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Home My WebLink About203-117• • ~._ ;~ ~. ,.; MICROFILMED 03/01/2008 DO NOT PLACE ,t ANY NEW MATERIAL UNDER THIS PAGE F:1I,aserFiche\C~rPgs_InsertslMicrofilm Marker.doc · e"""""J _j'i~\ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: X-08A, X-09B, X-31 L1 & Z-llA. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 X-08A: dD3 -II"? t:! IL!¿¡L/?- Digital Log Images: 50-029-20463-01 1 CD Rom X-09B: {)Ö d -03 ( ~ 14L/L/~ Digital Log Images: 50-029-20455-02 1 CD Rom X-31 L1: 6>08- - 67- 3 'it 1'tft.¡L/t-j Digital Log Images: 50-029-20435-60 1 CD Rom Z-11A: QDS- -03 ( .:It l?-./L/L/j- Digital Log Images: 50-029-22053-01 1 CD Rom :) RE: X-08 (PTD #2031170) Classified as prOb.welI AII- Please note that the subject line of my last email is incorrect and the well is being classified as a Problem well. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 SCANNED JAN () 8 2007 From: NSU, ADW Well Integrity Engineer Sent: Sunday, December 31,20067:04 PM To: Schmoyer, AI; GPB, GC3 Wellpad Lead; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; 'AOGCC Jim Regg (E-mail)'; 'AOGCC Winton Aubert (E-mail)'; NSU, ADW WL & Completion Supervisor; GPB, GC3 Operators; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; Lau, John, Jack Subject: FW: X-08 (PTD #2031170) Classified as Trouble Well All, Well X-OB (PTD #2031170) S-riser mods have been found to be completed. The wellwork will be completed as originally indicated, as follows:. 1. SL: Run full GL design 2. WIE: POP well, flow no more than two weeks 3. SL: Set TTP 4. FB: MIT-T The tubing string should elongate as it warms up which should stop the leaks. If the MIT-T fails we will run a tubing patch. A well bore schematic has been included for reference. 10f2 1/2/2007 1 :33 PM Rt,: X-08 (PTD #2031170) Classified as probl Well «File: X-08Apdf» . The well has been classified as a Problem well. Please call if you have any questions. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, December 30, 2006 3:30 PM To: Schmoyer, AI; GPB, GC3 Wellpad Lead; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; 'AOGCC Jim Regg (E-mail)'; 'AOGCC Winton Aubert (E-mail)'; NSU, ADW WL & Completion Supervisor; GPB, GC3 Operators; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; Lau, John, Jack Subject: RE: X-08 (PTD #2031170) Classified as Trouble Well AI!- This well will be unable to be unsecured for the evaluation at the present time as it requires S-riser modifications before being placed on production. The well will be left secured with a TTP until the S-riser modifications have been completed. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 20f2 1/2/2007 1 :33 PM · STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIQ.NS-¡;¡ " .,' .'.,-,,,,::'1_.:",, '..). i~ I-IVED OCT 2 4 2006 Cons. Commission 1. Operations Performed: (}, n t' ~-'; (¡" tt n ~ Abandon 0 Repair WellŒ Plug PerforationsD Stimulate 0 ¡ '" VÖt~~'rÐ Alter CasingD Pull TubingŒ Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD # 203-1170 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20463-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.48 X-08A 8. Property Designation: 10. Field/Pool(s): ADL-028313 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11691 feet true vertical 8904.0 feet Plugs (measured) 4-1/2" HES PXX @ 8684 (10/07/2006) Effective Depth measured 11658 feet Junk (measured) None true vertical 8901.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" x 30" 35 - 145 35.0 - 145.0 SURFACE 2782 13-318" 72# L-80 34 - 2816 34.0 - 2816.0 4930 2670 PRODUCTION 2108 9-5/8" 40# L-80 33 - 2141 33.0 2141.0 5750 3090 PRODUCTON 7206 9-5/8" 47# SOO-95 2141 - 9347 38.0 - 8640.0 8150 5080 LINER 673 7" 29# L-80 8859 - 9532 8185.0 - 8816.0 8160 7020 LINER 4 3-1/2" 8.18# L-80 8851 - 8855 8177.0 - 8181.0 10160 10530 LINER 782 3-3116" 6.2# L-80 8855 - 9637 8181.0 - 8907.0 8520 7660 LINER 2054 2-7/8" 6.16# L-80 9637 - 11691 ~~Z'~N~Of4\,! Oln"'8~ 11160 ¡' ¡ ~ ' .'. 1" . 1\ t, .f ,,!l"AJ ;"')wJbv -".;!HJ J ; ç .;..;,........ Perforation depth: Measured depth: Slotted Liner --- 9640-10127,10233-10568,10974-11658 True vertical depth: Slotted Liner -- 8909-8915, 8903-8883, 8855-8901 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 VAN TOP @ 31 - 8747 4-1/2" 12.6# L-80 @ 8749 - 8907 Packers & SSSV (type & measured depth): 9-5/8" DV Packer @ 2609 9-5/8" Baker S-3 PROD PKR @ 8660 9-5/8" Baker SAB-3 Packer @ 8798 4-1/2" HES Nipple @ 2085 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO completed --- cut 9-5/8" & cemented NEW Tie-back 9-5/8" Liner, then cut & replaced part of TBG with 4-112" Chrome TBG. 13 Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI 0 0 --- 0 Subsequent to operation: 857 3973 5784 -- 259 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ~ OilŒJ GasD WAGD GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 306-251 Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature .Å.d ..