1770psi, 1.6bpm. Run back down thru window. PU thru window backreaming a third time. Dry pass O.K. POH. Mills in gauge. Freeze protect coil with methanol. Cut coil connector, Install grapple in end of coil. Unable to get full engaugement of grapple. Pull tested to 2000#. Pull end of coil back to reel and secure. Continue to secure. Cut off grapple prep end of coil and cap coil. Lower the reel to trailer. Operation went well. Raise E line coil into reel house. Remove plug and grapple connector. Install grapple and tugger line. Need to look into grapple appears the grapple was for thinner wall pipe unable to get full engaugment. Pull coil over the pipe shed thru injector in ( 5 minutes) worked great. Cut off grapple. Megger cable. O.K. Install kendle eline coil connector. Pull test. Rehead. Reheading taking a bit longer than expected. Displace methanol from eline CT. IA=5, OA=35 PU Baker Inteq Eline BHA, 2.5deg Baker X-treme motor, Used Hycalog 2.67" x 3" bicenter(from Lisburne). BIT to GR= 26.74', to Survey=27.59', to CCL= 44.86', to NB INC. =12.84' Printed: 2/24/2003 10:31:23AM ) BPEX.PLORATION ppe.rations·.·.SummaPj.·.·Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date From -To Hours Task Code NPT 2/9/2003 13:00 - 14:00 1.00 DRILL P PROD1 Description of Operations start pumping. Freespin=2720psi at 1.55bpm. IA=100, OA=80psi (Weather upgraded to Phase 2, drifting again on the pad) Start drilling, 3100psi 1.6/1.6bpm ROP=25fph, WOB= 6501bs, Annular pressure=4300psi DFAL PROD1 Troubleshoot orientor, unable to hold TF. Likely in a bind across whipstock and 2.7" hole. PROD1 Drilling, 11165'md. 3700psi, 1.7/1.7 30-40fph WOB=2300Ibs. [Traction motor on Mud pump unable to maintain constant rate when motor work increaes, acts like it is bogging down. Watch the rate drop 0.3-0.4 bpm on its own. Makes it tough to decipher what is going on and how much motor work we are getting. Ideally we would like to see constant rate from our mud pumps. (This same problem also made our window milling parameters less obvious yesterday.) Schlumberger/Nordic looking for a fix. This phenomena is more noticeable with 2" CT] Stall at 11170', PU. Resume drilling. Pull up above whipstock to see if we can get orientor to respond inside 3-3/16". No good. Trouble shoot mud pump controls with electician. RBIH to one last time to see if we can get Orientor to respond. Orientor is completely out the window. POH for non-responsive orientor. EOP FLAG @ 10250'. Trouble shoot pumps as we poh. Try one more time at getting orientor to respond inside 4-1/2" liner, no good. Continue POH. LD BHA and trouble shoot Orienter. Checked out OK at surface. Will send to shop where they can check torque output of orienter. MU BHA #3 build assembly. New orienter and bit. Stab onto well RIH to flag. Correction -26'. Log to RA no additional correction. Directionally drill 1.62/1.68 @ 3450 psi. 3300 psi FS. DH annular pressure 4571 psi DH tubing pressure 5094 psi @ 8,786 TVD. drill to 11,208'. Directionally drill 1.66/1.66 bpm @ 3500 psi. FS 3300 psi. DH annular 4562 psi, DH tubing 5008 psi. 2K WOB, ROP 18. drill to 11245'. Drilling break ROP increased 40-60 ft/hr. Drill to 11,300'. Directionally drill 1.64 /1.64 bpm at 3,500 psi 3,300 psi FS, DH annular 4,602 psi, DH tubing 5,234 psi. at 8,850' tvd, WOB 1,700#, ROP 46. Tech limits/Safety meeting. Discuss plan forward, lessons learned, HSE issues. Drilling 1.7/1.7bpm, 3420psi, 25-30fph, 2140lbs WOB, DH Annular=4610psi, ECD=10ppg. Drill build to 11392'md. ROP increasing at 11396'md. [JA=433, OA=122psi] Weather graded PHZ 3 on pad, PHZ 2 on main roads, discuss operational risks w/ drilling team, plan to keep pad access open with rig loader to manage risk. PROD1 Drilling 1.7/1.7bpm, 3450psi, 50-60fph, 11 ,466'md. Wt transfer falling off. PROD1 100' short trip to improve wt. transfer. 14:00 - 14:25 0.42 DRILL N 14:25 - 15:15 0.83 DRILL P 15:15 - 15:35 0.33 DRILL N DFAL PROD1 15:35 - 15:50 0.25 DRILL N SFAL PROD1 15:50 -16:15 0.42 DRILL N DFAL PROD1 16:15 -18:00 1.75 DRILL N DFAL PROD1 18:00 - 19:33 1.55 DRILL N DFAL PROD1 19:33 - 20:15 0.70 DRILL N DFAL PROD1 20:15 - 22:20 2.08 DRILL N DFAL PROD1 21 :30 - 00:00 2.50 DRILL P PROD1 2/10/2003 00:00 - 05:00 5.00 DRILL P PROD1 05:00 - 06:30 1.50 DRILL P PROD1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 09:00 2.00 DRILL P PROD1 09:00 - 11 :00 2.00 DRILL P 11:00-11:15 0.25 DRILL P Printed: 2/24/2003 10:31 :23 AM , . ) ) BP..EXPLORATION Operations .Summary·Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date From~·To Hours Task Code NPT Phase Descri ptionofOperations 2/10/2003 11:15-11:30 0.25 DRILL P PROD1 Drilling, Land build at 11470'md, 90deg inc. 11 :30 - 13:00 1.50 DRILL P PROD1 POH to window at 1.7bpm, 20fpm conditioning hole. Hole in good condition. Open circ sub inside 3-3/16" liner: Continue POH to surface. 13:00 - 15:00 2.00 DRILL N WAIT PROD1 Wait for roads and pads and Nordic 2 loader to clear a path to the oxbow road prior to resuming operations. 15:00-15:15 0.25 DRILL P PROD1 Continue POH 15:15 - 15:30 0.25 DRILL P PROD1 PJSM prior to laying down tools. Discuss job roles and good communication. 15:30 -16:15 0.75 DRILL P PROD1 Unstab, inspect build assembly. Adjust motor to 1.1 deg, PU new Hycalog DS100. 16:15 - 17:30 1.25 DRILL N DFAL PROD1 Find short in Eline BHA on surface test. Troubleshoot. Short in lower quick connect. Change out lower quick connect and flow sub on upper quick connect. 17:30 -19:30 2.00 DRILL P PROD1 RIH with BHA #4 lateral assembly. 1.1 deg X-treme motor, new Hycalog DS100 3" bicenter. 19:30 - 20:40 1.17 DRILL P PROD1 Tie-in to RA tag correction (+14'. Tag deep 40' had a Gamma ray spike that fooled us. Retied in -38') net -24'. 20:40 - 20:50 0.17 DRILL P PROD1 RIH tag 11,472'. 20:50 - 23:30 2.67 DRILL P PROD1 Directionally drill 1.7 /1.7 bpm @3600 psi FS = 3300 psi Up 28,000# Dn 12,000# WOB 3K, Rap 27, HD annular pressure 4,632 psi DH tubing pressure 5,078 psi at 8891' TVD. Stacking mud .7 % solids. call for new mud. Drill to 11,620'. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip to window. No problems 2/11/2003 00:00 - 02:00 2.00 DRILL P PROD1 Directionally drill 1.65/ 1.68 bpm @ 3,666 psi 3,300 psi FS. Up 28,000# Dn 12,000# WOB 3K, Rap 40-60, DH annular pressure 4,672 psi DH tubing pressure 5,792 psi at 8891' TVD. Wiper tripped improved sliding greatly. drilled to 11,770'. Mud Swap. 02:00 - 02:30 0.50 DRILL P PROD1 Wiper to window. No problems smooth trip. 02:30 - 05:00 2.50 DRILL P PROD1 Continue to directionally drill 1. 71 / 1.71 bpm at 3,450 psi. FS 3,300 psi. Up 28,000# , DN 12,000#, WOB 4, Rap 60-80,DH annular pressure 4,600 psi, DH tubing pressure 5,279 psi. New mud improved weight transfer. Drill to 11,920' 05:00 - 05:40 0.67 DRILL P PROD1 Wiper to window. 05:40 - 06:30 0.83 DRILL P PROD1 Continue to directionally drill 1.71 /1.71 bpm at 3,450 psi. FS 3,300 psi. Up 28,000# , DN 12,000#, WOB 3-4, Rap 60-80. 06:30 - 08:45 2.25 DRILL P PROD1 Drilling, drop inclination to follow down dip as per geo. 1.7/1.7 bpm 3,400psi, Inc=89deg. FREESPIN= 3,250psi, DH tubing = 4,920, DH Annular = 4,615....305psi pressure drop across orientor, motor and bit, with new FloPro. Drill to 12,038' md. Start stacking wt. 08:45 - 09:05 0.33 DRILL P PROD1 Short trip, wiper to 11,947'. 09:05 - 10:05 1.00 DRILL P PROD1 Drilling, 3,450 - 3,500psi 1.7/1.7bpm. Drill to 12,083' md. 10:05-11:15 1.17 DRILL P PROD1 Wiper to window. 11 : 1 5 - 12: 00 0.75 DRILL P PROD1 Drilling, plan to stay horizontal and when we see GR coming up, start climbing with predicted dip. Drill to 12,127' md. 12:00 - 13:30 1.50 DRILL P PROD1 Drilling 1.7/1.7 bpm 3,500 psi, FS 3,200 psi. DH inner annulus pressure 4,595 psi, DH tubing pressure 5,340 psi UP 29,000# DN 13,000# WOB 2, Rap 45-60. 13:30 - 14:30 1.00 DRILL P PROD1 Wiper to window. 14:30 - 17:00 2.50 DRILL P PROD1 Drilling 1.6 / 1.6 bpm 3,650 psi, FS 3,200 psi. DH inner annulus Printed: 2/24/2003 10:31 :23 AM ) ) BPEXPLORATION Operations Summary Report Page.5,oftO Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/11/2003 14:30 - 17:00 2.50 DRILL P PROD1 pressure 4,595 psi, DH tubing pressure 5,420 psi UP 29,000# DN 13,000# WOB 3-4, ROP 40-80. 17:00 - 18:45 1.75 DRILL C PROD1 Wait on decision from town regarding side track for geologic reasons. 18:45 - 20:45 2.00 DRILL C PROD1 POH for open hole side track geological sidetrack. 20:45 - 22:00 1.25 STKOH C PROD1 LD drilling BHA and PU open hole whipstock. 22:00 - 00:00 2.00 STKOH C PROD1 RIH to tie-in. 2/12/2003 00:00 - 00:30 0.50 STKOH C PROD1 RIH to 11,140' tie -in 00:30 - 00:50 0.33 STKOH C PROD1 Tie in (-28' correction) 00:50 - 01:10 0.33 STKOH C PROD1 RIH to 11,934. UP wt 30,000# SO 10,000#. Top of whipstock at 11,920'. Close EDC. Pressure to 5000 psi at .18 bpm. See no shears. PU to Set wt of 30,000. Slacked off to 2000#. Took weight. 01: 1 0 - 03:00 1.83 STKOH C PROD1 POH. 03:00 - 04:00 1.00 STKOH C PROD1 LD whipstock running tool and PU drilling BHA#4. 04:00 - 05:45 1.75 STKOH C PROD1 RIH to tie in depth. No problem getting thru window with 2.76" bit. 05:45 - 07:45 2.00 STKOH X SFAL PROD1 Surface software troubles. Rebuild system. 07:45 - 08: 15 0.50 STKOH C PROD1 Log tie-in at RA. Correct depth (-25'). 08: 15 - 08:45 0.50 STKOH C PROD1 RIH and tag AI billet at 11,922' corrected. 08:45 - 10:15 1.50 STKOH C PROD1 Time mill first 1.5' (grabby getting started). Not getting TF updates. Confirm electronic failure in orienter. 10:15 - 11 :45 1.50 STKOH C PROD1 Orienter started working again. Time mill to 11930'. 11:45 - 14:20 2.58 DRILL C PROD1 Drill ahead to revised 8,879 TVD target -- got there at 12,082' but not in sand here. 14:20 - 16:00 1.67 DRILL C PROD1 Wiper trip while WOO. 16:00 - 16:45 0.75 DRILL C PROD1 Drill 1.6/1.6 bpm at 3,350 psi FS = 3,300 psi Up wt 29,000#, DN wt 12,000#, WOB 2K, ROP 40-70. DH annulus pressure 4,590 psi. DH tubing pressure 5,300 psi. 16:45 - 19:00 2.25 DRILL C PROD1 Wiper to window. 12,180'. 19:00 - 21:40 2.67 DRILL C PROD1 Drill 1.6/1.6 bpm at 3,350 psi FS = 3,300 psi Up wt 29,000#, DN wt 12,000#, WOB 2K, ROP 40-70. DH annulus pressure 4,611 psi. DH tubing pressure 4,955 ps. Drill to 12,250 Having trouble with weight transfer. Mud only .2% solids will bring lubtex from 3% to 4%. 21 :40 - 22:40 1.00 DRILL C PROD1 Wiper to Window. 22:40 - 00:00 1.33 DRILL C PROD1 Attempting to drill Stacking. Drill 1.7/1.7 bpm at 3,380 psi FS = 3,100 psi Up wt 30,000#, DN wt 12,000#, WOB 1-2K, ROP 15-40. DH annulus pressure 4,630 psi. DH tubing pressure 5,400 psi. 2/13/2003 00:00 - 01 :00 1.00 DRILL C PROD1 Drill 1.7/1.7 bpm at 3,350 psi FS = 3,300 psi Up wt 30,000#, DN wt 12,000#, WOB 2-4K, ROP50-100. DH annulus pressure 4,630 psi. DH tubing pressure 5,400 psi. Drill to 12,344' stacked out. 01 :00 - 02:00 1.00 DRILL P PROD1 Wiper to window. Set down at 12,260' went thru on second attempt. Tag at 12,346'. 02:00 - 07:00 5.00 DRILL P PROD1 Stacking out. Work pipe. Drilling at 1.6/1.6 bpm at 3640 psi. UP Wt 30,000# DN WT 12,000#. WOB 2-3. ROP 50 -100. Stacking continues to be an issue but once we get drilling progress is good. Drill to 12536'. 07:00 - 08:00 1.00 DRILL P I PROD1 Wiper to window. Hole in good shape on this up pass. 08:00 - 08:20 I 0.33 DRILL P PROD1 Log tie-in at RA. No correction. 