æ JJ.... JI Phone 564-5174 Date 1 0/23/06 " \ Form 10-404 Revised 4/2004 ORIGINAL RBDMS 8Ft 0 Cï 2 7 2006 TREE = 6" CrN WELLHEAD = MCEVOY ACTUA TOR = OTIS KB. ELEV = 73.48' BF. ELEV = 40.03' KOP = 3100' Max Angle = 98 @ 10172' Datum MD = 9592' Datum TVD = 8800' SS I 9-5/8" CSG, 40#, L-80 TC-IIID = 8.835" H 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 PJC DRAFT Minimum ID = 2.380" @ 9637' 3-3/16" X 2-7/8" XO 4-1/2"TBG, 12.6#, 13-CRVAM TOP, -i 8747' .0152 bpf, 10 = 3.958" I TOP OF 7" LNR H 8859' 14-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 8907' ] 1 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 9347' 1 TOP OF WHIPSTOCK H 9535' 17" LNR, 29#, L-80, .0371 bpf, 10=6.184" H 10331' X-08A 2141' 2678' IPBIDI 14-1/2" HES X NIP, 10 = 3.813" I 1 HES CEMENTER 1 19-5/8" DV PKR I GAS LIFT MANDRELS DEV TYÆ VLV LATCH 12 MMG OPEN 31 MMG DMY 31 MMG DMY 24 MMG DMY PORT DA TE o 12/20/02 o 12/20/02 o 12/20/02 o 12/20/02 ST MD TVD 4 3198 3193 3 5196 4997 2 6986 6516 1 8569 7919 RK RK RK 19-5/8" X 4-1/2" BKR S-3 PROD PKR, ID = 3.870" 14-1/2" HES X NIP, 10=3.813" I 14-1/2" HES PXX (10/07/06) I TBG STUB (TAGGED 10/04/06) 19-5/8" X 4-1/2" UNIQUE OV ERSHOT I ITBG SEAL ASSY I 19-5/8" X 4-1/2" BKR SAB-3 PKR, ID = 3.813" 14-1/2" OTIS X NIP, ID = 3.813" 1 13.7" BKR DEPLOYMENT SLY, 10 = 3.0" 13-1/2" X 3-3/16" XO, 10 = 2.80" I 4-1/2" OTIS XN NIP, MillED 10 = 3.80" (BEHIND CT LNR) 4-1/2" TBG TAIL 10 - 3.958" (BEHIND CT LNR) I MILLOUT WINDOW 9532' - 9539' 3-3/16" X 2-7/8" XO, 10 = 2.380" PERFORA TION SUMMARY REF LOG: EWR-GR ON 08/13/03 ANGLEATTOPPERF: 52 @ 9640' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SLOTTED LINER [ 3-3/16" LNR, 6.2#, L-80, .0081 bpf, 10 = 2.880" 1 4 9640 - 10127 C 08/18/03 4 10233 - 10568 C 08/18/03 4 10974 - 11658 C 08/18/03 DATE 05/31/80 08/19/03 10/12/06 07/28/06 09/03/06 10/18/06 REV BY COMMENTS ORIGINAL COMPLETION JLM/KK CTD SIDETRACK (X-OBA) D14 RWO RRD/PAG PULL IBP@8830' (04/26/06) JCM'PAG PULL PA TCH @ 8578' ?/PJC DRLG DRAFT CORRECTION 12-7/8" SLID/SOLlDLNR, 6.16#, L-80, .0555 bpf, ID= 2.372" I DATE PRUDHOE BA Y UNIT WELL: X-08A PERMIT No: '2031170 API No: 50-029-20463-01 SEC 7, T10N, R14E, 432' FSNL & 264' FWEL REV BY COMMENTS BP Exploration (Alaska) . . X-08A DESCRIPTION OF WORK COMPLETED EVENT SUMMARY TestEvent 06/27/2006 BOPD: 774 BWPD: 4,950 MCFPD: 6,898 AL Rate: 3,310 AWGRS 07/01/2006 TIO = 1540/1510/950. Temp = SI. Bleed IA & OA < 1000 psi (rapid IAxOA comm, AL FP IA). Well SI. AL casing & lateral valves SI. TBG FL @ 6400'. IA FL @ SO @ 7567'. OA FL @ surface. Bled lAP from 1510 psi to 800 psi in 2.75 hrs (bled slowly, FO request). IA AWGRS 07/02/2006 TIO = 1540/800/800. Temp = SI. Monitor WHP's post bleed (Rapid IAxOA comm, AL FP IA). TBGP & lAP unchanged, OAP increased 400 psi overnight. AL SI, ALP = 0 psi. AWGRS 07/29/2006 *** WELL SI ON ARRIVAL *** (pre rwo) UNABLE TO PULL PATCH W/.125 WIRE @ 8548' SLM, UNABLE TO GET THIRD PARTY CRANE FOR B/L TILL AFTER MIDNIGHT & RIG MOVING TO WELL NEXT DOOR IN A.M. JOB CANCELED.RDMO NOTE: 4 1/2" ECLIPSE PULLING TOOL SET IN PATCH @ 8548' SLM ***LEFT WELL SHUT IN*** AWGRS 07/31/2006 T/I/O=1180/830/830. Temp=SI. T BG & IA FL's. (Pre-EL, SCMT). TBG FL @ 3100' (48 bbl). IA FL @ 8195' sta#3 (439 bbl). AWGRS 08/23/2006 *** WELL SI ON ARRIVAL *** ( pre rwo) RIG UP BRAIDED LINE EQUIP & EXTRA RISERS *** JOB IN PROGRESS *** AWGRS 08/24/2006 (pre rwo) JARRED ON PATCH W/ BRAIDED LINE FOR APPROX 7.5 HRS @ 4000#, NO MOVEMENT *** JOB IN PROGRESS *** AWGRS 08/25/2006 (pre rwo) JARRED ON PATCH @ 8537' SLM FOR ANOTHER 4 HRS @ 4000#, UNABLE TO PULL W/ BRAIDED LINE ---- JOB INCOMPLETE---- TURN WELL OVER TO CTU *** WELL LEFT SI *** AWGRS 08/30/2006 CTU #5. Rig up. MIRU CTU. AWGRS 08/31/2006 CTU #5. Fish Eclipse Patch. RU CTU. MU BHA #1: Weatherford fishing string w/ hydraulic 4-1/2" GS. Latch fish at 8566' ctm. Pull Free after 21 jar licks(22k overpull). POOH. Trap fish in master. Freeze protect well with 40bbls 50:50 MeOH. RDMO. Pad Operator notified of well status Note: Patch was released but remained in well bore for S/L to remove. Lower packer will still need to be fished. *** CT operation completed *** AWGRS 09/03/2006 *** WELL SHUT IN *** (pre rwo) RECOVERD WFD UPPER PATCH SECTION FROM THE TREE TESTED OK FOR NORM, PAPER WORK TURNED IN TO WFD. MADE DRIFT RUN TO RECOVER MISSING RUBBER ELEMENTS (NO RECOVERY) PULLED LOWER SECTION OF PATCH AND RECOVERED ALL ELEMENTS. MADE SEVERAL ATTEMPTS TO SHIFT OTIS SLIDING SLEEVE. ****JOB STILL IN PROGRESS**** AWGRS 09/04/2006 T/I/O=1100/1250/900 Assist S/L [CTD Screen] Pumped 440 bbls down IA and 200 bbls down tbg. CMIT TxlA to 3500 psi. [PASSED]. Bled pressures down Final WHP= 125/140/320. Page 1 . . X-08A DESCRIPTION OF WORK COMPLETED AWGRS 09/04/2006 (Pre RWO) RAN SHIFTING TOOL, CAME BACK WI PIN SHEARED, SSD WON'T OPEN. RAN 4 1/2" BRUSH & 3.805 GAUGE RING, TAG DEPLOYMENT SLEEVE @ 8,832' WLM, =25' CORRECTION. LRS LOADED IA & TBG WI DEAD CRUDE, SEE LRS PUMP REPORT. SET 41/2" "XX" PLUG IN "X" NIPPLE @ 8,819' WLM, HUNG NO· FLOW I PLUG SET TAG ON THE WING VALVE. LRS PERFORMED CMIT T X IA TO 3,500 PSI. CMIT PASSED. DUMP BAILED SLUGGITS ON TOP OF 4 1/2" XX PLUG BODY. **** JOB STILL IN PROGRESS**** AWGRS 09/05/2006 SPOT EQUIPMENT.SIMOPS, TGSM, PRESSURE TEST, RIH W/TUBING PUNCH. WELL SHUT IN ON ARRIVAL. INITIAL TI II 0 = 0/180/170. AWGRS 09/05/2006 (Pre RWO) DUMP BAILED TWO BAGS OF SLUGGITS ON TOP OF 4 1/2" XX