08:20 - 09:15 0.92 DRILL P PROD1 RIH at 90R TF (drilled at 90L). Hole smooth up to 12230', then Printed: 2/24/2003 10:31:23AM ) ) Legal Well Name: 07 -29 Common Well Name: 07-29 Spud Date: 2/14/1988 Event Name: REENTER+COMPLETE Start: 2/5/2003 End: 2/18/2003 Contractor Name: NORDIC CALISTA Rig Release: 2/18/2003 Rig Name: NORDIC 2 Rig Number: Date From-To Hours Task Code NPT Phase Descri ption . of Operations 2/13/2003 08:20 - 09: 15 0.92 DRILL P PROD1 ratty weight and increase in CTP by about 25 psi. Hard set downs 12230',12250',12300' without any change in CTP. Swap TF to 90L and continue RIH with ratty weight. Sat down 12370', again with no bit work. RIH to TD. Tag 12532'. 09: 15 - 10: 15 1.00 DRILL P PROD1 RIH weight at TD = 10k. Try and get started -- stack, stack, stall. Very poor slide on bottom, then lose ground. Very high friction. Backream a couple times the length of the BHA. Drill to 12545'. Then lost ground again, losing BHA movement off bottom. Requires a higher running speed to get to bottom. 10:15 -11 :15 1.00 DRILL P PROD1 Wiper while mixing a 5% Flo-Lube pill (2 drums in 50 bbls mud -- which is currently at 4% lubetex). 11:15-12:00 0.75 DRILL P PROD1 Try drilling with pill on the backside -- no progress. Corrected TD 12546'. 12:00 - 14:30 2.50 DRILL P PROD1 Ream 12200' - 12350' at several different TF's. While there was little to no motor work, the area did clean-up (RIH wts lessy ratty and no set downs). Lay in new 25 bbl Flo-Pro pill on bottom (3% lubetex; 5% flo-Iube; otherewise same properties). 14:30 - 19:00 4.50 DRILL P PROD1 POOH at 2.0 BPM, circ sub open. Change over top well to KCL. Freeze protect coil. LD BHA. 19:00 - 20:00 1.00 CASE P COMP Cut off connector. The 1.75 grapple wouldn't stab replaced it with split grapple and install grapple in end of coil. O.K. 20:00 - 20:30 0.50 CASE P COMP PJSM pulling coil back. 20:30 - 21 :30 1.00 CASE P COMP Pull coil back and secure on reel. Release grapple. Plug coil. Set back injector. 21:30-22:10 0.67 CASE P COMP Rig up floor to run liner ( beginning of simultaneous operation with coil swap) 22:10 - 22:30 0.33 CASE P COMP PJSM for running liner. 22:30 - 23:20 0.83 CASE P COMP PU liner drifting each connection. Taking initially 3.5 min per connection. 23:20 - 23:30 0.17 CASE P COMP PJSM with PEAK for coil swap out. 23:30 - 00:00 0.50 CASE P COMP Continue simultaneous operations. Liner running and coil Swap. Simultaneous operations terminated at midnight. Coil swap completed incident and accident free. 43 of 69 joints of 2-3/8 STL liner picked up by 23:59. 2/14/2003 00:00 - 03:00 3.00 CASE P COMP Continue to run liner. 03:00 - 03:15 0.25 CASE P COMP PJSM pull coil to injector. 03:15 - 04:00 0.75 CASE P COMP Pull test grapple. Remove coil restraint. Pull coil to injector and stab into injector. 04:00 - 06:00 2.00 CASE P COMP Make up coil connector and pull & pressure test. Circulate out freeze protection from coil, pumping dart to check MM. Bump at 40.2 bbls (vs 41.4 theoretical). MU coil to CTLRT. 06:00 - 10:00 4.00 CASE P COMP RIH with liner. Wt check at 10250' -- 28k and 13k. 0.5; 1640 psi. RIH. Smooth until about 11800', then weight started getting ratty. From 11975' to TD slow going, making progress in 0' - 20' steps before reaching max negative weight and requiring PU. Unable to work past 12558' uncorrected. Can't work past this depth -- probably bottom. 32k up. Check circulation: 0.45/0.45 and 1850 psi. 10:00 -10:30 0.50 CASE P COMP Stack to -1 Ok. Drop 5/8" ball and pump to seat at 1.7/1.7; 4000 psi. Ball on seat at 32 bbls. Shear at 3700 psi. Pump at 0.5/0.5 BPM, 1870 psi. PU to make sure we are free. 21 k. Off liner. 10:30 - 12:30 2.00 CEMT P COMP Displace well to 2% KCL. Safety meeting with cementers. Printed: 2/24/2003 10:31 :23 AM ') ) BPEXPLORATION Operations,. Summary '. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date From-To Hours Task Code NPT Phase Description of Operations 2/14/2003 10:30 - 12:30 2.00 CEMT P COMP Seeing some losses: 1.7/1.4; 3950 psi CTP final circ conditions. Lower rate to check losses -- 1.12/.86; 1860 psi. 12:30 - 14:15 1.75 CEMT P COMP Mix cement. At weight -- 12:45. PT lines to 4000 psi with KCL water. Load 12.5 bbls of 15.8 ppg Class G cement into the coil. Load and launch coil dart, verify it's gone. Chase cement with 30 bbls of 1.5 ppb biowater using rig pump. Displace cement at 1.8/1.4 initial, 1.7/1.5 when cement turned the corner. Reduce rate to 1.0/0.9 BPM about 2 bbls before latch-up. Latch up at 40.0 bbls, shear LWPat 4000 psi. Chase LWP to latch collar at 0.8/0.7 and 4000 psi initial, but losses increased gradually to 0.82/0.25 and 4000 psi final. Bump plug at 48.5 bbls right on the money. Pressure to 4400 psi. Bleed to check floats. LOST 3.2 BBLS CEMENT TO FORMATION DURING JOB. Pressure CT to 500 psi. Unsting. 14:15 - 16:15 2.00 CEMT P COMP POOH, laying in remainder of the bio water at < 0.5 BPM. POOH, maintaining a trickle of returns. 16:15 - 16:30 0.25 CEMT P COMP LD liner running tool. 16:30 -17:00 0.50 CLEAN P COMP Safety meeting. 17:00 - 18:30 1.50 CLEAN P COMP MU 36 stands + one single of 1" CSH on motor/mill. 18:30 - 20:45 2.25 CLEAN P COMP RIH to 12,562'. No motor work smooth sailing all the way. 20:45 - 00:00 3.25 CLEAN P COMP POH circulating at 1.1 bpm 55 fph until returns cleanup. Return density as high as 8.9 ppg . POH. 2/15/2003 00:00 - 00:15 0.25 CLEAN P COMP Continue to POH, diverting contaminated cement to cuttings tank. 00: 15 - 02:30 2.25 CLEAN P COMP Drop ball open circulation sub. Stand back 1" CSH. LD BHA. 02:30 - 03:00 0.50 EVAL P COMP Clear floor. 03:00 - 03:30 0.50 EVAL P COMP PU logging tools. 03:30 - 03:45 0.25 EVAL P COMP PJSM for installing radioactive source. 03:45 - 05:00 1.25 EVAL P COMP RIH with 1" CSH. 05:00 - 06:45 1.75 EVAL P COMP Stab injector and RIH. 06:45 - 08:00 1.25 EVAL P COMP Log down at 60 FPM starting at 10200'. Sat down twice at top of liner 10343'. Work thru. Log down to PBTD at 12552' uncorrected depth. Log out of hole at 60 FPM, laying in 15 bbls of new high vis Flo-Pro mud in liner. 08:00 - 09:15 1.25 EVAL P COMP POOH to 7000'. Cement check: lab sample at 2500 psi. Pressure test hole to 2100 psi. 09:15 - 09:30 0.25 CEMT P COMP Cement check: lab sample at 2500 psi. Pressure test hole to 2100 psi. lAP = 300; OAP = 100. Good flatline test -- bled 20 psi in 15 minutes. 09:30 - 10:15 0.75 EVAL P COMP POOH. 10:15 - 12:00 1.75 EVAL P COMP Stand back 19 stands CSH; LD remaining 35 joints in singles. 12:00 -12:15 0.25 EVAL P COMP Safety meeting. 12:15 -12:45 0.50 EVAL P COMP LD logging tools, clear floor. Download data -- some CNL data missing/noisy. GRlCCL log looks good. Fax to Stephan. CORRECTED LINER TOP = 10304'. CORRECTED PBTD = 12535' . 12:45 -17:30 4.75 BOPSURP COMP Pressure test BOPE. Witness waived by AOGCC's John Spaulding. 17:30 - 18:30 1.00 PERF P COMP RU floor to run perforating guns. 18:30 -19:00 0.50 PERF P COMP Tech Limits and PJSM for picking up perforating guns. 19:00 - 21 :20 2.33 PERF P COMP PU perforating guns. 21:20 - 22:15 0.92 PERF P COMP PU 19 stands of 1" CSH. 22:15 - 22:30 I 0.25 PERF P COMP Stab injector on to well and test reel valve. Printed: 2/24/2003 10:31 :23 AM ') ) BPEXPLORA TION OperatiOns,.··Sumrné),ry'.,.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Date From>-To Hours Task Code NPT 2/15/2003 22:30 - 00:00 1.50 PERF P CaMP 2/16/2003 00:00 - 00:30 0.50 PERF P CaMP 00:30 - 00:50 0.33 PERF P CaMP 00:50 - 03:00 2.17 PERF N STUC CaMP 03:00 - 04:30 1.50 PERF N STUC CaMP 04:30 - 05:00 0.50 PERF N STUC CaMP 05:00 - 05:30 0.50 PERF N STUC CaMP 05:30 - 07:30 2.00 PERF N STUC CaMP 07:30 - 08:30 1.00 PERF N STUC CaMP 08:30 - 09:45 1.25 PERF N STUC CaMP 09:45 - 11:45 2.00 PERF N STUC CaMP 11:45 - 12:30 0.75 PERF N STUC CaMP 12:30 -14:00 1.50 PERF N SFAL CaMP 14:00 - 14:30 0.50 PERF N STUC CaMP 14:30 - 15:00 0.50 PERF N SFAL CaMP 15:00 - 17:00 2.00 PERF N STUC CaMP 17:00 - 19:00 2.00 PERF N STUC CaMP 19:00 - 20:30 1.50 PERF N STUC CaMP 20:30 - 21 :00 0.50 PERF N STUC CaMP 21 :00 - 22:30 1.50 PERF N STUC CaMP 22:30 - 00:00 1.50 PERF N STUC CaMP 2/17/2003 00:00 - 00:30 0.50 PERF N STUC COMP 00:30 - 02:00 1.50 PERF N STUC CaMP Description of Operations RIH. Tag at 12,535 (corrected) PU 15' and drop .5" ball. UP wt 30K DN wt 13 K. Circulate ball to firing head at 1.8 bpm. Slow pump to .9 bpm. @ 1,060 psi. Pressure to 3000 psi. Guns appeared to fire. Stuck! Pull to max 30K over with and without circulation. Slack off to -9K NO GO. Hold 30K over wait 10 min -- NO GO. Discuss options with town. Discuss fishing options with BOT. Smallest jars on slope are 2-1/8" O.D. Mix 6% Lubtex pill in 30 bbl pill and circulate to annulus. Pull 60K (30 over) and hold. No go. Shut in backside and pressure to 1000 psi. Shut down bleed off to formation slow. Thick Flo Pro perf pill probably the cause for slow bleed off. SO to zero weight. Bleed off pressure fast. No Go. Contact Anchorage discuss options. Will disconnect above preforating guns and lay in lub pill prior to POH for fishing assy. Drop 5/8" ball to disconnect. Chase ball with lub pill to lay in above fish. Disconnect from perf gun fish. POH. Stand back CSH. LD top half of CSH. MU hyd spear and 18 stands CSH. Check/tighten all middle tool joints. MU 2-1/4" jars, two weight bars, accelerators, MHA. RIH. SD pumps in liner to keep slick pill in place. 28k up; 16k down. Latch fish at 11,400'. Jar pipe up for 18 hits setting max of 48k for jar licks (limit on jars) -- kind-of weak hits, and jars going off early most of the time at about 42k. No movement. Line up on backside to bullhead the slick lube pill down around guns and to perfs (we hope there are some perfs). Unable to pump down kill line -- frozen. PU above pill. Bullhead 4 bbls pill into perfs via coil: breakdown at 2050 psi, then inject at stable 0.57 BPM; 1600 psi for 3.5 bbls; then pressure climbed back to 2000 psi as we were finishing up the 4.0 bbls. SD and bleed. RIH. Latch FN at 11390' (took a few tags to latch). Jar 5 more times and something shucked loose. No weight change. Try to latch up about 6 more times. Couldn't. Want to POOH filling so we don't lose any clues what might be hanging on. Thaw kill line. POOH filling through kill line. Unstab inj. LD jars. Standback CSH. Lower disconnect sheared. Wait on fishing tools, Cut coil, PJSM change out BHA. Run 18 stands of 1" CSH. Check middle connections on all stands. Stab on to well with injector. Pump 30 bbl pill into coil while running in hole. Continue to RIH with out pump to top of fish. (Pill = 30bbl + 2drums lubtex + 2 buckets Flo-vis) Continue to RIH to top of fish. Tag at 11,406' Up wt 30K, Dn Wt 9K. Spot 20 bbl of pill in annulus. Tag latch onto fish 11,406 DN . Shut-in backside bullhead .5 bpm pressure ramped up to 2600 psi and broke back to 2000 psi jar Printed: 2/24/2003 10:31 :23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02:00 - 04:00 04:00 - 04: 15 04:15 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 13:30 13:30 - 15:30 15:30 - 18:00 18:00 - 21 :00 ) BPEXPLORATION Operations "Sum mary Report 07-29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 2.00 PERF N 0.25 PERF N 1.75 PERF N 1.00 PERF N STUC CaMP STUC CaMP STUC CaMP STUC CaMP Date Frorn"To Hours Task COde NPT Phase 2/17/2003 00:30 - 02:00 1.50 PERF N STUC CaMP 1.00 PERF N STUC CaMP 1.00 PERF N STUC CaMP 4.50 PERF N STUC CaMP 2.00 PERF N 2.50 PERF N STUC CaMP STUC CaMP 3.00 PERF N STUC CaMP Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Descri