PLUG @8,819' SLM. (TOP OF SLUGGITS @8,805' SLM) RDMO. ****4" 1/2" XX PLUG IN HOLE, NOTIFIED DSO OF WELL STATUS**** AWGRS 09/06/2006 BEGIN CHEM CUTTING 4-1/2" TUBING. WELL SHUT IN ON ARRIVAL. INITIAL TI II 0 = 0/180/170. JOB CONTINUED ON 6-SEP-2006 AWGRS. CUT TUBING AT 8748' TUBING TALLY DEPTH. SEVERING HEAD LOOKS GOOD. JOB COMPLETE. AWGRS 09/07/2006 T/I/O=80/130/130, Temp=SI. Bleed Well pressures to 0 psi (for PPPOT). AlLP= 20 psi, shut-in @ casing valve. Bled OAP from 130 psi to 0 psi in 15 min (fluid to surface). Monitored pressure for 30 min, OAP remained at 0 psi. FWHP=80/13010. AWGRS 09/08/2006 Circ out (Pre RWO) Job postponed due to high level alarms. AWGRS 09/10/2006 T/I/O= XXX Circ Well bore & Freeze Protect TxlA (Shut In){ Circ-Out RWO) Pumped into TBG Takeing Returns from IA to Flowline. 5 bbls 60/40 Meth, 1120 1 % KCL, 27 bbls Meth, 8 bbls Diesel, 82 bbls 60/40 Meth, 8 bbls Diesel, 27 bbls Meth ....Let U- tube,...Bleed Tubing down to 0 psi....Freeze protect flowline with 7 bbls methanol and 83 bbls crude....FWHP = 50 120 180 AWGRS 09/14/2006 T/I/O= 30155/55. Temp= SI. ALP= 20 psi (SI at the lateral and casing valves). Bleed WHP's to 0 psi (pre-PPPOT-T, IC). Bled IAPIOAP from 57 psi to 0 psi in 2.5 hrs. TP went on a vac during bleed. Monitored WHP's for 30 minutes. Final WHP's= Vac/OIO. AWGRS 09/14/2006 POA: T/IAlOA = SI{VAC)/OIO ( BAD LOCKDOWN SCREWS) PPPOT-IC = PASSED I CHANGED OUT LOCKDOWN ASSEMBLIES. DHD TECH- GRANT CHIACCHIA ON SITE MONITORING BLED ON IA AND OA. REMOVED (12) LOCKDOWN SCREWS, CHASED LOCKDOWN AND GLAND THREADS, INSTALLED NEW LOCKDOWN PINS, PACKING, JUNK RINGS AND GLAND NUTS. TORQUED TO 500 FT/LBS. RIGGED UP TEST EQUIPMENT, PUMPED UNTIL CLEAN FLUIDS WERE ACHIEVED. PRESSURED UP VOID TO 3,800 PSI. FOR 30 MINS. - PASSED. AWGRS 09/15/2006 T/IAlOA = SIIOIO (Pre Rig Inspection) PPPOT-T = Passed Bled tubing hanger void to 0 psi. Functioned and torqued 550 Nibs. Rigged up equipment and pumped until clean fluid returns were achieved. Pressured up tubing hanger to 5,000 psi. for 30 mins. = (Passed) AWGRS 09/15/2006 SET BPV , PRE RIG DIMS 09/18/2006 Skid floor, Move from X-01 to X-08, Pull BPV, RU tiger tank to circulate freeze protect from well Page 2 AWGRS 09/18/2006 DIMS 09/19/2006 DIMS 09/20/2006 DIMS DIMS . . X-08A DESCRIPTION OF WORK COMPLETED PULLED BPV AFTER THE RIG MOVED OVER THE WELL Cir freeze protect out, Set & test TWC, ND, NU, Test BOPE, Pull TWC, Engage hanger w/spear,Establish cir, Pull on tbg, Parted tbg, LD hanger and tbg, (Recovered 40 jts) RIH wlrope spear, Retrieve control line, RIH w/o-shot on 41/2" work string, Engage fish, RU SWS, RIH w/3.73" drift (no go), RIH w/2 1/8" & 3.25" drifts (will go), RIH w/3.58" drift (no go), RIH w/3.445" drift (will go), RIH & shoot 3 strand string shot. 09/21/2006 Run string shot, Run chemical cuttter, Cir and work pipe, Tbg parted, POH,LD recovered tbg, RIH wI rope spear, Recover control line. 09/22/2006 RIH and dress off tbg stub, RIH wlovershot, Engage and verify fish, RIH w/3.73 drift, RIH w/jet cutter and cut @ 8755' (no success), RIH wlstring shot then chemical cutter and cut at 2194'(successful), POH w/wireline, POH wlwork string to fish. DIMS 09/23/2006 DIMS 09/24/2006 DIMS 09/25/2006 DIMS 09/26/2006 DIMS DIMS DIMS DIMS DIMS LID recovered fish, RIH w/O-shot, Engage fish, RIH & free point @ 8680', Drift w/3.73 to 8800', RIH wlchem cut & cut @ 8680',RD SWS, Cir hole clean. Cir, LD 41/2" work string, LD 41/2" BTC tbg, Test casing(good), MU washover BHA, Cut drlg line, RIH. RIH, Wash & mill to 8765', Cir hole clean, POH, LD BHA & Fish,MU dress off BHA, RIH, Dress off stump, POOH. Install test plug - Change rams - Test - RD test equipment - Install wear ring - MU 9 5/8" RBP - RIH set RBP at 3000' - Test to 1000 psi fl5 min. - Dump I spot 20/40 Sand - RIH tag sand at 2929' - POH - LD running tool- RU test equip - PJSM - Test BOPE. 09/27/2006 Test BOP's - MU 9 518" casg cutter - RIH - Cut casg - Displace out Artic pack - POH 2 stands - MU 9 5/8" Storm I set at 90' - LD running tool - Test - PJSM - pull wear ring - Install test plug wI 9 5/8" - RU test equip - C/O rams to 9 5/8" - Test rams. 09/28/2006 NO - X/O tubing spool - NU BOPs - RU I test breaks - Pull storm packer - cont. POH - LD cutter assy. - MU spear assy. - engage 95/8" casing I pull to rig floor - Circulate - LD spearlcut jt. - LD 9 5/8" csg - Repair riser I repair cuttings drag chain. 09/29/2006 LD 9 518" casing - Install test plug - C/O rams to 31/2" x 6" VBRs - Test - MU clean out assy. - RIH to 2428' - Displace - POH - MU wash pipe assy. - RIH - Washover 9 5/8" csg stump @ 2121' - Wash to 2150' - Circulate - POH. 09/30/2006 POH/LD BHAlMU Back-out tool/RIH/Back out 95/8" casg stump/POH/LD BHAlPU spear assy/RIH/Engage stump back ouUPOH/LD fish-BHAlRU casg equip/Change rams to 9 5/8"/PU Run 9 5/8" casgl Repair pipe skate/Run casg. 10101/2006 Screw into 95/8" casg/Pull test to 250K/Attempt to test casg/No tesUOpen ES Cementer/Circ/Cement 95/8" casg/ND BOP's/NU tubing spool/TesUNU BOPs/Change rams/TesUMU BHAlRIH/Drill cmUES Cementer/RIH to 2929 Drill junk/Displace to SW- RU test equip. Page 3 . . X-08A DESCRIPTION OF WORK COMPLETED DIMS 10102/2006 