ptionofOperations down -6K. Jar 6 licks No results. Jar up while continue to bull head. Not seeing alot of jar action. Jars firing fast. After bullheading 20 bbl. Bleed off wellhead pressure (1200 psi) fast while continueing jarring. NO GO. Up jarring progressed from 20K over incrementally increasing to 30K over. Fishing neck of disconnect is limiting factor on overpull to 30K over. NO sign of any movement. Total of 23 lick up 9 down. Will save some coil life for jarring with N2. Wait on N2. Holding 28K over. PJSM addressing RU issues for N2 job. RU hardlines to N2 unit. PJSM pumping N2, Reviewed Muster Areas, PT, Flow back tank RU, Compressed gases hazards, N2 gas leaking response. This job has NO time critical issues. We can shut it down any time. Bullhead 30,000 SCF N2 down kill line at 1000 SCF/min. 1850 psi WHP initial; 2100 psi WHP final. Tank shows 422 gallons pumped, which doesn't jive with the 30,000 number. Also, SICTP = 1300 psi; SIWHP = 1950. The difference between these numbers also doesn't jive with the 422 SCF or 30,000 SCF. Bleed WHP to flowback tank while jarring down -- didn't get any jar hits, at some point we must have released from fish. WHP bled down quickly and smoothly to 100 psi-- hatch covers on flowback tank did a little fluttering, otherwise noneventful. Latch back up with fish. Regroup, crunch numbers, and revise plan. Keep bind on fish for all circulating. Bullhead N2 down kill line again in stages, checking SICTP and SIWHP at each step to determine BS fluid level. Bullhead 150,000 SCF (1100 gallons) down kill line. 1800 psi SI differential. SICTP and SIWHP suggests fluid level about 4300'. Bleed WHP to zero (and bleed CTP to keep differential off hyd spear -- to keep it latched in) to flow back tank. Jar down once, PU and jars went off on up, RIH and jar down once again, PU not latched, RIH and jar down 4 more times (able to cock jars even though we are not latched) and guns broke free. Push guns to bottom easily -- about 15'. Unable to latch up FN after numerous times. SI WHP built to 550 psi. Circulate kill well on choke. Attempt to latch fish -- can't get it. Start POOH to check fishing tools. Must have something on, started seeing ratty weight 11 ,200ish, then pulled heavy to 60k at 11,120'. Drag heavy, with a few jar hits up, to 11,092' (spear depth). Unable to work up past here with several jar hits up. Try to work free going down. Move it down to 11094' -- then no more progress. Jar down over 30 times -- no progress. Jar up a couple of times -- got it moving again. Pull to 11,060' and hung up here. - got it moving again. NOTE: HITTING TIGHT SPOTS EVERY 30' (PULLING THROUGH LINER TOOL JOINTS??). Pull to 11,030' and hung up here. Hold 23k over while circulating to warm coil. Continue jarring up and down. Pressure up backside to 2200 psi. Shut down pump holding pressure. Jar down. Free down. Unable to pull up. Printed: 2/24/2003 10:31 :23 AM ) ) BPEXPLORATION Operáti onsSul11rna ry ..,Repo rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From -To Hours Task Gode' ... NPT Phase 2/17/2003 18:00 - 21 :00 3.00 PERF N STUC CaMP 21 :00 - 23:30 2.50 PERF N STUC CaMP 2/18/2003 23:30 - 00:00 00:00 - 00:15 STUC CaMP STUC CaMP 0.50 PERF N 0.25 PERF N 00:15 - 01:00 0.75 PERF N STUC CaMP 01 :00 - 03:20 2.33 WHSUR N WAIT CaMP 03:20 - 04:30 1.17 WHSUR N WAIT CaMP 04:30 - 05:30 1.00 WHSUR P CaMP 05:30 - 06:30 1.00 RIGD P POST 06:30 - 15:00 8.50 RIGD P POST 15:00 - 17:30 2.50 RIGD N WAIT POST 17:30 - 20:30 3.00 RIGD N POST Start: 2/5/2003 Rig Release: 2/18/2003 Rig Number: Spud Date: 2/14/1988 End: 2/18/2003 Description of Operations Retry losing ground. Lost total of 56'. Attempt to circulate no returns. Packed off. Attempt to release hydraulic GS to circulate sweep. Pumping down coil at 4300 psi @ .9 bpm. Pick up. Pressure dropped to 800 psi rate increased to 1.2 bpm. Attempted to relatch set down. Seen presure increase to 3090 psi but unable to relatch. Something is broken. Circulate high vis sweep. Prior to POH to CSH. Injected 3 bbls at .5 bpm at 2250 psi. POH. Un sting from well. Set back injector. Found upper hydraulic disconnect released. Most probable cause jarring weakened pins. Total length of Fish = 2,258' (1133' guns,Lower dicsonnect, Baker GS shear ,XO, 1120' 1" CSH,XO,XO, Lower Hydraulic disconnect) with top of fish at 9,955' CTD. Reviewed fishing options. 1) Wait on special built 0 ring seal sub leaving us with 2 hydraulic disconnects in the bha with uncertainies regarding which would release first or 2) Latch fish and pull to failure. Weak point is the fishing neck on the lower disconnect. Discussed with CTD manager. Decided to terminate fishing operations. RIH with nozzle to freeze protect to 2000'. Methanol trailer valving frozen. Thaw valve Freeze protect well to 2000' and reel with 60/40 methanol while pulling out of hole. 60/40 methanol is 40/60 according to the MM. Called for more 60/40. Freeze protect well to 2000' with 60/40. POOH. Rig down. Unstab coil and pull//secure to reel, nipple down BOPE, NU and PT tree cap. change out reel, start cleaning pits. Waiting on vac truck to finish cleaning pits. Clean mud pits. Rig Released at 20:30 hrs 2-18-2003 Printed: 2/24/2003 10:31:23 AM , . ) ) BP Baker Hughes INTEQ Survey Report .,,,,,,',,,,,,, ,,,,,. ""..'.......... ..........."...... IN;IEQ Company: Field: Site: Well: Wellpath: BPAmoco Prudhoe Bay PB DS 07 07-29 07-29B Date: 3/27/2003 Time: 14:09:45 Page: Co-ordinate{NE) Reference: Well: 07-29, True North Vertical (TVD)Reference: 42: 292/14/198800:0065:0 Section (VS) Reference: Well (0.00N,O;00E,34.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft Latitude: Longitude: North Reference: Grid Convergence: 70 15 49.847 N 148 33 56.934 W True 1.35 deg Well: 07 -29 Slot Name: 29 07 -29 Well ,Position: +N/-S 2355.38 ft Northing: 5950464.69 ft Latitude: 70 16 13.010 N +E/-W -1471.51 ft Easting : 675855.79 ft Longitude: 148 34 39.770 W Position Uncertainty: 0.00 ft Wellpath: 07-29B 500292178202 Current Datum: 42 : 29 2/14/1988 00:00 Magnetic Data: 2/7/2003 Field Strength: 57544 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 07-29BPB1 11889.55 ft Mean Sea Level 26.00 deg 80.81 deg Direction deg 34.00 Height 65.00 ft Survey Program for Definitive Wellpath Date: 3/27/2003 Validated: Yes Actual From To Survey ft ft 42.00 11085.00 11085.00 11130.00 11130.00 11889.55 11919.66 12550.00 Version: 5 Toolcode Tool Name 1 : Schlumberger GCT multishot 2 : MWD - Standard (1) MWD (4) MWD GCT-MS MWD MWD MWD Schlumberger GCT multi shot MWD - Standard MWD - Standard MWD - Standard Annotation 8953.06 KOP 8943.69 TD Survey: MWD Start Date: 2/13/2003 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path .J ') ) BP Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 3/27/2003 Time: 14:09:45 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07 ~29, True North Site: PB OS 07 Vertical (TVD) Reference: 42 : 29 2/14/1988 00:00 65.0 Well: 07~29 'SeCtion (VS) Reference: Well (0.00N,0.00E,34.00Azi) Wellpath: 07-29B Survey Calculation Method: Minimum.Curvature Db: Oracle Survey MD Jncl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11889.55 90.28 40.27 8953.06 8888.06 6273.05 480.60 5956746.85 676189.66 5469.34 0.00 11919.66 87.76 42.36 8953.58 8888.58 6295.66 500.47 5956769.92 676209.00 5499.20 10.87 11949.62 95.04 39.55 8952.85 8887.85 6318.26 520.09 5956792.97 676228.08 5528.91 26.04 11978.09 95.57 44.04 8950.21 8885.21 6339.39 538.97 5956814.53 676246.4 7 5556.98 15.81 12005.25 96.18 48.44 8947.43 8882.43 6358.07 558.48 5956833.66 676265.53 5583.38 16.27 12039.36 93.14 53.15 8944.66 8879.66 6379.55 584.82 5956855.75 676291.36 5615.91 16.39 12070.27 90.00 58.66 8943.81 8878.81 6396.86 610.39 5956873.65 676316.52 5644.57 20.51 12100.30 89.94 66.13 8943.83 8878.83 6410.77 636.98 5956888.17 676342.78 5670.97 24.88 12131.72 88.90 68.71 8944.15 8879.15 6422.83 665.99 5956900.91 676371.49 5697.19 8.85 12150.56 90.00 73.20 8944.33 8879.33 6428.98 683.79 5956907.4 7 676389.15 5712.24 24.54 12180.07 92.95 76.01 8943.57 8878.57 6436.81 712.23 5956915.96 676417.39 5734.63 13.80 12210.34 93.35 80.10 8941.90 8876.90 6443.06 741.79 5956922.91 676446.80 5756.35 13.56 12240.33 90.18 84.14 8940.98 8875.98 6447.17 771.48 5956927.70 676476.38 5776.35 17.12 12270.09 84.28 85.77 8942.42 8877 .42 6449.78 801.07 5956931.01 676505.90 5795.07 20.57 12300.40 87.67 82.46 8944.55 8879.55 6452.88 831.14 5956934.81 676535.88 5814.45 15.61 12330.48 88.96 74.31 8945.43 8880.43 6458.93 860.56 5956941.55 676565.16 5835.92 27.42 12361.14 86.68 61 .40 8946.60 8881.60 6470.45 888.88 5956953.73 676593.20 5861.31 42.73 12390.58 89.85 55.27 8947.49 8882.49 6485.89 913.91 5956969.74 676617.86 5888.10 23.43 12420.05 91.97 50.94 8947.03 8882.03 6503.58 937.47 5956987.97 676641.00 5915.94 16.36 12452.54 92.95 48.63 8945.63 8880.63 6524.53 962.26 5957009.50 676665.28 5947.17 7.72 12480.23 93.53 45.43 8944.07 8879.07 6543.38 982.48 5957028.81 676685.06 5974.10 11.73 12500.50 90.58 42.09 8943.34 8878.34 6558.00 996.49 5957043.76 676698.72 5994.06 21.98 12520.03 89.35 39.88 8943.35 8878.35 6572.74 1009.30 5957058.79 676711.18 6013.44 12.95 12550.00 89.35 39.88 8943.69 8878.69 6595.74 1028.51 5957082.23 676729.85 6043.25 0.00 ) ) BP Baker Hughes INTEQ Survey Report ..............................,...,.. Company: BP Amoco Field: Prudhoe Bay Site: PB DS 07 Well: 07-29 Wellþath: 07-29BPB1 Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level (,Nl'EQ Date: 3/27/2003 Time: 14:03:50 Page: Co-ordinate{NE) Reference: Well: 07-29, True North Vertical (TV D) Reference: 42: 29 2/14/1988 00:0065.0 Section (VS) Reference: Well (0.00N,O.00E,7.72Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft Latitude: Longitude: North Reference: Grid Convergence: Alaska, Zone 4 Well Centre BGGM2002 70 15 49.847 N 148 33 56.934 W True 1.35 deg Well: 07-29 Slot Name: 29 07-29 Well Position: +N/-S 2355.38 ft Northing: 5950464.69 ft Latitude: 70 16 13.010 N +E/-W -1471.51 ft Easting : 675855.79 ft Longitude: 148 34 39.770 W Position Uncertainty: 0.00 ft Wellpath: 07-29BPB1 500292178271 Current Datum: 42: 292/14/198800:00 Magnetic Data: 3/27/2003 Field Strength: 57546 nT Vertical Section: Depth From (TVD) ft 0.00 Height 65.