Cont. test 9 5/8" casing I POH fl 2950' - LD BHA - MU rev. circ assy. - RIH to 2950'- Wash to 2986' - POH - LD BHA - MU RTTS - RIH - Set - Test csg. @ 2118' I 2151' I 2907' - POH - LD RTTS - MU RBP ret. tool- RIH. DIMS 10103/2006 RIH - Latch RBP - POH - LD RBP - Test 95/8" csg - MU BHA - RIH - Rot. wash inside 4 1/2" stump fl 8825' to 8836' - Circ. - POH - Test BOP's. DIMS 10104/2006 Test BOP's - MU 4" Spear assy - Set 9 5/8" Storm packer - Change out rams - Test - Pull XX Plug - Shoot fluid levels - LD 4" DP. AWGRS 10104/2006 TIIIO=OIOIO. SI. IA FL (for RIG). FinallA FL @ 1440'. DIMS 10105/2006 LD 4" DP - LD BHA - RU tubing equipment - PU I Run 41/2" Completion- AWGRS 10106/2006 ** ASSIST DOYON 14** PULLED RHC FROM 8701' SLM. DRIFTED WI 2' STEM, 3.80" CENT, SAMPLE BAILER TO 8,882' SLM (TIGHT SPOT @ 8,778' SLM) MEMORY LOG TUBING FROM 8,500 ' SLM DOWN TO 8,950' SLM AND BACK UP TO 8,500' SLM @ 40 FPM SET 4.5" RHC @ 8701' SLM STAND BY FOR RIG TO DROP B&R FOR GOOD TEST. ** TURNED WELL OVER TO RIG** DIMS 10106/2006 Space out TBG - WO landing Jt. - Land TBG - RILD - RU SLB slickline - RIH ret. RHC plug - Log - WO SLB tools - Log - RD Lbricator - Pump treated Inhibited SW - Drop ball & Rod - AWGRS 10107/2006 ABLE TO TEST RHC PLUG TO 3000 PSI, WHEN CMIT WAS DONE. TBGIIA LEAKING,TROUBLESHOOT. PULL B&R @ 8,695' SLM, PULL RHC @ 8,701' SLM SET 4.5" PX PLUG @ 8,701' SLM (PLUG BODY HAS 4-3/16" HOLES.102" PRONG, 1 7/8" BODY, 1 3/4" FN) @ 8698' SLM. RIG TESTED TUBING,STILL LEAKING. DIMS 10107/2006 Chasing Tubing I IA leaks AWGRS 10108/2006 PULLED 1 112" RK- DCR FROM STA 4 @ 3212' SLM. SET 1 1/2" RK-DGLV IN STA 4 @ 3212' SLM. RE-MIT-T, FAILED, CMIT TO 3500 PSI, PASSED. PULL RK DGLV FROM STA. # 4 @ 3,212' SLM (STA. # 4 LEFT EMPTY) **RELEASED FROM RIG** DIMS 10108/2006 Test tubing I IA - Pull Blank - RD Slickline - Install TWC test to 1000 - ND BOP's - NU Adapter Tree - Test Adapter to 5K Tree 1 K - Freeze protect - Install BPV - Test to 1000 DIMS 10109/2006 Tested tree to 5K 15 mins - RU DSM - Pull TWC -Install BPV _ RD DSM - Secure Well _ Rig Released 03:00 Hrs 10/9/2006 Page 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 9/18/2006 16:00 - 16:30 0.50 MOB P DECOMP PJSM - Skid rig floor 16:30 - 17:30 1.00 MOB P DECOMP Move rig off well X-01 17:30 - 20:00 2.50 MOB P DECOMP Move rig and spot on well X-08 20:00 - 20:30 0.50 MOB P DECOMP Skid rig floor - Spot and berm rockwasher 20:30 - 21 :00 0.50 MOB P DECOMP RU rig floor - Take on seawater to pits 21 :00 - 22:00 1.00 DHB P DECOMP RU lubricator - Pull BPV (Accepted rig @ 2100 hours) 22:00 - 00:00 2.00 EV AL P DECOMP Spot tiger tank - Run hardline from tiger tank to rig - RU to circulate 9/19/2006 00:00 - 00:30 0.50 EVAL P DECOMP Continue RU to circulate to tiger tank - Check with air for leaks 00:30 0 03:00 2.50 EVAL P DECOMP PJSM - Rev cir 40 bbls freeze protect out of tubing with seawater (138 gpm @ 350 psi) - Circulate 140 bbls freeze protect out of IA (220 gpm @ 680 psi) - Wait 30 minutes for migration - Cir 40 bbls seawater (168 gpm @ 640 psi) 03:00 - 04:00 1.00 EVAL P DECOMP Install TWC - RU and test from below to 1000 psi for 5 min on chart, test from above to 3500 psi for 5 min on chart - RD test equipment 04:00 0 06:30 2.50 EVAL P DECOMP RD hardlines - ND tree and adaptor flange 06:30 - 09:00 2.50 BOPSU P DECOMP NU BOPE, riser, and flowline 09:00 - 09:30 0.50 BOPSU P DECOMP RU test equipment 09:30 - 14:00 4.50 BOPSU P DECOMP Test BOPE - Test was performed w/ 4" - Annular 250 psi low / 3500 psi high - 3 1/2" x 6" top rams - Choke manifold - HCR choke / kill - Manual choke / kill - Floor safety valves 0 Upper / Lower IBOP - 2 7/8" x 5" lower rams - Perform Accumulator test - Blind rams - 250 psi low / 3500 psi high, Pull 4" test joint 0 Install 4 1/2" test joint - Test top VBR's 31/2" X 6" to 250 low 3500 high all tests 5 minutes each. All tests witnessed by WSL - Chuck Scheve with AOGCC waived witness of test 14:00 - 14:30 0.50 BOPSU P DECOMP RD test equipment 14:30 - 15:30 1.00 EVAL P DECOMP RU lubricator - Pull TWC - RD lubricator 15:30 - 16:00 0.50 EV AL P DECOMP Mobilize spear assembly to floor 16:00 - 17:30 1.50 PULL P DECOMP PJSM - MU spear - Stab into hanger - BOLD's - Pull 280K, no sucess - Establish circulation (1950 psi @ 360 gpm) 0 Work from 200K to 300K with 50K block weight - Tubing parted leaving 70K w/ blocks hanging weight 17:30 - 18:00 0.50 PULL P DECOMP Pull hanger to floor and circulate surface to surface 18:00 - 19:30 1.50 PULL P DECOMP RU to LD tbg - Break out spear - LD hanger 19:30 - 20:00 0.50 PULL P DECOMP Inspect derrick - PJSM 20:00 - 22:30 2.50 PULL P DECOMP LD 40 joints 41/2" tubing, 1 tbg collar, 19 clamps, 2 stainless steel bands, and recovered control lines 22:30 - 23:30 1.00 PULL P DECOMP RD control line spool and mobilize fishing tools to floor 23:30 - 00:00 0.50 PULL P DECOMP Install wear bushing 9/20/2006 00:00 - 00:30 0.50 PULL P DECOMP MU rope spear assembly 00:30 - 01 :30 1.00 PULL P DECOMP RIH to 1740' (rotate every 5 stands) 01 :30 - 02:30 1.00 PULL P DECOMP Rotate and engage fish down to 1740' (5-100verpull @ 1725') -PU 75, SO 75 02:30 - 03:00 0.50 PULL P DECOMP POOH from 1740' to 26' 03:00 0 03:30 0.50 PULL