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Survey Program for Definitive Well path Date: 3/27/2003 Validated: Yes Actual From To Survey ft ft 42.00 11085.00 11085.00 11130.00 11130.00 12337.00 Version: Toolcode 1 : Schlumberger GCT multishot 2 : MWD - Standard (1) MWD GCT-MS MWD MWD Annotation 07 -29APB 1 11130.00 ft Mean Sea Level 25.95 deg 80.82 deg Direction deg 7.72 Tool Name Schlumberger GCT multishot MWD - Standard MWD - Standard MÐ Survey: MWD Start Date: 2/11/2003 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11130.00 49.64 25.13 8803.13 8738.13 5664.17 314.76 5956134.30 676038.11 5655.12 0.00 11160.07 48.10 15.94 8822.93 8757.93 5685.33 322.71 5956155.64 676045.56 5677.16 23.58 11190.02 46.20 6.27 8843.32 8778.32 5706.82 326.96 5956177 .22 676049.30 5699.02 24.49 11220.23 41.58 346.21 8865.20 8800.20 5727.51 325.75 5956197.87 676047.61 5719.36 48.34 11250.51 47.78 335.63 8886.75 8821.75 5747.52 318.71 5956217.72 676040.11 5738.25 31.93 11280.82 48.93 323.15 8906.93 8841.93 5766.93 307.20 5956236.85 676028.15 5755.94 30.97 11310.07 57.98 327.64 8924.34 8859.34 5786.28 293.92 5956255.88 676014.42 5773.32 33.29 11340.18 66.31 332.16 8938.40 8873.40 5809.30 280.62 5956278.58 676000.59 5794.35 30.67 11370.31 76.24 336.31 8948.06 8883.06 5834.97 268.27 5956303.96 675987.64 5818.13 35.44 11400.57 83.10 341.11 8953.49 8888.49 5862.69 257.48 5956331 .42 675976.21 5844.15 27.52 11430.77 88.16 348.90 8955.79 8890.79 5891.75 249.70 5956360.28 675967.76 5871.90 30.69 11462.00 90.12 8.32 8956.26 8891.26 5922.81 248.95 5956391 .32 675966.28 5902,58 62.49 ') ) BP Baker Hughes INTEQ Survey Report "".."".........,...........,,,............. IN'lliQ Company: BPAmoco Date: 3/27/2003 Time: 14:03:50 Page: 2 Field: Prud hoe Bay Co-ordinate(NE) Reference: Well: 07-29. True North Site: PB DS 07 Vertical (TVD) Reference: 42 : 292/14/198800:0065.0 Well: 07-29 Section (VS) Reference: Well (0.00N,O.00E,7.72Azi) WeJlpath: 07-29BPB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey 1\'10 Incl Azim TVD SSTVD N/S E/W MapN MapE \'8 DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11490.24 91.20 14.14 8955.94 8890.94 5950.50 254.45 5956419.12 675971.13 5930.76 20.96 11520.84 91 .44 17.78 8955.23 8890.23 5979.91 262.86 5956448.72 675978.85 5961.03 11.92 11550.05 91.11 24.32 8954.58 8889.58 6007.15 273.34 5956476.19 675988.69 5989.43 22.41 11580.35 90.89 26.90 8954.05 8889.05 6034.46 286.44 5956503.81 676001.14 6018.25 8.54 11610.15 90.40 30.14 8953.72 8888.72 6060.64 300.66 5956530.31 676014.75 6046.11 11.00 11650.41 90.52 35.62 8953.40 8888.40 6094.44 322.51 5956564.60 676035.80 6082.53 13.61 11680.34 91.38 39.06 8952.90 8887.90 6118.23 340.66 5956588.81 676053.39 6108.54 11.85 11710.19 89.72 42.66 8952.61 8887.61 6140.80 360.18 5956611.83 676072.38 6133.53 13.28 11743.14 88.55 47.09 8953.11 8888.11 6164.14 383.42 5956635.70 676095.06 6159.78 13.90 11770.31 88.80 47.64 8953.74 8888.74 6182.54 403.40 5956654.56 676114.61 6180.70 2.22 11800.38 91.47 43.89 8953.67 8888.67 6203.51 424.94 5956676.03 676135.65 6204.37 15.31 11 830. 13 91.60 39.11 8952.87 8887.87 6225.77 444.64 5956698.75 676154.82 6229.08 16.07 11 860. 11 88.68 34.82 8952.80 8887.80 6249.72 462.66 5956723.11 676172.28 6255.23 17.31 11889.55 90.28 40.27 8953.06 8888.06 6273.05 480.60 5956746.85 676189.66 6280.76 19.29 11920.25 86.44 47.39 8953.94 8888.94 6295.17 501.83 5956769.46 676210.37 6305.53 26.34 11950.65 89.91 51.02 8954.91 8889.91 6315.02 524.82 5956789.84 676232.89 6328.29 16.51 11980.22 87.94 53.33 8955.47 8890.47 6333.15 548.17 5956808.50 676255.81 6349.39 10.27 12010.00 89.85 56.28 8956.04 8891.04 6350.30 572.50 5956826.22 676279.73 6369.66 11.80 12040.55 89.69 59.93 8956.16 8891.16 6366.44 598.43 5956842.96 676305.28 6389.13 11.96 12070.87 90.43 63.65 8956.13 8891.13 6380.77 625.15 5956857.91 676331.65 6406.92 12.51 12099.76 90.61 66.87 8955.87 8890.87 6392.86 651.38 5956870.61 676357.59 6422.42 11.16 12130.70 89.85 70.20 8955.75 8890.75 6404.18 680.17 5956882.60 676386.11 6437.51 11.04 12160.67 88.83 73.11 8956.09 8891.09 6413.61 708.61 5956892.69 676414.32 6450.67 10.29 12190.59 91.81 75.60 8955.92 8890.92 6421.68 737.42 5956901.43 676442.93 6462.54 12.98 12220.86 91.84 74.80 8954.96 8889.96 6429.41 766.67 5956909.84 676471.99 6474.12 2.64 12250.97 89.23 73.28 8954.68 8889.68 6437.69 795.61 5956918.79 676500.73 6486.22 10.03 12280.62 87.30 69.69 8955.58 8890.58 6447.09 823.71 5956928.85 676528.59 6499.31 13.74 12337.00 87.30 69.69 8958.23 8893.23 6466.64 876.53 5956949.63 676580.94 6525.78 0.00 ~1J~~~ (".:0 ) f !Æ~!Æ~~~!Æ j) ~ FRANK H. MURKOWSKI, GOVERNOR AIIASIiA OILAlWD GAS CONSERVATION COlWlISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK. 99519 Re: Prudhoe Bay Unit 07-29B BP Exploration (Alaska), Inc. Pennit No: 202-239 Surface Location: 452' SNL, 327' WEL, Sec. 33, TIIN, R14E, UM Bottomhole Location: 932' NSL, 677' EWL, Sec. 22, TIIN< R14E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure, to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this/~ day of January, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. l^JtiA- '2.-·/~OIVI?_ , STATE OF ALASKA, I~ ALASKA 0,. ÅND GAS CONSERVATION COMMI5, ,bN PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil ORe-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. RKB = 65' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool /' P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028306 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 452' SNL, 327' WEL, SEC. 33, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 4900' NSL, 173' WEL, SEC. 28, T11N, R14E, UM 07-298 /' Number 2S100302630-277 At total depth 9. Approximate spud date 932' NSL, 677' EWL, SEC. 22, T11N, R14E, UM 01/07/03 / Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well / 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028309,932' MD No Close Approach 2560 12650' MD / 8895' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} Kick Off Depth 11135' MD Maximum Hole Angle 900 Maximum surface 2370 psig, At total depth (TVD) 8800' / 3250 psig 18. Casin~ Program Specifications Setting Depth Size TOD Bottom Quantitv of Cement Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (include staQe data) 3" 2-3/8" 4.7# L-80 ST-L 2330' 10320' 8167' 12650' 8895' 59 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 Casing Structural Conductor Surface Intermediate Production Liner Liner 12817 feet 8927 feet 11240 feet 8869 feet Length Plugs (measured) IBP set at 11240' (10/01) IBP set at 12098' (05/01) Junk (measured) Size Cemented MD TVD 110' 20" x 30" 3767' 13-3/8" 10591' 9-5/8" 720' 7" 2452' 3-3/16" 2568 # Poleset 291 sx CS II, 3000 sx CS III, 600 sx Class 'G' 110' 3767' 110' 3625' 354 sx CS I, 700 sx Class 'G' 387 sx Class 'G' 123 sx Class 'G' 10591' 8424' 10371' - 11091' 8269' - 8777' R ELE-rv1~ D 8263' - 8927' Perforation depth: measured Open Perfs: 11142' - 11162' nFr 11 2002 Isolated Below IBP's: 11610' - 11665', 11950' - 12430', 12600' -127'60' true vertical Open Perfs: 8811' - 8824' ~1ä~ II ' " . Isolated Below IBP's' 8918' - 8919' 8929' - 8934' 89~~'& Gas Cons. LommlSSlon . , , Mchgraao 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch- -.15rilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 MC 25.050 Requirements Contact Engineer Name/Number. Dan Kara, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 Permit Number API Number 262... - .2:5 f 50- 029-21782-02 Conditions of Approval: Samples Required 0 Yes r8I No Hydrogen Sulfide Measures EYes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: n-s.t 'ßop¿= -/-0 'j500 p~(,\. ORIGINAL SIGNED BY Approved By M L. Dill Form 10-401 Rev. 12-01-85 ue and correct to the best of my knowledge Title CT Drilling Engineer Date 12. J '0 10 'Z.. ~,.":",,,:,c' "." ,.', , .,;CQ~'.i~I,:(J~;PP~~~,?{~::.ri\'~::{::;~;;:"'::',\:,,:;"1'::' '. "'...'.:'"..,:;',: f'.Pf.rpx~~ Date See cover letter I ¡ ¡ \ ¡ L- .I for other reauirements Mud Log Required 0 Yes ŒI No Directional Survey Required ~ Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Commissioner "' ! t·to I ;,\ ,., !I f -- Ii n ¡¡ \~~,,)! ~ t~ by order of the commission ¡ j ) r ¡/\ ? Date J I [i jC 7 S bmlt In Triplicate ') ) BP 7-29b CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for Prudhoe well 7-23P. The coil sidetrack, 7-29b, will exit the 3- 3/16" liner in the Ivishak Zone 2 formation and target Zone 1 A. /' A cast iron bridge plug will be set at approx. 11165', just below the existing perforations. The sidetrack whipstock will be set at approximately 11130' (8741ss), just above the existing perforations. The existing perforations will be open during sidetracking operations. The perforations will be isolated during the primary cement job on the J--3f8" liner. / . Approximately is'1"s/Of 3" ~enhole will be drilled to access Zone 1A reserves. 7-29b will be completed with a fully cemente~~:3/8" line and perforated. The top of cement will be placed at the top of the 3-3/16" liner /' at 10368' (8202'ss). Running the 2-3/8" liner up into the 4-1/2" tubing allows the option of a liner top packer if the well fails a liner lap test. A Bonsai completion will be considered if lost circulation is not encountered. Prep work. Planned to commence December 20, 2002. 1. Mechanical integrity testing of inner and outer annulus 2. Install dummy gas lift valves. Drift tubing. 3. Install CIBP at 11165', just below existing perfs. /'" 4. Install mechanical whipstock top at 11130', just above existing perfs. Mill window, Drill and Complete sidetrack: Planned for first week of January 2003. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle is planned for 90 degrees. A cased hole Memory CNL will be run prior to perforating. .......~ Mud Program: · Prep Work: Seawater · CTD: Mill and drill with KCI based Polymer mud system (8.6 - 8.7 ppg) ~ Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: ~-"",;"..._) The production liner ill e a 2-3t ST, L ~.Oifd liner from TD to approx. 10320' (8167'ss). Liner cement will be a minimum of 1 bb of 15.8 pgJátêx cement. Consideration will be given to a Bonsai completion (part cemented/p tted) if no loot circulation is encountered. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over all of the open hole section. Memory CNL will be run inside the liner. ) ) Hazards · Drillsite 7 is not considered an H2S pad and has no production with H2S in excess of 100 ppm. Pad /' offsets <1 Oppm H2S. · The proposed well path lies at the boundary between moderate and high risk provinces of the field for lost circulation at faults. No faults are expected to be encountered. However, the risk of LC is higher than average. · If loss circulation becomes unmanageable a plug back may be required. · Close approach to 7-29A well; -30' TVD separation as 7-29B passes beneath 7-29A at 12390' md ~. Reservoir Pressure Res. press. is estimated to b:/250psi at 8800'ss (7.1 ppg EMW). Max. surface pressure with gas (0.1 psi/ft) to surface is 2370 psi. TREE = 4-1/8" FMC WELLHEAD = FMC ÄêfûÄ'fõFr;;^'''''''^'ÃXËCŠÕÑ' 'KIi.wËlËV;;;"W"^"""""""'^"'''''"'''"'W^W65~ "B'F':""'E["Bï"";""'"'''''''''' ,... .,., ··'w,·,·,·,·,·,·,····....,.,.·",·,····,·· T<ðpN;;'''^~N'N''W,'W''~''"''W',W^'WN''26ÕÕ;'' 'MaJ('Ä'ngie"';;"""·"97@'1'2ä1'7' ^5ãiü!ñrv1D ;-^""'-"'''-'''"-ff2'33' 'Õã-iüm"iVÖ^;""""^"'î3"ãõõí^š^S' ) 113-3/8" CSG, 72#, K-55, ID= 12.347" H 3767' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I 13.75" BKR OEA...OYMENT SLV, ID = 3.00" H 10363' TOP OF 3-3/16" LNR, 6.2#, ID = 2.786" 1---1 10368' 19-5/8" X 7" LNR HANGER 1---1 10371' Minimum 10 = 2.350" @ 10329'slm 4·1/2" HES RCP PACKER 07-29A r,AFETY NOTES: WELL ANGLE> 70 OEG I ,@ 11323' & > 90 DEG @ 11454'. - 2223' 1---1 4-1/2" OTIS HRQ SSSVN, 10 = 3.813" GAS LIFT MANDRELS ST MD 1VD OEV ìYÆ VLV LTCH PORT DATE .. 1 2811 2804 13 TGPD DOME TG 16 12/30/98 2 5260 4623 46 TGPD DV TG 0 06/21/88 3 7052 5885 46 TGPD DOME TG 16 12/30/98 4 8378 6803 46 TGPD DV TG 0 06/21/88 5 9367 7503 44 TGPD DV TG 0 06/21/88 6 9889 7894 38 TGPD DV TG 0 12/30/98 7 10191 8133 39 TGPD DV TG 0 11/05/98 8 10281 8203 41 TGPD S/O TG 20 12/30/98 . L ~ r l)-- í~ 110329'slm 1---1 4-1/2" HES RCP PKR, 10 = 2.350" (02/06/99~ 1 10365' 1---1 TOPOFBKRLOCSEALASSY I 1 10366' 1-1 9-5/8" X 4-1/2" BKR DB PKR, ID = 4.750" 1 I 10377' 1-1 BTM OF 4-1/2" BKR SEAL ASSY 1 ~ 10379' 1-1 BTM OF BKR SBE, ID = 4.750" I . . I 10449' 1-1 4-1/2" OTIS XN NIP, 10 = 3.8" (MILLED OUT) 1 14-1/2" TIP, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1---1 10460' I 19-5/8" CSG, 47#, L-80, ID= 8.681" l-i 10591' ~ I TOP OF WHIPSTOCK l-i 11085' IRA PIP TAG l-i 11094' PERFORA TION SUMMARY REF LOG: BHCS ON 03/03/88 ANGLEATTOPPERF: 91 @ 11610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11142-11162 0 11/04/01 2" 6 11152-11162 0 10/19/01 2" 6 11610-11665 C 10/16/01 2-1/8" 4 11950 - 12430 C 10/16/01 2-1/8" 4 12600 - 12700 C OS/20/01 7" LNR, 29#, L-80, ID = 6.184" 1---1 11470' I 10461' 1-1 4-1/2" WLEG (BEHIND LNR) I ~ 7" LNR SIDETRACK WINDOW 11091' - 11096" (OFF WHIPSTOCK) I ~ ~ - y - I 1-1 2-1/8" BKR IBP (10/16/01) 1 12098' 1---1 2-1/8" BKR IBP (05/20/01) I 3-3/16" LNR. 6.2#, L-80, .0076 bpf, ID = 2.786" l-i 12815' I DATE 03/07/88 12/25/98 12/12/00 02/12/01 09/26/01 REV BY COMMENTS o RIG INA L COMA..El1ON CTD SIDETRACK CONVERTED TO CANVAS FINAL CORRECTIONS DA TE REV BY COMMENTS 10/21/01 CH/KAK CORRECTIONS 10/19/01 CAO/KK ADÆRFS 11/04/01 CWS/tlh ADD & REÆRFS PRUDHOE BA Y UNIT WELL: 07-29A PERMIT No: 198-2270 API No: 50-029-21782-01 452' FNL & 327' FEL, Sec. 33, T11 N, R14E BP Exploration (Alaska) SIS-MO SIS-MO RN/TP TREE = 4-1/8" FMC WELLHEAD = FMC 'Ã^'êTÜÃrÕ¡:r;""_M"ÄxÊLsõÑ 'KŠ'~'ÊrË.\T';;;"'M'^""''',^W""M''''''''M''^,'''''''''"135'' äF~'ELBr;' """ '..."",,,, 'i(õP';,^' W,""MW_""",""^'''"_'' '-"^'-2Ëf6õ' 'iv1a';('A'ñg'îe";;''''''''g:r@''f2'ã1''jï' '5ãtu~mM5;w-""M_-"-""'1'1233i ...."'·.'.........w...w,'.·..'~···'·..WM......""...............".w.'.w.......w."w.w......... Datum ND = 8800' SS ) 07 -29B Proposed CTO Sidetrack "~AFETY NOTES: WELL ANGLE> 70 DEG @11323'&>90DEG@11454', 113-3/8" CSG, 72#, K-55, ID = 12.347" H 3767' .41 41> 2223' l-l 4-1/2" OTIS HRQ SSSVN, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV 1YÆ VLV LTCH PORT DATE ~ 1 2811 2804 13 TGPD DOME TG 16 12/30/98 2 5260 4623 46 TGPD DV TG 0 06/21/88 L 3 7052 5885 46 TGPD DOME TG 16 12/30/98 4 8378 6803 46 TGPD DV TG 0 06/21/88 5 9367 7503 44 TGPD DV TG 0 06/21/88 6 9889 7894 38 TGPD DV TG 0 12/30/98 7 10191 8133 39 TGPD DV TG 0 11/05/98 8 10281 8203 41 TGPD S/O TG 20 12/30/98 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I 12-3/8 liner x 4-1/2" Deployment sleeve l-l 10320' I /" ITop of cement l-l 10368' 1_ ITOP OF 3-3/16" LNR, 6.2#, ID = 2.786" l-l 10368' I 19-5/8" X 7" LNR HANGER l-l 10371' I XiI Gi"B ...... \ ,- I'~ !, -,',,',,',,', ,',',,', , ""'''' ~ 10365' l-l TOP OF BKR LOC SEAL ASSY I 10366' l-l 9-5/8" X 4-1/2" BKR DB PKR, ID = 4.750" I 10377' l-l BTM OF 4-1/2" BKR SEAL ASSY I 10379' l-l BTM OF BKR SBE, ID = 4.750" I Minimum 10 = 2.350" @ 10329'slm 4-1/2" HES RCP PACKER I I 10449' l-l 4-1/2" OTIS XN NIP, ID = 3.8" (MILLED OUT) I I 10461' 1-1 4-1/2" WLEG (BEHIND LNR) I .. I l-l /' 10690' Est'd Top of cement I 14-1/2" TIP, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 10460' I 19-5/8" CSG, 47#, L-80, ID = 8.681" l-l 10591' ~ I TOP OF WHIPSTOCK l-l 11085' 12-3/8" Cemented and Perfed Liner 1-1 12650' I 7" LNR SIDETRACK WINDOW 11091' - 11 096" (OFF WHIPSTOCK) 'ìlilili!!\._.,,¡ ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/03/88 ANGLEATTOPPERF: 91 @ 11610' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11142-11162 0 11/04/01 2" 6 11152 - 11162 0 10/19/01 2" 6 11610-11665 C 10/16/01 2-1/8" 4 11950 - 12430 C 10/16/01 2-1/8" 4 12600 - 12700 C OS/20/01 11130' 11165' Mechanical Whipstock CIBP 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" 1-1 12815' 1 T ~I ~ 11240' l-l 2-1/8" BKR IBP (10/16/01) 1 12098' 1-1 2-1/8" BKR IBP (05/20/01) I I 12731' 1-1 PBTD DATE 03/07/88 12/25/98 12/12/00 02/12/01 09/26/01 SIS-MD SIS-MD RNlTP COMMENTS ORIGINAL COMA..ETION CTD SIDETRACK CONVERTED TO CANVAS FINAL CORRECTIONS DA TE REV BY COMMENTS 10/21/01 CHlKAK CORRECTIONS 10/19/01 CAO/KK ADPERFS 11/04/01 CWS/tlh ADD & REÆRFS PRUDHOE BAY UNIT WELL: 07-29A PERMIT No: 198-2270 Apt No: 50-029-21782-01 452' FNL & 327' FEL, Sec. 33, T11N, R14E BP Exploration (Alaska) REV BY ------- BP Amoco "" 1 111J2.M 48.12 25.00 2 11115..00 50.11 24..51 ~ ~n:t= ~~ ~~: 6 1 U45.00 ".S2 n7.8t S 11431.10 80.00 wo.... ~ ~=-~~: ::: ::::: IniAl 111U.H ".1.31 11121.00 ,,_ 11111.00 "n... 111".00 1"1.1111_.00 .....00 11U3.&O "UM 1 noaAI .....00 12110.00 IUI.oO 10......... n....o 10127.12 IMI.oo 111...12 1110.00 10....01 "11.00 11030.24 ii :~l:::-~~~:tU 11 .')'.00 112H.otI 17 .._ 11311.11 II.,.., W.UpaUu Tie o. MDI IIIlgl It... DatMrm V.s.cUoft AB." :J4.00· WELL,UH onAlLS "..1t10 07-2.. 500212171202 01·21AJ1a1 11125.00 .u I 21 2110&11111 00100 O.1ts 0.00 C:~= ::=Tt.D REFERENCE INFORMATION co-ordinate~~ Reference: Well Centre: 07-29, True North V~~~n (VS) ~:¡:~:~c:: ~~~~~ roe~N~~~)el Measured Depth Reference: 42: 29 211411988 00:00 65,00 Calculation Method: Minimum Curvalure alCTJON DIITAIl& 1138.45 '1"'.35 81&440 .1.3.45 8n8.M .....00 U85.00 ."$.00 1845.&0 ........ Mð1Al 5707.')0 5418A7 ....... 8528.51 MðS.17 +EJ.W DLe. TFace !!i~ 1o..:!:!:!: t~* 19 Jiä ANNOTATIONI MO A'ulotatlo. ~~ ~:: ~~ ~ ~OO 11082'5 1~).I ~ ~~ ~~~ .~~ ~ TI, KO' 1 2 3 . I TO TIHU TlJ.D TU TZ2Ç TZU 2ZT1I TnA TZIB TZIA f¡¡~"1 -1---------1---- I I '... I 0.. Ii BAKIR_ -, ¡ _ : bp HUGIIES l_________ ~~TEQ -~------- --- T Azimuths to True North ----^M-- MagnetiG.North: 26_06° ¡~ / é LEGEND 07-29 (07-29) -----07-29 (07~A)-- 07-29 (07-29APB1) Plan#10 07-29B - Plan #10 Plan: Plan #10 (07 -29/Plan#1 0 07 -29B) Created By: Brij Potnis - - eate: ,12/-1.(J/2002------- --- Magnetic Field Strength: 57541nT Dip Angle: 80.81° Date: 12/10/2002 Model: BGGM2002 Contact Information: Direct: (907) 267-6613 E-mail: brij.potniS@inteq.com Baker Hughes INTEQ: (907) 2ô7--6600 "'.,-"" 72(){}-::-- n T_..t ----" ------ --- ---------_.--------- ------ - - -------- ---- ____ n -------~-,---'~7-298 Faun 2'- __.__~__ :~:-~--~:~---~~=~~~~~~-=-~:~;-~- - - ~;:_~~-~~~- --~--=-~;--- . ---~..-~~-=-~~==-~- ---~ -~ 690~--- -- ----- ------ ----~--- ------- ._~-_._- - ----- "----- - -------------- --------- --~-----~-- ---------- --- --- -~---------------- 4.873.450 &875.60 ",fM)..53 0&817-03 "H2.72 5OJa.78 157'84.'32 11078.17 ------"------ - ----------- ~7OO :::--- ---------::...... - 07-298 Faun 3,':'----: 07-29 tC)7.29APB1r----.:.: --,07-298n02:-.L C ,~ ~::__n-,n;-_ -~-'-nn--=-nC"'- ... ¡=-------~ - :---------- +6400-:'=-":::"::::-====--==- - Z 1:: 6300 :..-------- o .- ~ 62oo~:-=-=----:::..-=---==--==-:-.:.:. --==--=======- - I -- ---------- Z 61<X>--=--'--:::--=====--~ .. :I _____,__ o 6000--~- tI) - -----------~--------- --------- ------"- Plan#10 07-298 --------- -------------~- ~ ------------------- ----~- -~-----~-- ------- - -------- ------ --- ------~---- -------~--- ------------------ ------ ------- 8200 - -- ~-- 8250 8300 8350 "'" - TSÀÕ¡ C .- 8400 ~ 8450 - ;; 8500 Co .! 8550 ~ 8600 i 8650 ~ 8700 ! 8750 8800 8850 8900 8950 -, -- ßl-; ,_we: -----------~- ------ ------ -------~- 5900:::- --- ---- ----~~--~---- ------------------ ----------- ---------- 57oo-=:--- --------~~- ::__;~ C~nn -_n__ .. .~~'~~~.~.nn-- ~-' =.::~ :nnnnn~~_~_ c= __= -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 West( -)/East(+) [100ftlin) -----~- -~-- ------ ----- -~---- ---- -----~--~-- --~- - ------------------ --- -~- -- ----------- --------- , ',--mB _n!.s~ ------- ~-- --- " , ,-TIP. "< '-KOP .___ _ _ ___-===-_-_-:======-- ---- ------ ------- --------=--==~_===_____===_..::..=.:::..:..:_=__=__=___=_==_=:..=_= ~~- -_~~ u__===-_ _ ----=-=--_~ ____u_~_ --=~-==_____==~- '\~"·,,-..-:·'TZ1B· --------- --- --~~-~-~ ",oo,,~~~;~ n_~= _~ ....... ~~ n ~~_ ~__-: ,""''"'~'" -~~ nn~".","':')~_ - - }<im,~-==----- i_07~29~T10,2;_____'! Plan#10 07-298' ---~ ----- - ---- -------- --~~----~------- ----------- -----------~-- ------- :::. 07-29 (~,,---- _-:..:..-___ _::: ~-~_- __- ------------ ------------ --- ----------------~----------------~----~-- -------- - - -------- 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 5950 6000 6050 6100 6150 6200 6250 6300 6350 6400 Vertical Section 'at 34.000 [50ft/in) -- -------~ 12/10/2002 1 :00 PM ') ) 'Oi"",,:',:bP , ~, , . ' " I BP Baker Hughes INTEQ Planning Report .,.~. ".....____. 'M"_.'."_''''''~ '.h_"_",.~~_,__~."__ .."______ .".__"_~. . _.~_.. ~-~- '--"7-:--'--:---'-'-"7'-~~--~~'~~""~"-"'-~'-"~~~'~ ----:- ~~"""--"""""'."--:--"~-:-~'-'~~'''''~'~-:'''"'--'-~--:-'''''-''-.''' .._--":,...~,--;--+,,.,- . . "_".N.".....~.. ~_....:'!...._"_'_...__'''..__._''"..''__._.''''.._~"._.., _., « IN"rItQ Company: Field: Site: Wen: Well path: I Field: Djt~:J2ðd/2Ö02, ' .",',.' '..'.'., ti~~t1~:60:32 .,., ,"", ..'.' ,< .....,'.','. .'. ' ,.', rage: ,',·,"1 " . ", '.,'..,...", ...",Ço~rd,~nåte(~E)R~feren~e:<VV~II:.O!~29iTrueNorth '... '...'.','. .,.,',. i '.', .', '.'.',. '".", ,". ..,'..".. "'i: ,", , ", ", ' ". ,,"~J.1~~~I(TV~)~eferellç~: ." SYS~~ITI: M~~n S~éI'L:evel i< .",.. ','.. .,.'.....,'.'. ,',',' ..,',., ',..Sectio~(VS),R~f~ren~~:, .', ,',i ,.,'.',..,.".,'^'ell~0~q9f\J10.00E¡31·00~i)¡,· .'". ."" .,'" ,·:·::··,··.:·:::::·::~"','~:·:·:::·,~~:::~~~~~x~l~:~!~fJg~~~!~~!~~:::-=:::~~~~~:~,.8~~~~f~"~::...-::~;_::~~;L;8~~à~~~":.~.. BP Amoco P~udhoe Bay PB OS 07 07-29" , :~I,a~~~'9·'..~~;~~~:.~:::.,.:_,:~:., . .¡...,..:..',._,'..~'::",,~ ".....,-,-.;;......:;, Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 . -..._"__..~_..,_,,,... .... ____.. __., __"." ,_,.. __,_._ ....._...._." ,_.__......__ ......._.... __._____" ",,_'n .. -0 ". .. '" ."..._.____ _.., d.. ~___._ ._.." _.."...._ ~_ . _ ,..______._....".._._ .,_..__...__________ _..'M_" "...._.....__ ._,_, ".... .. _ ,.,.___~.....'.", "'...._" "_.__,,,_ Site: PB OS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft Latitude: 677382.28 ft Longitude: North Reference: Grid Convergence: ". ... -"._.~."., .._-..--.... . ,".,.--- -- -_.,.-..._..._.......-_.__..~..._...._..._--~....,"'.."- ...,-..-.~_._..._--_..".,-,,- 70 15 49.847 N 148 33 56.934 W True 1.35 deg - ~ _"_ _. _,,_ ..,," __..... woo... _.... ,.._h',.__,._ ___._,,__., _,.._,__ _", .._.__~,._.u_."..... ~,.."_. ._M'"'' ....__"..".M'.~_._.___...._._._ ___... '_'_'M'_'_'" ....,.,_.. ...._,.", __ ,,_.__,___ Well: 07 -29 Slot Name: 07-29 Well Position: +N/-S 2355.38 ft Northing: 5950464.69 ft Latitude: +E/-W -1471.51 ft Easting: 675855.79 ft Longitude: Position Uncertainty: 0.00 ft Well path: Plan#10 07 -29B 500292178202 Current Datum: 42: 292/14/198800:00 Magnetic Data: 12/10/2002 Field Strength: 57541 nT Vertical Section: Depth From (TVD) ft 0.00 Targets 29 70 16 13.010 N 148 34 39.770 W _ _ _. M'_~_ ....,"'."_,~...._".___~,,..____,.'_'._ __....M~___.._._._ "M~~'", .,_.,"__.___ .. .... --.._.~ ',-.,,,,,..- ..- ..-....._..,.,..,,,._._-.~.....,,.,. "---....-.-."-...-..-"-..,,...-..-...--..... .---..--.....-....-...".. -'-,_....."...,-,,,..,_.'"-"-_..._,-".~-_. .- ._,.". Height 65.00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 07-29APB1 11135.00 ft Mean Sea Level 26.06 deg 80.81 deg Direction - --- .._.-"--"-~'- -.,."-.,,. ,-'._-,~".. ..".'''~ ~.'-"'.'-'~"'---',"" - .'.."... -... "....-""-...---... - .. '·-,··,·,.....·--·00-·--._----- .·._.._.__..._.__..._.....u__ ......._._.._..__._,.,_....,,_ _..~_.._,.. .__.._..._...._ '.____ ...._, .~..._..,_ _"_.__""._...~._ 34.00 --_. . ---.'. .-. . . -.-- ._._. -- -- .~. .__...__,... ~ .'__'__'__.' .~._ .__..~~_~_._..... _..__ _~. ._""_.__ ._. _.._._ _ __.__.~__ ........ ._.__.._ _.._._ ____.__... . ___ _. ._,. _____. ,_ __ M_.___. M........_.__.. .~..._""_". _ __M....___M.. .. Map,.."" 'Map,', "'----Latitude' -..;...>~- Longitude--> Name Description TVD :+N/"S +E/-W 'Nórthhtg,~tsting' De~.t"iß'Sec "pegMin,Sec. ,. ..,' '~~~,".' ,.,,,,, "", .'