P DECOMP Remove recovered control line off rope spear 03:30 - 04:00 0.50 PULL P DECOMP RI H with rope spear to 1736' 04:00 - 04:30 0.50 PULL P DECOMP Rotate and engage fish @ 1740' 04:30 - 05:00 0.50 PULL P DECOMP POOH - LD rope spear assembly (no control lines recovered) 05:00 - 06:30 1.50 PULL P DECOMP Clear floor - Mobilize Overshot assembly - RU to run 4 1/2" tubing work string 06:30 - 09:30 3.00 PULL P DECOMP MU overshot assembly - RIH with 4 1/2" NSCT tubing work Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 9/20/2006 06:30 - 09:30 3.00 PULL P DECOMP string to 1691' ( PU 70, SO 70) 09:30 - 10:00 0.50 PULL P DECOMP Space out for working height above rig floor - Engage fish @ 1736' - PU to 150K - Set string in slips @ 70K 10:00 - 10:30 0.50 PULL P DECOMP Clear floor - RD tubing equipment 10:30 - 12:30 2.00 EV AL P DECOMP PJSM - RU SWS - MU packoff, pump-in sub, NSCT X-over 12:30 - 14:30 2.00 EV AL P DECOMP RIH with 3.73" swedge on wireline - could not get past 1736' 14:30 - 15:30 1.00 EVAL P DECOMP RIH with 2 1/8" weight bar to 2300' - No problems 15:30 - 16:30 1.00 EVAL P DECOMP RIH with 3.25" swedge to 2300' - No problems 16:30 - 17:30 1.00 EVAL P DECOMP RIH with 3.58" drift - Would not go past 1736' 17:30 - 19:00 1.50 EVAL P DECOMP Wait on SWS tools (Send 3.58 drift to Baker and have it cut to 3.445" drift) 19:00 - 22:00 3.00 EVAL P DECOMP RIH with 3.445" drift to 8840' - No problems 22:00 - 00:00 2.00 EVAL P DECOMP PJSM - RIH with string shot - Pull 25K over string weight - Spot 3 strand shot @ 8743' - 8755' - Fire shot 9/21/2006 00:00 - 01 :30 1.50 EVAL P DECOMP POH w/ string shot assembly (shot fired). 01 :30 - 02:30 1.00 EVAL P DECOMP LD string shot assembly - PJSM - PU 3 3/8" chem. cutter 02:30 - 04:00 1.50 EVAL P DECOMP RIH w/ chem cutter- Spot at 8752.5' and fire shot - No indication of firing - 04:00 - 07:30 3.50 EVAL P DECOMP POH w/ C.C. - PJSM - LD cutter (shot fired). 07:30 - 12:30 5.00 EVAL P DECOMP Pull on pipe w/230K + blocks (18' stretch, no pipe movement) - RU & cir w/8 bpm @ 550 psi while continuing to work pipe 70K down to 280K up including blocks (80% of 4 1/2" tensile rating) -Continue working pipe while waiting for SWS tools - Pipe parted @ 275k up weight leaving 73K hanging weight 12:30 - 14:00 1.50 EVAL P DECOMP Inspect top drive - LD SWS tools - RU to POOH with 4.5" tubing work string 14:00 - 17:30 3.50 FISH P DECOMP PJSM - POH LD 4 1/2" tubing work string 17:30 - 19:00 1.50 FISH P DECOMP LD overshot and recovered 41/2" 12.6# BTC tubing (7 joints, 1 tubing collar, 4 clamps recovered = 290.91 'total length) 19:00 - 19:30 0.50 FISH P DECOMP Clear floor - Mobilize rope spear and jars to floor 19:30 - 20:30 1.00 FISH P DECOMP MU rope spear assembly 20:30 - 21 :00 0.50 FISH P DECOMP RIH to 1806' - Tag fish 21 :00 - 21 :30 0.50 FISH P DECOMP Rotate and engage fish - POOH to 38' 21 :30 - 22:00 0.50 FISH P DECOMP Remove recovered control line from rope spear 22:00 - 23:00 1.00 FISH P DECOMP RIH with rope spear to 2020' 23:00 - 00:00 1.00 FISH P DECOMP Rotate and attempt to engage fish - POOH 9/22/2006 00:00 - 01 :30 1.50 FISH P DECOMP Make service breaks - LD rope spear, drain sub - Clear floor- MU dress off assembly 01 :30 - 03:00 1.50 FISH P DECOMP RIH to 2019' - Screw in T.D. - Obtain parameters 03:00 - 03:30 0.50 FISH P DECOMP Tag T.O.F. at 2028' - Dress off OD & ID of 4 1/2" tubing w/ 9 bpm 590 psi 50 rpm 1 k torque - PU wt 80k- SO wt 80k RT wt 80k 03:30 - 04:30 1.00 FISH P DECOMP POH - LD dress off assembly - OD & ID mills showed good wear pattern 04:30 - 05:00 0.50 FISH P DECOMP PJSM - RU to run 4 1/2" tubing workstring 05:00 - 08:30 3.50 FISH P DECOMP MU 8 1/8" overshot wi 41/2" grapple - PU 4 1/2" 12.6# tubing to 1988' 08:30 - 09:00 0.50 FISH P DECOMP Obtain parameters - Engage fish at 2028' - Slight overpull to ensure catch 09:00 - 09:30 0.50 FISH P DECOMP PJSM - RD tubing equip. - RU SWS 09:30 - 12:00 2.50 EVAL P DECOMP RIH wi 3.73" drift to 8800' - POH w/ drift 12:00 - 13:00 1.00 EVAL P DECOMP LD drift - PJSM - PU 3.65" power jet cutter 13:00 - 15:30 2.50 EVAL P DECOMP RIH w/ jet cutter - Taking weight at 7880' - PU to 7780' - Pull Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/1 8/2006 10/8/2006 14 Spud Date: 5/10/1980 End: 9/22/2006 13:00 - 15:30 2.50 EVAL P DECOMP tension on string w/ 25k over string wt. - Continue in hole - Spot cutter at 8755' - Fire cutter wI good indication of shot - POH wI cutter - LD same - Cutter fired normal. 15:30 - 18:30 3.00 EVAL P DECOMP PJSM - PU string shot assembly & RIH & Fire @ 2194' - Good indication of shot - POH - String shot fired normal 18:30 - 21 :00 2.50 EVAL P DECOMP RIH wI chemical cutter - Pull tension on string w/10K over string weight - Spot chemical cutter at 2194' - Successful cut - POOH - RID wireline 21 :00 - 22:00 1.00 EVAL P DECOMP PJSM - RU compensator and tubing equipment 22:00 - 00:00 2.00 EV AL P DECOMP POOH LD work string to overshot and fish 9/23/2006 00:00 - 01 :00 1.00 FISH P DECOMP LD fish - Recovered 3 joints + cut jt (15.92'), SSSV & pups, 1 control line clamp, 2 S.S. clamps & remainder of control line. (Total clamps recovered = 24 control line clamps and 3 stainless steel bands) 01 :00 - 01 :30 0.50 FISH P DECOMP Clear floor - Change bails - Change grapple in overshot 01 :30 - 04:30 3.00 FISH P DECOMP RIH w/4 1/2" NSCT workstring to 2160' 04:30 - 05:00 0.50 FISH P DECOMP Change to long bales for W.L. purposes - RD tubing tongs 05:00 - 05:30 0.50 FISH P DECOMP Obtain parameters - Engage fish at 2194' - Pull 50k over to verify catch and pipe integrity before free point 05:30 - 06:30 1.00 EVAL P DECOMP PJSM - Hang sheave in derrick - RU SWS 06:30 - 08:00 1.50 EVAL P DECOMP RIH w/ free point tool to 8706' - Attempt to obtain free point- Tool not reading 08:00 - 09:00 1.00 EVAL P DECOMP POH wI free point tool 09:00 - 10:00 1.00 EVAL P DECOMP Change out W.L. head & test 10:00 - 13:00 3.00 EVAL P DECOMP RIH wI free point to 8706' - Obtain reading at 8680' (pipe free in first joint above Sliding Sleeve) - RIH to 8735' - Obtain reading (pipe stuck at first joint below Sliding Sleeve) - POH and confirm free point at 8680' (reading free)- POH w/ free point. 13:00 - 15:30 2.50 EV AL P DECOMP LD F.P. tools - PU 3.73" drift - RIH to 8800' - POH w/ drift 15:30 - 18:30 3.00 EV AL P DECOMP PJSM - PU & RIH w/2 strand string shot - Spot shot across middle of joint at 8680' and fire - POH 18:30 - 22:30 4.00 EVAL P DECOMP M/U - RIH wI chemical cutter - Cut pipe @ 8680' (cut successful) - POOH - RID wireline 22:30 - 00:00 1.50 EVAL P DECOMP RU - Pump hi-vis sweep - Circulate hole clean (PU 142, SO 120,435 gpm, 770 psi) 9/24/2006 00:00 - 00:30 0.50 EV AL P DECOMP Continue circulate hole clean 00:30 - 03:30 3.00 EV AL P DECOMP POOH UD work string and overshot with cut tubing stub in o-shot. 03:30 - 04:00 0.50 EVAL P DECOMP CO bails - RD compensator -RU LD 4 1/2" BTC tubing 04:00 - 09:30 5.50 PULL P DECOMP UD 41/2" BTC 12.6# tubing. 09:30 - 10:30 1.00 PULL P DECOMP Service rig - Repair pipe skate 10:30 - 12:00 1.50 PULL P DECOMP Continue to LD 41/2" BTC tubing - Recovered 150 jts + top & bottom cut jts. (20.20' & 19.25') - 5 GLM's 12:00 - 13:00 1.00 PULL P DECOMP PU overshot - Release fish - Make service breaks 13:00 - 13:30 0.50 PULL P DECOMP RD tubing equip. - Clear floor - RU to test casing 13:30 - 14:30 1.00 EVAL P DECOMP Close blind rams - Test 9 5/8' casing to 3500 psi for 30 min. on chart (Test good) - RD test equipment 14:30 - 15:30 1.00 FISH P DECOMP Clean up rig - Install wear ring - Mobilize BHA to rig floor. 15:30 - 17:30 2.00 FISH P DECOMP MU wash pipe BHA & PU DC's 17:30 - 19:00 1.50 FISH P DECOMP PJSM - Cut drill line - Service top drive and blocks 19:00 - 00:00 5.00 FISH P DECOMP RIH with 4" drill pipe from derrick - Continue in hole with singles from pipe shed to 6910' (PU 173 SO 148) 9/25/2006 00:00 - 01 :30 1.50 FISH P DECOMP Continue RIH to 8650' - Obtain parameters - PU wt. 200k - SO Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X -08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 9/25/2006 00:00 - 01 :30 1.50 FISH P DECOMP wt. 160k - ROT wt. 50 rpm - TO 3-5k 01 :30 - 02:30 1.00 FISH P DECOMP Break circulation w/7 bpm 1250 psi - Wash down & tag top of fish at 8676' - Milling on hard spot fl 8700'-8705' 02:30 - 04:00 1.50 FISH P DECOMP Pump H.V. sweep & continue to wash down. Tag top of 41/2" x 7" XO at 8765' 04:00 - 05:00 1.00 FISH P DECOMP Pump H.V sweep around w/10 bpm 2350 psi 05:00 - 09:30 4.50 FISH P DECOMP POH to BHA at 399' 09:30 - 10:30 1.00 FISH P DECOMP Stand back DC's - LD jars, boot basket 10:30 - 12:30 2.00 FISH P DECOMP Change elevators - LD top jt wash pipe - Retrieve fish from wash pipe - Recovered top cut joint (23.60') - Sliding sleeve wI pups (24.30') - bottom cut joint (20.30') - 2 short cut pieces from bottom (3.83' & 1.37') - LD wash pipe. 12:30 - 13:00 0.50 FISH P DECOMP Clear floor - Mobilize dress oft BHA to rig floor 13:00 - 14:00 1.00 FISH P DECOMP PJSM - MU dress oft BHA 14:00 - 17:30 3.50 FISH P DECOMP RIH from 316' to 8749' 17:30 - 18:00 0.50 FISH P DECOMP Dress oft OD & ID of tubing stump @ 8749' (PU 208, SO 161, RW 180, RPM 50, TO 5, GPM 200 @ 590 psi) 18:00 - 19:00 1.00 FISH P DECOMP Reverse circulate 3 bottoms up at 1800 psi @ 340 gpm - Observe well - Pump dry job 19:00 - 22:00 3.00 FISH P DECOMP POOH from 8749' to 316' 22:00 - 23:00 1.00 FISH P DECOMP Stand back drill collars - LD dress off BHA 23:00 - 00:00 1.00 EVAL P DECOMP Clear rig floor - Pull wear ring - Install test plug with 9 5/8" test joint 9/26/2006 00:00 - 01 :00 1.00 BOPSU P DECOMP PJSM - Change top rams to 9 5/8" 01 :00 - 01 :30 0.50 BOPSU P DECOMP Test rams to 250 psi low 3500 high 01 :30 - 02:00 0.50 BOPSU P DECOMP RD test equip. - Install wear ring - Clear floor 02:00 - 04:00 2.00 EVAL P DECOMP PJSM - Mobilize SWS tools to floor - RU shooting nipple wI pump in sub & wireline packoff - LD shooting nipple - Build tools for USIT log run - PU shooting nipple assembly - Run tool string through same. 04:00 - 14:30 10.50 EVAL P DECOMP RIH wi USIT to 8720' - Log up in cement/corrosion mode to 100' - T.O.C. at 2600' - LD US IT tools - PJSM - RU & RIH wi string shot - Spot across casing collar at 2143' WLM and fire- POH - RD SWS 14:30 - 15:00 0.50 BOPSU P DECOMP Clear rig floor - Pull wear ring - Install test plug - Change top rams to 3 1/2" x 6" variables - test wI 4" test joint to 250 psi low, 3500 high 15:00 - 16:30 1.50 BOPSU DECOMP Change top rams to 3 1/2" x 6" variables - test wI 4" test joint to 250 psi low, 3500 high - Pull test plug - Install wear ring 16:30 - 17:00 0.50 DHB P DECOMP PU I MU HES 9 5/8" RBP - 17:00 - 19:00 2.00 DHB P DECOMP RIH slow - Set @ 3000' middle of element - Top of plug 2996' 19:00 - 20:00 1.00 DHB P DECOMP RU test equipment - Test RBP to 1000 psi - 15 mins - Record on chart - RD testing equipment 20:00 - 22:30 2.50 DHB P DECOMP Dump 2200# 20/40 sand - Pump 15 bbls @ 1.6 bpm - POH 1 stand - Pump 15 bbls @ 1.6 bpm - Wait 1 hour - RIH tag sand @ 2929 22:30 - 23:30 1.00 FISH P DECOMP POH - LD running tool for RBP - Pull wear ring 23:30 - 00:00 0.50 BOPSU P DECOMP Install test plug - RU testing equipment - Testing BOP's 9/27/2006 00:00 - 04:30 4.50 BOPSU P DECOMP Test BOP's - Annular 250 low 3500 high 5 mins each test - Top rams 3 1/2" x 6" VBR's - Choke manifold - HCR Choke I Kill - Manual Choke I Kill - Upper I Lower IBOP - Floor safety valves - Lower VBR's 2 7/8" X 5" - 250 low 3500 high 5 mins each test - Perform Accumulator test - Blind rams 250 low 3500 high 5 Printed: 1019/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X -08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 8/18/2006 10/8/2006 14 Spud Date: 5/10/1980 End: mins each test - All test witnessed by WSL - John Spaulding with AOGCC waived witness of test - Close annulus valves - RD testing equipment - Pull test plug - Install wear ring 04:30 - 05:00 0.50 FISH P DECOMP PU I MU Baker 9 5/8" cutter assy 05:00 - 06:30 1.50 FISH P DECOMP RIH to 2160 - Screw in TD - Obtain parameters - Locate casing collar @ 2141' - Pull up 20 ' to 2121' 06:30 - 07:30 1.00 FISH P DECOMP Begin rotating wI 80 RPM, 1 k torque - Bring pumps on and observe torque increase - Cutting casing wI 6 bpm 720 psi - Casing cut at 2121' 07:30 - 08:30 1.00 FISH P DECOMP Stop pumps - Observe well - Close annular - PJSM - Line up to pump down DP and out 13 3/8" x 9 5/8" annulus to tiger tank - Pump w/1.5 bpm - Broke over wI 4.5 bbls pumped 1950 psi - Establish circulation wI 2.3 bpm 1340 psi 15 bbls away 08:30 - 10:00 1.50 FISH P DECOMP PJSM wI Hot Oil - RU Hot Oil - Test lines to 3000 psi 10:00 - 11 :30 1.50 FISH P DECOMP Pumping 125 bbls hot diesel down DP and into OA - Initial circulating pressure 1350 psi at 1.5 bpm - final circ. pressure 400 psi at 1.7 bpm 11:30 -16:30 5.00 FISH P DECOMP Displace hot diesel from DP and spot in OA - Let soak for 1 hr- Pump 125 bbls 140 degree seawater 4 bpm @ 550 psi - Pump 75 bbls of hot diesel 1.68 bpm @ 400 psi - Pump 35 bbls Safe Surf 0 followed by 40 bbls Hi-Vis sweep 5 bpm @ 710 psi -Shut down - Open Annular - Con't circulating taking returns into the pits - Flow check - RD circulating lines 16:30 - 18:00 1.50 FISH P DECOMP Cut Drlg line - Service top drive I blocks I rig 18:00 - 20:30 2.50 DHB P DECOMP Clear floor - POH 2 stands - PU I MU HES 9 5/8" Storm packer - RIH @ 90' set - POH 1 stand - Close Blinds - RU testing equipment - Test to 3500 psi for 10 mins - Record on chart- Blow down lines - RD testing equipment 20:30 - 23:00 2.50 BOPSU P DECOMP Pull wear ring - Install test plug with 9 5/8" test joint - Change out top VBR's 31/2" x 6" to 9 5/8" casing rams - Test to 250 low 3500 high 5 mins each test - Record on chart 23:00 - 00:00 1.00 BOPSU DECOMP PJSM - Nipple down BOP's 9/28/2006 00:00 - 01 :00 1.00 BOPSU DECOMP ND I Remove tubing spool 01 :00 - 01 :30 0.50 BOPSU DECOMP Remove plastic packing from top of emergency slips - Install handles on slips - Re-instasll plastic packing on top of slips 01 :30 - 03:30 2.00 BOPSU DECOMP NU BOPs - Choke line (add 2' extension) - Riser - Flowline 03:30 - 04:30 1.00 BOPSU DECOMP RU testing equipment - Close Blinds - Test lower breaks to 250 low 3500 high 5 mins each test - Record on chart - Close annulus valve - RD testing equipment - Blow down Kill line I Choke manifold 04:30 - 05:30 1.00 DHB P DECOMP MU HES Retrieving tool - RIH - Screw into HES 9 5/8" Storm packer - POH - LD Retrieving tool I 9 5/8" Storm packer 05:30 - 07:00 1.50 FISH P DECOMP Con't POH with Baker 9 5/8" Multi String cutter - LD cutter assy - Clear rig floor 07:00 - 11 :00 4.00 FISH P DECOMP PJSM - MU Baker 9 5/8" Spear - Engage 9 5/8" csg - Set grapple - ROLDS - PUWT 300k I broke over to 280k, 1.5 BPM I 750 PSI - Pull 9 5/8" csg to rig floor - Mobilize casing equipment to rig floor 11 :00 - 12:30 1.50 FISH P DECOMP Circulate out artic pack wI hot sea water - 10 BPM I PP 320 - RU casing equipment to LD 9 5/8" casing 12:30 - 14:00 1.50 FISH P DECOMP LD Baker spear assy. I remove 9 5/8' casing slips ( emergency slip handle missing) LD 9 5/8" cut joint 14:00 - 20:00 6.00 FISH P DECOMP LD 9 5/8" 1 x1 to pipe shed - LD 41 joints I average UPWT 150k Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08A X-08 WORKOVER DOVON DRILLING INC. DOVON14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 9/28/2006 14:00 - 20:00 6.00 FISH P DECOMP to 200k - joint 41 to 46 working up to 340k ( large chunks hard cement coming up wI pipe falling back into stack) Break out torque 35 to 45K - (Well head 1133/8" casg 1 to 1 1/2" travel) 