- , ,J:)i,~~,_.",,,c .." ,...,.f.L...." '_c." '.. .... "...._,.,_','~ .c.....', ,.,..,,~ ,_.'.,c.C". ".~..::. ....""'-,,,', ,-'..._:.~:"_.,.:"",,.,"C_"~ ,:.~.::~_~ '~:''':_":....,,.-,'''':''.c:,._ .',.,,,,,:"',,,,:""',:...::.. ,.._:.....C:CC"..._;',;:.,_..., ~';.;....,;.::":.'-"-..C..:.'~,_,.,,,c,~..,, 07-298 Polygon10.1 0.00 5882.84 -23.36 5956345.00 675694.99 70 17 10.868 N 148 3440.451 W -Polygon 1 0.00 5882.84 -23.36 5956345.00 675694.99 70 17 10.868 N 148 34 40.451 W -Polygon 2 0.00 6632.40 434.31 5957105.00 676134.99 70 17 18.240 N 148 3427.116 W -Polygon 3 0.00 6843.22 1044.44 5957330.00 676739.99 70 17 20.312 N 148 34 9.338 W -Polygon 4 0.00 6528.75 1017.08 5957015.00 676719.99 70 17 17.220 N 148 34 10.137 W -Polygon 5 0.00 6230.15 524.94 5956705.00 676234.99 70 17 14.283 N 148 34 24.476 W -Polygon 6 0.00 5634.71 320.96 5956104.99 676044.99 70 17 8.427 N 148 34 30.420 W 07-29B Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 07-29B Fault 2 -Polygon 1 -Polygon 2 07-29B Fault 3 -Polygon 1 -Polygon 2 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8895.00 8895.00 07 -29B T1 0.1 07-29B T10.2 7481.97 7481.97 7207.59 6808.40 7207.59 7108.26 7108.26 6997.44 6705.24 6705.24 5842.06 5850.84 6679.65 679.23 679.23 862.88 608.47 862.88 190.34 190.34 437.83 -114.18 -114.18 -204.38 275.99 980.59 5957960.00 676359.99 5957960.00 676359.99 5957690.00 676549.98 5957285.00 676304.99 5957690.00 676549.98 5957575.00 675879.99 5957575.00 675879.99 5957470.00 676129.98 5957165.00 675584.99 5957165.00 675584.99 5956300.00 675514.99 5956320.00 675994.99 5957165.00 676679.99 70 17 26.595 N 70 17 26.595 N 70 17 23.896 N 70 17 19.970 N 70 17 23.896 N 70 17 22.920 N 70 17 22.920 N 70 17 21.830 N 70 17 18.956 N 70 17 18.956 N 70 17 10.467 N 70 17 10.553 N 70 17 18.704 N 148 34 19.977 W 148 34 19.977 W 148 34 14.627 W 148 34 22.041 W 148 34 14.627 W 148 34 34.224 W 148 34 34.224 W 148 34 27.013 W 148 34 43.097 W 148 34 43.097 W 148 3445.725 W 148 34 31.730 W 148 34 11.199 W bp . "''''~"'"-.,~.~."_._,,.-.."_.,._-.-,. _... Company: BF'Amoco Field: Prudhoe Bay Site: P8 OS 07 Well: 07-29 Wellpath: Plan#1007-298 Annotation MD ft 11132.36 11135.00 11155.00 11195.00 11345.00 11433.80 12308.80 12650.00 110546.44 10627.62 10858.82 10949.05 11030.24 11119.14 11181.34 11266.06 11316.18 .. - .-. ..". ,."..'''.---.' .. .... .."-...~,,. .' ..~.. . .-.."~'" ...".,-".."... '''"'~''.._,,,. TVD ft 8739.65 8741.35 8754.40 8783.45 8876.98 8895.00 8895.00 8895.00 8328.00 8384.00 8546.00 8610.00 8668.00 8731.00 8773.00 8835.00 8864.00 ) ) BP Baker Hughes INTEQ Planning Report _.....11..111"",,'.' ',", "',,, ".".",,1, "... IN"Ì'EQ .".,.. ,_ ."'":..~' --...,.., "...... .--__._.."'._....__....,_. -'-r·"_·__·__'~,····~·" Date:, <,.t2110/2002 '..,' "..' , ".Tifue:1~:O():32 Pag~: C0-ordi~ate(NE)Reference:Wen: 07~29, True NQrth., V ertical{TVD) Refea:el1ce: : $ystem,M!9an, $~a L~vel Section (VS) ,Reference: " WeH(p.OO\J,O.00E,34.00Azi) ,..~~~.Y~r-.~~l,~.u.!~~.i~!~~!!~~~:'_..".....~M~~~~~.T-g,~,'~~~~E~...~;,__,..;"~~: "..2~~?~f:."... .... n _"'_~_'''''''''____''" ..____._ ~__._,_"_-.____.._~"..n._ '-,. ._..._,...._._.._...~_ _ ,__.. .~._~'_..H_"....~..,.".__.....,...____,·..._"_, ..._..",' ~"___"H'_"'_'~~'___~'_""'_ .,...._,..... .. . .'....--- ''''''''-''-.. .,'" ...;... ".'-~.".,,,..........._--. ". ..."._._._,~. Plan: Plan #10 Identical to Lamar's Plan #10 Principal: Yes TIP KOP 1 2 3 4 5 TO TSHU TSAD TZ3 TZ2C TZ2B 22TS TZ2A TZ18 TZ1A Plan Section Information MD ft 11132.36 11135.00 11155.00 11195.00 11345.00 11433.80 12308.80 : 12650.00 Survey MD ft 10546.44 10627.62 10858.82 10949.05 11030.24 11119.14 11132.36 11135.00 11150.00 11155.00 11175.00 11181.34 11195.00 11200.00 11225.00 11250.00 11266.06 11275.00 11300.00 11316.18 11325.00 loci deg 49.92 50.11 48.42 38.39 66.52 90.00 90.00 90.00 ... . ._.."....__ _,n.... '''~''''''_'''_',"''.--' 2 Date Composed: Version: Tied-to: ..__:'__.__.__ ..",.",,,._->__...,..__,,.,, __ ... _".._........."..~_w__.. ".,' Azim deg 25.00 24.57 23.75 14.11 327.99 340.94 85.94 45.00 8739.65 8741.35 8754.40 8783.45 8876.98 8895.00 8895.00 8895.00 5665.80 5667.64 5681.47 5707.30 5816.47 5894.38 6526.53 6665.17 12/10/2002 2 From: Definitive Path ."~_.._,_, _"'"'_'''''_'__~''~'''''''''''_''' "...'h..,..."...".".... '.....~h"'~_,·. .,"._.,_..... .,,_....,..,,__. .._._ Target +E/:'W I.)LS·.'.·'.~.JladI4L .'.·,)Tllrn rFO "..,..,"~~..f~._.... ,.,.~:.,.~~.~~{1H5~~..:~~~~~g~~:,~~~(~:~,?-~.,_.,c...~~~~~",.. 315.52 0.00 0.00 0.00 0.00 316.37 14.41 7.20 -16.29 299.83 322.57 9.00 -8.44 -4.11 200.00 331.66 30.00 -25.09 -24.09 210.00 305.17 30.00 18.75 -30.75 290.78 268.43 30.00 26.44 14.59 30.00 685.96 12.00 0..00 12.00 90.00 989.81 12.00 0.00 -12.00 270.00 ... "'. _,......._... ._,........" .. _'W"_~' ... .... _ _.~._ ,~._" ..... M."..."....._ "_""'W_'._."';-.'__'_"._ "'_'_"'_ .,....... .. -.._~-.__."..".."...,-_.. lncl deg 46.59 46.19 45.09 44.64 44.15 48.33 49.92 50.11 48.84 48.42 43.30 41.72 38.39 38.94 42.29 46.45 49.45 51.21 56.41 59.95 61.93 Azim dég 30.68 30.83 29.60 28.14 27.52 25.76 25.00 24.57 23.96 23.75 19.38 17.82 14.11 11.88 1.56 352.62 347.54 344.91 338.21 334.30 332.29 ....".-.-,....--......"" .- ...~_,,",~ ~""W'" ....., .....,_,..... _. ".._""___...,,. ,,~. "...".....w......" ~......,,~"._ l ... '.. .., '_'w "., .........J"~.". ",. ."'. ..__._---_..-,~-_._._- '..~---~. --".--' ._-,---,. -'~~"._--_.__.. .--.." "_...._-,,~ -- ..---- .-...... - Tool SSTVD ft ."... ."."...".-,..," 8328.00 8384.00 8546.00 8610.00 8668.00 N/S E/W MapN ' MapE ft ft ft ft ..;.,.,.,~ ... ,_,_w. ,_......__.,.....~."..' ~...:.w,. '".~_.w."4 ...... ..w...._.._"._~~....~~.....i.-..,;;.,.'..'......_._.. .___._ _._,......_..;....___....._...~'._....._.....I. 5301.88 112.55 5955767.41 675844.43 5352.38 142.64 5955818.59 675873.33 5495.05 225.41 5955963.15 675952.74 5550.70 256.20 5956019.50 675982.22 5600.99 282.64 5956070.39 676007.48 8731.00 8739.65 8741.35 8751.09 8754.40 8768.32 8773.00 8783.45 8787.36 8806.35 8824.24 8835.00 8840.70 8855.4 7 8864.00 8868.29 5656.78 5665.80 5667.64 5678.04 5681.47 5694.80 5698.86 5707.30 5710.34 5726.46 5743.88 5755.62 5762.30 5781.40 5793.97 5800.86 311.24 315.52 316.37 321.06 322.57 327.87 329.24 331.66 332.36 334.21 333.27 331.21 329.57 323.16 317.61 314.15 5956126.83 5956135.95 5956137.81 5956148.31 5956151.77 5956165.22 5956169.32 5956177.81 5956180.87 5956197.03 5956214.42 5956226.10 5956232.74 5956251.69 5956264.13 5956270.93 676034.76 676038.83 676039.64 676044.08 676045.51 676050.49 676051.77 676053.99 676054.62 676056.10 676054.75 676052.41 676050.62 676043.76 676037.93 676034.30 VS DLS TFO ft degl100ft deg . .' ..._.....~,.. ,~..-."..,_..."...- .~.. _........~_._._._."... ,-,. 4458.40 0.00 0.00 4517.09 0.51 164.64 4681.65 0.61 218.28 4745.00 1.25 245.85 4801.49 0.81 221.22 4863.72 4873.60 4875.60 4886.84 4890.53 4904.54 4908.67 4917.03 4919.94 4934.34 4948.26 4956.83 4961.45 4973.71 4981.03 4984.80 4.91 12.82 14.41 9.00 9.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 TSHU TSAD TZ3 TZ2C TZ28 342.56 22TS 339.80 TIP 299.83 KOP 200.00 MWD 200.40 1 210.00 MWD 213.05 TZ2A 214.20 2 290.78 MWD 292.52 MWD 300.37 MWD 306.77 TZ18 310.18 MWD 311.85 MWD 315.82 TZ1A 317.88 MWD bp . ,_."..~..,._,,,-.,.._.....-..-....._...._., ) BP Baker Hughes INTEQ Planning Report ) . IN '''[ÈQ "..__._ "_,._.....~'_.~_."'._.".,,... ..., ".", .........__.___...._...... "_~.._".~._'__..._~._......~__,____~.,,..."__M.'_......._._____.____...___'....~"_..~_.__....~.,,'~,..,-.~._._._......._,_ ,,,,,_._.,,__._..M'_'~'__""'."_"_'____"_"'·'___'_"_""._'"--_._.~,,_ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 07 Well: 07-29 Wellpath: Plan#1007-29B Date:, ,'., ~2/~O/2002 ,..'"..",,'Jime:·'··13:00;32, Påge:' 3 Co-Ordina~(N:E)ltefe~ençe: ".' ,,' VVell:07;'~9Jru~N()rth Vertical(lW'D),~~fe~e~ce: Sy~terr):MEI~n~~a Level Secti~n(VS)Refer~nce:' ," Well(0.00N,O.OQE¡34.00Azi) _ "'_.. "... ..,.. _"..c:,_"__--'-___.~_._. ,:"_:. _.~_,..___~~~~~ç:~_.~-':!~~~~~:!t~~~~~..,J~2,~~rn_~~"<?_~'_~~~~!~__.~_:,.__'"_',~~~_=--.,~,~~el~ Survey ~."._'_ . ~.." _ '.k. .."._ MD ft 11345.00 11350.00 11375.00 11400.00 ,," , ·'iri~I-' :-.~7·'A~i~'."----' "'SSTVDu----u---·Nï~--'···-;-'··..E^'f~: ---·--'-·--~~~N""~"----:-',."l\1~;È7~·:-'-·_·--VS~--;-T"-?DLS-----T~()·". ,',' 'Toóï---"j deg "deg ft .ft ,. ,,'.. .'.. ,ft> '., ,·i.ft .'.'.. " ,,','.. .',., .,'.....'..,. ..' .ft..' .'...' ..,..,.fì> ,.·,.,".,qeg/1pOft.. ".. ~ég, ...,'" ,,'.', '... ;..., ..~ ,".,... ~... _._ . ...~.___ ,_ ....." .u..._, __ .. '_' ......w,.,..:. .k'__.. _._,.~, ~...,__~"_.':"~..._...--:.,..~_._~___."._. .__....,..., ..,_._.".,~ ...,.,~.",,,"~,..... _ ,......, ..,,' "...' .......,.... ~...~:".......~..~ .~;.._.._~ ,...' .~;__........_... ;,......""__........-......_.;._... .~.....w.L .¡.__._..".~:_ '._..._'._. --..:... .~.....:..;..'w ~.",..I':'" _I.._..;..,....:...~,...~... .."......... _.._~:_...~.._..~.,.. ; .;~'.~..:_'., 66.52 327.99 8876.98 5816.47 305.17 5956286.32 676024.97 4992.72 30.00 318.86 3 67.82 328.80 8878.92 5820.39 302.76 5956290.19 676022.46 4994.62 30.00 30.00 MWD 74.38 332.65 8887.02 5841.01 291.22 5956310.53 676010.44 5005.27 30.00 29.69 MWD 81.00 336.26 8892.35 5863.04 280.70 5956332.31 675999.41 5017.64 30.00 28.44 MWD 11425.00 11433.80 11450.00 11475.00 11500.00 11525.00 11550.00 11575.00 11600.00 11625.00 11650.00 11675.00 11700.00 11725.00 11750.00 11775.00 11800.00 11825.00 11850.00 11875.00 11900.00 11925.00 11950.00 11975.00 12000.00 12025.00 12050.00 12075.00 12100.00 12125.00 12150.00 12175.00 12200.00 12225.00 12250.00 12275.00 12300.00 12308.80 12325.00 12350.00 12375.00 12400.00 12425.00 12450.00 12475.00 12500.00 12525.00 12550.00 12575.00 87.65 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 339.73 340.94 342.89 345.89 348.89 351.89 354.89 357.89 0.89 3.89 6.89 9.89 12.89 15.89 18.89 21.89 24.89 27.89 30.89 33.89 36.89 39.89 42.89 45.89 48.89 51.89 54.89 57.89 60.89 63.89 66.89 69.89 72.89 75.89 78.89 81.89 84.89 85.94 84.00 81.00 78.00 75.00 72.00 69.00 66.00 63.00 60.00 57.00 54.00 8894.82 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 8895.00 5886.09 5894.38 5909.77 5933.85 5958.24 5982.89 6007.72 6032.67 6057.66 6082.64 6107.52 6132.25 6156.76 6180.97 6204.83 6228.26 6251.20 6273.59 6295.37 6316.48 6336.86 6356.45 6375.21 6393.07 6410.00 6425.93 6440.84 6454.68 6467.41 6478.99 6489.40 6498.61 6506.59 6513.32 6518.77 6522.95 6525.83 6526.53 6527.95 6531.21 6535.77 6541.60 6548.70 6557.04 6566.61 6577.37 6589.30 6602.36 6616.52 271.39 268.43 263.40 256.67 251.21 247.04 244.16 242.59 242.32 243.36 245.71 249.36 254.29 260.50 267.97 276.68 286.60 297.71 309.98 323.37 337.85 353.37 369.90 387.38 405.78 425.04 445.10 465.92 487.43 509.58 532.31 555.55 579.24 603.31 627.71 652.35 677.19 685.96 702.09 726.88 751.46 775.76 799.73 823.29 846.39 868.95 890.92 912.23 932.83 5956355.13 5956363.35 5956378.62 5956402.53 5956426.79 5956451.33 5956476.08 5956500.98 5956525.97 5956550.96 5956575.89 5956600.70 5956625.31 5956649.66 5956673.68 5956697.31 5956720.47 5956743.12 5956765.18 5956786.59 5956807.30 5956827.25 5956846.39 5956864.65 5956882.00 5956898.38 5956913.75 5956928.07 5956941.30 5956953.40 5956964.34 5956974.08 5956982.61 5956989.90 5956995.93 5957000.67 5957004.13 5957005.04 5957006.84 5957010.68 5957015.80 5957022.20 5957029.86 5957038.75 5957048.85 5957060.14 5957072.57 5957086.13 5957100.76 675989.56 675986.41 675981.03 675973.74 675967.71 675962.96 675959.51 675957.35 675956.50 675956.96 675958.72 675961.79 675966.15 675971.79 675978.70 675986.86 675996.25 676006.83 676018.58 676031.47 676045.47 676060.53 676076.61 676093.68 676111.67 676130.55 676150.26 676170.75 676191.96 676213.83 676236.30 676259.32 676282.82 676306.73 676330.98 676355.52 676380.28 676389.04 676405.13 676429.83 676454.29 676478.45 676502.25 676525.61 676548.4 7 676570.78 676592.46 676613.46 676633.72 5031.55 5036.76 5046.71 5062.91 5080.08 5098.18 5117.16 5136.96 5157.53 5178.82 5200.77 5223.31 5246.38 5269.93 5293.88 5318.18 5342.75 5367.52 5392.44 5417.43 5442.42 5467.34 5492.13 5516.72 5541.04 5565.02 5588.60 5611.71 5634.29 5656.28 5677.62 5698.25 5718.11 5737.15 5755.32 5772.56 5788.83 5794.32 5804.52 5821.08 5838.60 5857.03 5876.32 5896.42 5917.26 5938.80 5960.97 5983.72 6006.97 30.00 30.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 27.67 MWD 27.32 4 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 5 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD ') ) ~ I,N''I'ßQ' bp BP Baker Hughes INTEQ Planning Report .......-.,.....'..".- -,~....-."-..."-,, .__,. _'," ~"",.. "".~,,., .._"'.,. .___.._".., .._,~~..."..'",.,_"_'_"._,.,_....._. .,."_'"W.~_.. .... _,.__._.".__........ ,_......", __,,_._, ...._.,~~._.._'.".._._"_,.._"_.'"'""_,,.....~_,__'"__._....,,__._. _.....~.__._._,.__.__. ".__.,._ .-"__._,.___",,._,,___._~_________"""__...._,_,,__"~_.____ Date: 12/10/2Q02 Time: ,13:00:32 'Page: 4 Co-ordblate(NE)R,ef~rence: Well:. OT..2~i True North' .Vert~cal('(YD) Re(e"~l1ce: SY$~em:Mean 'S~a,'Ll;!vel .'" Section(VS)Refe~ence: .",.,. ", '.','.. Well (b.00N,0.00E,34.00Azi) " .' ,... ,___" :__....... .._.._..._:~~u.~~~y.J;~I~"u}~!i?..~,_~~~~~~:,'~.._, .~iDiL~'_~~_E~~~J~!.::..,..___.,~~:_..9~~Þ.!~.. ,__._ .. Company: BP Amoco Field: Prudhoe BélY Site: P8 OS 07 ' Well: 07-29 Well path: Plan#10 07-298 Survey - . .'. ""~-"""'-'-'---"'-'-'--_._-' .~---,.._~. .. _,._... .... _"_"~'_'. .~_'__' ,..._.,. ..,._..~ ._...~...."':'''''':"._..,~. ......_., ~,....w... ___....__ __ .,.". ,"'_' __.~,.._~. . "__._"_~_~__''"___ _,.......___..,...._..... ..~.' ".....__. _.. '...... w":"_,.._. ,._...~...._...".:..,:';'_...'''.. _".,.____" ,.._." ~._."...~.__' ... . _".._. MD lncl Azim SSTVD N/S E/W MapN MapE VS DLS TEO Tool ft deg deg ft ft ft ft ft ft deg/100ft ._.~,:~.. '."__._.'_'W_'. ... -.. ..~._,_. ...... ""-"''''. . . ..."......, '-.1."''',,- .."" ...._..... . ,,_ _,I . .".~ ....::-y.., "~'~' ,,~..~.. ... ..:.".:.._. _. ."...~....;..:;.._~.. ,~~.......:..~'".'-_. :..........:.." ..;:.. ~....I~,_~:.~.~......:.,,'~.__, ..........._ :_,;..._,_.__,,_:.....~_~~..~.r....;. :_".""...~...; .....,.. ."~,..; ,.. . ._,...;,~ . 12600.00 90.00 51.00 8895.00 6631.73 952.67 5957116.44 676653.19 6030.68 12.00 270.00 MWO 12625.00 90.00 48.00 8895.00 6647.97 971.67 5957133.11 676671.81 6054.77 12.00 270.00 MWO 12650.00 90.00 45.00 8895.00 6665.17 989.81 5957150.74 676689.54 6079.17 12.00 270.00 TO - ...-...--,......-.....-..-.-."-..-..---..,-.-.--.,- ., --,-"~"'_._._..."...._.._,,....,_.__._- """"'- Well 1'\:'/'1"1,:"', I~" 5000 psi ~ ') BOP-Tree ) ., ~," I, KB Elevation I Lubricator 10 = 6.375" with 6" Otis Unions 171/16" 5000 psi BOP's. 10 = 7.06" I ./ I I I I 1/16" 5000 psi, RX-46 I I I . I I I~ 1/16" 5000 psi, RX-24 I 7 1/16" 5000 psi (RX-46) or 41/16" 5000 psi (RX-39) I Swab Valve I Tree Size I SSV I I Master Valve I I Base FlanQe . I Page 1 P054967 DATE INVOICE I CREDIT MEMO DESCRIPTION 11/18/02 INV# CKll1402H PERMIT TO DRILL FEE THE ATTACHED CHECK IS IN PAYMENT FOR rfEMS DESCRIBED ABOVE. . ,.- TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519~6612 PAY TO THE ORDER OF B P r::'" ."". ,"I' tt:,; - .~~~,.. 'j . . .. '.!j ..,f" ~!W;: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVE SUITE 100 ANCHORAGE, AK 99501 ------- DATE GROSS 11/18/02 VENDOR DISCOUNT , '_I /\ C{?- ~-.._ f J ,j-.... ·,.0 \,-)- t ~ - NATIONAL CITY BANK Ashland, Ohio 56-389 412 CONSOLIDATED COMMERCIAL ACCOUNT ,~:::;¡. ,::;:}. "-¡'J U)lff DATE CHECK NO. P054967 NET No.P 054967 AMOUNT ~--~----'J NOV 18, 2002 ****$100.00**** NOT VALID AFTER 120 DAYS g;?ffJ~J~:" II- 0 5 ~ 9 b ? II- I: 0 ~ . 20 3 8 9 5 I: o. 2 ? 8 9 b II- iii '~ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "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. HOLE 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). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY Ap X WELL NAME r~/-1 o'? w'2....1.11 FIELD & POOL ç; ~O /. S- ~ INIT CLASS I?,.._d -' / - d .. "/ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . JJq 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . ~ /;;..,1/1102.... 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . .. . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . APPR DATE (Service Well Only) (Service Well Only) ENGINEERING l l I APPR DATE 1tJ6k- i ¿¡"Solo 1- (Service Well Only) GEOLOGY APPR DATE ¡(ft. I<.ß/Asz. (Exploratory Only) Rev: 10/15/02 PROGRAM: Exp _ Dev....k Redrll...K.. Re-Enter _ Serv _ Wellbore seg _ GEOL AREA ? 5" t"'1 UNIT# 1/ t:, Ç"/""¡ ON/OFF SHORE ~ 0N Y N Y N Y N Y N Y N Y N Y N Y N Y N \Y N 12. Permit can be issued without administrative approval.. . . . . \::p N 13. Well located w/in area & strata authorized by injection order #_ Y ..Þt /'V...A \ 14. All wells wlin X mile area of review identified. )l"N .¥-N- -~ -¥-N-Ai/A- --v--N- ~~ crDu-. &ì~ 1'l-/iL{ ~L '~ N ' ¡U/Æ- œjN (I/l~ MvJ i, 1 PP5 . I~MS.P z:570 pic'. 'Y N . Ai/lit- Y@ }{ flJ IA. RESERVOIR ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. 18. CMT vol adequate to tie-in long string to surf csg. . 19. CMT will cover all known productive horizons. . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; testto "35" 0 0 p sig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... GEOLOGY: RPc4?L- PETROLEUM ENGINEERING: TEM SFD_ WGA ./ G:\geology\permits\checklist.doc UIC ENGINEER JDH JBR MJW COM MISSIONER: COT DTS rJj03j03 MLB ""'//Ø'-:/-=-3 .( Commentsllnstructions: ') ) Well History File APPENDIX Infornlation of detailed nature that is not particularly germane to the Well PenTlitling Process but is part of the history file. To inlprove the readability of the Well History file and to simplify finding infomlation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) **** REEL HEADER **** MWD 03/06/19 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/06/19 428189 01 2.375" CTK *** LIS COMMENT RECORD *** ) ¡J(ß-C)3C¡ :tf 130 /0 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information Remark File Version 1.000 Extract File: ldwg.las VERSo WRAP. 1.20: NO: ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11118.5000: STOP.FT 12336.0000: STEP.FT 0.2500: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #MN'EM.UNIT #--------- SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 07-29BPB1 Prudhoe Bay Unit 70 deg 16' 13.010"N 148 deg 34' 39.770"W North Slope Alaska Baker Hughes INTEQ 2.375" CTK 11-Feb-03 500292178271 Value Description ------------------------- -------------------------- 33 11N 14E MSL o RKB 65.0 KB 65.0 N/A N/A ~~~f\~ section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Gr'REeelVED JUN 2;:) 2003 Alas!{a 0;) 81' 13;:1:; Cons. Commi$Sion llJ1(mofltge SSTVD) ) ) CASE.F 051 . 052 . ~Remarks 11129 DIRECTIONAL PRESSTEQ I Casing Depth Other Services Line 1 Other Services Line 2 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is Realtime data. (4) This borehole, 07-29BPB1, was kicked off from 07-29APB1 at 11129' MD (8737' SSTVD). (5) Baker Hughes Inteq utilized CoilTrak downhole tools and ADVANTAGE surface system. (6) Tools ran in the string included CCL, Electrical Disconnect and Circulating sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and an Orienting Sub with a near bit inclination sensor. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve recorded by SWS on February 15, 2003 for a 07-29B well. Only interval above 11920' MD (8888' was utilized for depth shifting to PDC for 07-29BPB1 well. (8) The interval from 12307' MD (8892' SSTVD) to 12333' MD (8894' SSTVD) was not logged, due to bit to sensor offset. MNEMONICS: GRCX ROPS TVD -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, feet/hour -> Subsea True Vertical Depth (SSTVD), feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 26.74 ft. 27.59 ft. 2 26.74 ft. 27.59 ft. 3 26.74 ft. 27.59 ft. CURVE SHIFT DATA OBSERVED, ACTUAL, DISPLACEMENT 11120.9, 11118.0, 11125.5, 11123.0, 11130.7, 11130.5, 11135.0, 11137.7, 11145.9, 11145.3, 11150.5, 11150.7, 11159.4, 11159.7, 11168.0, 11168.4, 11171.1, 11171.7, 11173.8, 11174.2, 11176.3, 11177.3, 11178.4, 11179.8, 11187.5, 11187.7, 11192.9, 11194.4, 11198.3,11199.9, 11208.9, 11209.1, 11213.9, 11215.1, 11220.1, 11221.8, 11223.4, 11224.0, 11225.5, 11226.5, 11228.4, 11229.7, -2.90918 -2.49414 -0.208008 2.70117 -0.624023 0.208008 0.208008 0.415039 0.623047 0.416016 1.03906 1.4541 0.208008 1. 4541 1. 66211 0.207031 1.24707 1.66211 0.623047 1.03906 1.24707 ) 11234.4, 11235.1, 11238.6, 11238.6, 11244.2, 11244.6, 11252.3, 11252.7, 11257.5, 11258.1, 11264.4, 11265.0, 11266.6, 11267.1, 11276.2, 11275.7, 11281.1, 11281.8, 11284.9, 11285.7, 11290.5, 11292.2, 11296.9, 11295.7, 11303.0, 11304.5, 11310.7, 11307.8, 11315.1, 11312.2, 11319.4, 11316.9, 11325.9, 11326.7, 11335.9, 11335.6, 11343.5, 11343.3, 11351.6, 11351.2, 11358.7, 11359.1, 11369.9, 11369.5, 11379.9, 11378.2, 11394.9, 11394.1, 11398.3, 11398.3, 11412.2, 11412.8, 11421.8, 11423.2, 11435.3, 11436.6, 11475.4, 11475.2, 11489.1, 11487.4, 11498.2, 11497.3, 11507.9, 11506.7, 11541.9, 11540.3, 11556.1, 11555.7, 11566.6, 11565.6, 11592.4, 11592.8, 11612.4, 11608.2, 11648.1, 11648.9, 11672.5, 11670.2, 11692.6, 11691.5, 11704.6, 11700.9, 11711.5, 11707.3, 11722.2, 11720.5, 11728.3, 11730.0, 11737.8, 11737.4, 11758.6, 11758.2, 11769.0, 11770.8, 11778.8, 11777.6, 11820.2, 11817.1, 11840.8, 11837.1, 11853.9, 11852.9, 11876.0, 11873.1, 11893.7, 11890.5, EOZ END ) 0.623047 o 0.415039 0.415039 0.623047 0.624023 0.416016 -0.415039 0.623047 0.831055 1.66211 -1.24609 1.4541 -2.90918 -2.90918 -2.49414 0.831055 -0.208008 -0.208008 -0.416016 0.416016 -0.415039 -1. 66309 -0.831055 o 0.624023 1.45508 1.24707 -0.208008 -1. 66211 -0.832031 -1.24609 -1. 66211 -0.416016 -1.03906 0.415039 -4.15625 0.831055 -2.28613 -1. 03906 -3.74023 -4.15625 -1. 66211 1. 66211 -0.416016 -0.416016 1.87012 -1.24707 -3.11719 -3.74121 -1. 03906 -2.90918 -3.11719 ! BASE CURVE: GROH, OFFSET CURVE: GRCX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** 156 records... 8 bytes 132 bytes ) ) MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska) Inc. 07-29BPB1 Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !!!!!! !! ! ! ! !! ! !!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve recorded by SWS on February 15, 2003 for 07-29B well. Only interval above 11920 ft. MD (8888 ft. SSTVD) was utilized for depth shifting to PDC for 07-29BPB1 well *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 API 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 58 ) ) Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11118.500000 12336.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 2 67 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 BP Exploration (Alaska) 07-29BPBl Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** ! ! !!!!!!! !!! ! !!!!!! Remark File Version 1.000 The data contains the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRCX ROPS GRCX ROPS GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME ) ) Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Total Data Records: Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** Size Length 4 4 4 4 ------- 8 58 11121.000000 12336.000000 0.250000 feet Tape Sub file: 3 67 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/06/19 428189 01 **** REEL TRAILER **** MWD 03/06/19 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 2 is type: LIS DEPTH 11118.5000 11118.7500 11150.0000 11200.0000 11250.0000 11300.0000 11350.0000 11400.0000 GR 16.1800 16.1525 24.5619 16.3579 35.1356 83.8797 38.6066 42.3112 2 records... 132 bytes 132 bytes ROP -999.2500 -999.2500 15.6796 35.9330 19.5599 47.8487 39.7410 41.1641 ) ) 11450.0000 45.3329 57.3217 11500.0000 45.1358 69.8590 11550.0000 46.3521 78.1690 11600.0000 41.4235 34.3705 11650.0000 42.5270 76.9520 11700.0000 81.0171 64.2954 11750.0000 43.2979 79.3396 11800.0000 47.0816 86.3165 11850.0000 48.4480 91.3948 11900.0000 46.8024 78.1810 11950.0000 74.6157 23.0894 12000.0000 45.5599 56.0287 12050.0000 121. 0764 50.7581 12100.0000 82.1408 67.2680 12150.0000 118.3680 55.8590 12200.0000 76.2149 111.9966 12250.0000 69.2624 65.1925 12300.0000 95.6585 69.0782 12336.0000 -999.2500 -999.2500 Tape File Start Depth 11118.500000 Tape File End Depth 12336.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 3 is type: LIS DEPTH GRCX ROPS 11121. 0000 16.1800 -999.2500 11121. 2500 16.1525 -999.2500 11150.0000 24.2400 13.6000 11200.0000 13.7100 10.8800 11250.0000 37.6200 20.4400 11300.0000 85.5900 47.7200 11350.0000 37.1300 39.4900 11400.0000 42.3400 39.0500 11450.0000 44.9200 56.2700 11500.0000 44.1000 31. 7700 11550.0000 44.7400 77.1900 11600.0000 41. 0400 89.0700 11650.0000 40.1500 75.8500 11700.0000 69.6900 66.8500 11750.0000 43.2100 79.0800 11800.0000 45.6400 84.5000 11850.0000 47.3800 89.5600 11900.0000 42.9100 71. 4500 11950.0000 77.5000 27.0800 12000.0000 44.1200 57.7700 12050.0000 102.4400 47.9700 12100.0000 68.3700 70.1600 12150.0000 112.2700 62.6400 12200.0000 56.8000 112.2000 12250.0000 65.9700 61.5200 12300.0000 104.0200 72.6700 12336.0000 -999.2500 -999.2500 Tape File Start Depth 11121.000000 Tape File End Depth 12336.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 4 is type: LIS ) **** REEL HEADER **** MWD 03/06/15 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/06/15 428189 01 2.375" CTK *** LIS COMMENT RECORD *** ) ¿if ~ - ~,3 c¡ (/ 7 qg ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information Remark File Version 1.000 Extract File: ldwg.las VERSo WRAP. 1.20: NO: ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11117.0000: STOP.FT 12545.7500: STEP.FT 0.2500: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCAT I ON : CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #:MNEM.UNIT #--------- SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 07-29B Prudhoe Bay Unit 70 deg 16' 13.010"N 148 deg 34' 39.770"W North Slope Alaska Baker Hughes INTEQ 2.375" CTK 13-Feb-03 500292178202 Value Description ------------------------- -------------------------- 33 IlN 14E MSL o RKB 65.0 KB 65.0 N/A N/A Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ) ) CASE.F OSl . OS2 . ~Remarks 11129 DIRECTIONAL PRESSTEQ I Casing Depth Other Services Line 1 Other Services Line 2 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is Realtime data. (4) This borehole, 07-29B, originated from a kick off 07-29APB1 at 11129' MD (8737' SSTVD). This borehole was also sidetracked off of the plugged-back wellbore, 07-29BPB1, at 11920' MD (8888' SSTVD). (5) Baker Hughes Inteq utilized CoilTrak downhole tools and ADVANTAGE surface system. (6) Tools ran in the string included CCL, Electrical Disconnect and Circulating sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and an orienting Sub with a near bit inclination sensor. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on February 15, 2003. (8) The interval from 12520' MD (8878' SSTVD) to 12546' MD (8879' SSTVD) was not logged, due to sensor to bit offset. MNEMONICS: GRCX ROPS TVD -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, feet/hour -> Subsea True Vertical Depth (SSTVD), feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 26.74 ft. 27.59 ft. 2 26.74 ft. 27.59 ft. 3 26.74 ft. 27.59 ft. 4 24.63 ft. 25.48 ft. 5 26.54 ft. 27.39 ft. CURVE SHIFT DATA OBSERVED, ACTUAL, DISPLACEMENT 11120.9, 11118.0, -2.90918 11125.5, 11123.0, -2.49414 11130.7, 11130.5, -0.208008 11135.0, 11137.7, 2.70117 11145.9, 11145.3, -0.624023 11150.5, 11150.7, 0.208008 11159.4, 11159.7, 0.208008 11168.0, 11168.4, 0.415039 11171.1, 11171.7, 0.623047 11173.8, 11174.2, 0.416016 11176.3, 11177.3, 1.03906 11178.4, 11179.8, 1.4541 11187.5, 11187.7, 0.208008 11192.9, 11194.4, 1.4541 11198.3, 11199.9, 1. 66211 11208.9, 11209.1, 0.207031 11213.9, 11215.1, 1.24707 11220.1, 11221.8, 1. 66211 11223.4, 11224.0, 0.623047 11225.5, 11226.5, 1.03906 11228.4, 11229.7, 1. 24707 11234.4, 11235.1, 0.623047 ) ) 11238.6, 11238.6, 11244.2, 11244.6, 11252.3, 11252.7, 11257.5, 11258.1, 11264.4, 11265.0, 11266.6, 11267.1, 11276.2, 11275.7, 11281.1, 11281.8, 11284.9, 11285.7, 11290.5, 11292.2, 11296.9, 11295.7, 11303.0, 11304.5, 11310.7, 11307.8, 11315.1, 11312.2, 11319.4, 11316.9, 11325.9, 11326.7, 11335.9, 11335.6, 11343.5, 11343.3, 11351.6, 11351.2, 11358.7, 11359.1, 11369.9, 11369.5, 11379.9, 11378.2, 11394.9, 11394.1, 11398.3, 11398.3, 11412.2, 11412.8, 11421.8, 11423.2, 11435.3, 11436.6, 11475.4, 11475.2, 11489.1, 11487.4, 11498.2, 11497.3, 11507.9, 11506.7, 11541.9, 11540.3, 11556.1, 11555.7, 11566.6, 11565.6, 11592.4, 11592.8, 11612.4, 11608.2, 11648.1, 11648.9, 11672.5, 11670.2, 11692.6, 11691.5, 11704.6, 11700.9, 11711.5, 11707.3, 11722.2, 11720.5, 11728.3, 11730.0, 11737.8, 11737.4, 11758.6, 11758.2, 11769.0, 11770.8, 11778.8,11777.6, 11820.2, 11817.1, 11840.8, 11837.1, 11853.9, 11852.9, 11876.0, 11873.1, 11893.7, 11890.5, 11925.7, 11923.2, 11949.4, 11947.1, 11962.9, 11961.4, 11978.3, 11976.8, 11983.5, 11984.9, 11996.8, 11996.6, 12007.4, 12003.2, 12013.2, 12011.1, 12017.0, 12015.4, 12031.4, 12026.2, 12035.0, 12031.3, 12049.7, 12047.4, 12058.2, 12056.3, 12075.6, 12075.6, 12103.6, 12100.5, o 0.415039 0.415039 0.623047 0.624023 0.416016 -0.415039 0.623047 0.831055 1. 66211 -1.24609 1. 4541 -2.90918 -2.90918 -2.49414 0.831055 -0.208008 -0.208008 -0.416016 0.416016 -0.415039 -1.66309 -0.831055 o 0.624023 1.45508 1. 24707 -0.208008 -1. 66211 -0.832031 -1.24609 -1. 66211 -0.416016 -1. 03906 0.415039 -4.15625 0.831055 -2.28613 -1.03906 -3.74023 -4.15625 -1. 66211 1. 66211 -0.416016 -0.416016 1.87012 -1.24707 -3.11719 -3.74121 -1. 03906 -2.90918 -3.11719 -2.49414 -2.28613 -1.4541 -1. 45508 1.4541 -0.208008 -4.15625 -2.07812 -1.66211 -5.19531 -3.74121 -2.28613 -1. 87012 o -3.11719 12121.0, 12119.2, 12127.7, 12126.2, 12150.1, 12148.3, 12158.2, 12156.2, 12168.8, 12163.4, 12175.7, 12170.5, 12180.1, 12174.9, 12183.8, 12179.2, 12197.4, 12191.6, 12204.5, 12198.7, 12212.4, 12206.1, 12220.9, 12218.9, 12238.1, 12232.9, 12246.3, 12241.9, 12252.7, 12245.6, 12253.7, 12248.3, 12258.3, 12252.2, 12259.3, 12253.7, 12275.0, 12270.0, 12289.2, 12283.8, 12291.7, 12286.5, 12294.8, 12289.4, 12298.3, 12293.7, 12305.6, 12302.3, 12312.1, 12309.0, 12321.9, 12317.4, 12335.1, 12331.6, 12344.2, 12339.2, 12361.8, 12361.6, 12372.0, 12369.9, 12382.6, 12378.7, 12391.5, 12386.3, 12395.3, 12391.7, 12400.5, 12396.9, 12410.1, 12406.6, 12428.8, 12425.5, 12436.6, 12434.5, 12452.2, 12446.2, 12458.6, 12453.4, 12465.4, 12460.4, 12474.7, 12467.4, 12479.4, 12475.1, 12492.3, 12487.3, 12499.6, 12496.1, 12505.6, 12501.9, 12516.0, 12515.6, EOZ END ) -1. 87012 -1. 45508 -1. 87012 -2.07812 -5.40332 -5.19531 -5.19531 -4.57129 -5.81934 -5.81836 -6.23438 -2.07812 -5.19531 -4.36426 -7.06543 -5.40332 -6.02734 -5.61133 -4.9873 -5.40332 -5.19531 -5.40332 -4.57227 -3.3252 -3.11719 -4.57129 -3.53223 -4.9873 -0.208008 -2.07812 -3.94824 -5.19531 -3.53223 -3.53223 -3.53223 -3.3252 -2.07812 -6.02734 -5.19531 -4.9873 -7.27344 -4.36328 -4.9873 -3.5332 -3.74023 -0.415039 ! BASE CURVE: GROH, OFFSET CURVE: GRCX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 218 records... 8 bytes 132 bytes ) *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska) Inc. 07-29B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** ! !!! !! !! !!!! !!!! ! !! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on February 15, 2003 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 API 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 69 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11117.000000 12545.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 2 78 records... ) ) Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 BP Exploration (Alaska) 07-29B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data contains the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRCX ROPS GRCX ROPS GRCX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRCX MWD 68 1 API 4 4 2 ROPS MWD 68 1 F/HR 4 4 ------- 8 ) ) Total Data Records: 68 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11120.000000 12545.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 77 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/06/15 428189 01 **** REEL TRAILER **** MWD 03/06/15 BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS DEPTH GR ROP 11117.0000 16.4700 -999.2500 11117.2500 17.5775 -999.2500 11150.0000 24.1447 10.6126 11200.0000 15.0556 35.2697 11250.0000 37.2755 20.0081 11300.0000 84.6249 47.3529 11350.0000 41.1321 40.2576 11400.0000 41.9047 37.7226 11450.0000 43.4272 57.7791 11500.0000 44.9128 70.2807 11550.0000 46.7743 79.5605 11600.0000 41.6082 35.5256 11650.0000 43.3366 77.2288 11700.0000 78.6530 63.3062 11750.0000 40.6180 78.4828 11800.0000 46.3875 87.3945 11850.0000 50.1052 90.2049 ) ) 11900.0000 46.3399 77.1435 11950.0000 67.1048 70.8529 12000.0000 38.7620 88.5030 12050.0000 79.6720 71. 8235 12100.0000 50.1338 83.7012 12150.0000 50.6865 99.8454 12200.0000 79.7962 111.8262 12250.0000 61.7317 71.5347 12300.0000 69.7746 79.6510 12350.0000 67.2373 26.9895 12400.0000 48.9320 217.2498 12450.0000 37.0386 148.7434 12500.0000 34.0555 176.3565 12545.7500 -999.2500 -999.2500 Tape File Start Depth 11117.000000 Tape File End Depth 12545.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 3 is type: LIS DEPTH GRCX ROPS 11120.0000 16.4700 -999.2500 11120.2500 17.7000 -999.2500 11150.0000 23.4200 13.6000 11200.0000 13.6400 10.8800 11250.0000 37.6700 20.4400 11300.0000 90.1600 47.7200 11350.0000 40.1900 39.4900 11400.0000 42.3800 39.0500 11450.0000 45.0200 56.2700 11500.0000 44.3100 31. 7700 11550.0000 44.9100 77.1900 11600.0000 41.0300 89.0700 11650.0000 40.8650 75.8500 11700.0000 69.5200 66.8500 11750.0000 43.0900 79.0800 11800.0000 45.8900 84.5000 11850.0000 47.4800 89.5600 11900.0000 45.2050 71. 4500 11950.0000 67.5000 75.4200 12000.0000 37.6100 87.7500 12050.0000 78.9700 70.7300 12100.0000 54.3300 87.3300 12150.0000 58.2814 86.9500 12200.0000 51.8600 299.3800 12250.0000 35.6900 113.6200 12300.0000 73.2200 103.1900 12350.0000 67.1200 83.5300 12400.0000 50.0900 218.2000 12450.0000 43.6967 168.3900 12500.0000 32.8400 123.7400 12545.7500 -999.2500 96.4000 Tape File Start Depth 11120.000000 Tape File End Depth 12545.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 4 is type: LIS