20:00 - 22:00 2.00 FISH P DECOMP Repair riser (traveled up 3" to 4" due to cement compaction) repositioned I secured 22:00 - 00:00 2.00 FISH P DECOMP PJSM - Repair cuttings drag chain (came off track lover load wI cuttings) realigned drag chain I flushed cuttings load out of chute 9/29/2006 00:00 - 03:00 3.00 FISH P DECOMP LD 95/8" casing joints 47 to 491 UPWT 75k to 200k - LD Joints 50 to 52 I UPWT 65k to 90k - LD cut joint - RD casing equipment - Clear rig floor (recovered 1 9 5/8" cut jt. 24.55' I 53 joints 47# 9 5/8" casing I 1 cut jt. 18.88') 03:00 - 04:00 1.00 FISH P DECOMP PU Baker spear assy.to rig floor - Release spear from 9 5/8" casg - LD spear - 9 5/8" casg 04:00 - 06:30 2.50 BOPSU P DECOMP PJSM - Install test plug - Change 9 5/8" casg rams to 31/2" X 6" VBR's - Test to 250 low 3500 high 5 mins each test - RD test equipment - Close annulus valve - Pull test plug - Install wear ring 06:30 - 07:00 0.50 FISH P DECOMP Moblize clean out assy to rig floor 07:00 - 09:00 2.00 FISH P DECOMP MU 9 5/8" scraper assy 09:00 - 10:00 1.00 FISH P DECOMP RIH with clean out assy from 336' to 1189' - CBU I GPM 380 I PP 370 10:00 - 13:00 3.00 FISH P DECOMP RIH fl 1189' to 2096' - Tag fill @ 2096' - CBU I GPM 635 I PP 1650 - Wash and ream fill to 2121' (top of stump) - Enter 9 5/8" stump @ 2121' wash to 2428' 13:00 - 14:00 1.00 FISH P DECOMP CBU I GPM 650 I PP 1780 I RPM 50 - Pump 40 bbl high visc polymer sweep 14:00 - 15:00 1.00 FISH P DECOMP Displace sea water wI hot 9.8 ppg Nacl brine I GPM 650 I PP 2080 - Observe well fl flow 15:00 - 17:00 2.00 FISH P DECOMP POH fl 2428' to 336' - Stand back collars in derrick - LD 9 5/8" scraper assy. 17:00 - 18:00 1.00 FISH P DECOMP Clear rig floor - Mobilize Baker wash pipe assembly to rig floor - PJSM 18:00 - 21 :30 3.50 FISH P DECOMP MU 113/4" wash pipe assy. - RIH fl 332' to 2121' - Wash over 9 5/8" csg stump at 2121' - Wash over collar at 2141' - Cont. washing down to 2150' I BPM 7.5 I PP 430 I RPM 40 I TQ 4·5k 21 :30 - 23:30 2.00 FISH P DECOMP Pump 40 bbl polymer sweep - Circulate sweep surface to surface I BPM 8.5 I PP 600 - RU to reverse circulate - Reverse circulate 1.5 drill pipe volumes I BPM 31 PP 1900 - Pull up hole to 2140' (above collar) - Circulate 2 bottoms up - BPM 111 PP 800 23:30 - 00:00 0.50 FISH P DECOMP Check well fl flow - POH wI Baker wash pipe assy. 112141' to 1500' 9/30/2006 00:00 - 00:30 0.50 FISH P DECOMP Continue POH 00:30 - 02:30 2.00 FISH P DECOMP LD BHA . Clear floor 02:30 - 04:30 2.00 FISH P DECOMP MU backoff tool BHA 04:30 - 06:30 2.00 FISH P DECOMP RIH - Spot power section across 9 5/8" casing collar at 2141' 06:30 - 07:30 1.00 FISH P DECOMP Pressure to 1000 psi to set lower anchor - Slack off 15k wt on anchor - Pressure to 2500 psi to set top anchor - slack off 20k on top anchor - Set slips - Pressure to 3000 psi to break connection (30k ft/ Ibs) - Bleed off and pressure up. Cycle tool until 5 turns achieved. PU to release anchors - Drop ball & Printed: 10/912006 10:32:42 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08A X-08 WORKOVER DOYON DRilLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 9/30/2006 06:30 - 07:30 1.00 FISH P DECOMP shear pump out sub 07:30 - 08:00 0.50 FISH P DECOMP POH to BHA 08:00 - 09:30 1.50 FISH P DECOMP LD backoff BHA - Stand back DC's 09:30 - 10:00 0.50 FISH P DECOMP MU spear assembly 10:00 - 11 :00 1.00 FISH P DECOMP RIH to 2100' - Screw in TD - Obtain parameters - Engage 9 5/8" casing stub at 2121' - rotate stub out w/5 L.H. turns. 11 :00 - 13:30 2.50 FISH P DECOMP POH - LD fish (19.11 ') and spear assembly- Clear floor 13:30 - 15:00 1.50 BOPSU P DECOMP PJSM - Pull wear ring - Install test plug - Change top rams to 9 5/8" 15:00 - 15:30 0.50 BOPSU P DECOMP Test w/9 5/8" test jt to 250 psi low, 3500 high - RD testing equipment 15:30 - 17:00 1.50 CASE P DECOMP Mobilize casing equipment to rig floor - RU 9 5/8" casg equipment 17:00 - 18:00 1.00 CASE P DECOMP MU 9 5/8" triple conn - Baffle - HES Cementer - Run 9 5/8" 40# L-80 TCII casg 18:00 - 19:00 1.00 CASE N RREP DECOMP Repair pipe skate coupling 19:00 - 23:00 4.00 CASE P DECOMP Con't Run 9 5/8" casg to to 2139' 23:00 - 00:00 1.00 CASE P DECOMP MU 5' TCII Pup jT - 4 1/2" IF x 9 518" TCII - 4" HT38 X 4 1/2" IF XO's - PUW 125 - SOW 125 - Screw into 9 5/8" @ 2141' - MU to 10K Ft/lbs - Work torque down - Total turns made up 8.75 with 1 OK torque 1 0/1/2006 00:00 - 01 :00 1.00 CASE P DECOMP PU pull 250k on 9 5/8" csg - RU testing equipment - Attempt to test csg to 2000 psi (possibly leaking off through surface equip.) 01 :00 - 02:00 1.00 CASE P DECOMP RD - Screw in XO's - 9 5/8" TC11 P X B Pup jt - Install TC11 P X BTC B XO - Make up Cementing head - Cementing lines 02:00 - 03:00 1.00 CASE P DECOMP Test casg with cement lines to 2000 psi - Isolate from rig surface equipment - Bled off 300 psi in 25 mins - No visual leaks on surface - No flow from annulus - Call town - Open ES Cementer - Pressure up to 2600 psi ES Cementer open 03:00 - 03:30 0.50 CASE P DECOMP Circulate one casing volume 7 BPM I 180 PSI 03:30 - 05:00 1.50 REMCM P DECOMP PJSM - RU SLB cement lines Test lines to 4500 psi Pump 5 bbls water ahead I BPM 3 I PP 190 Pump 142 bbls 680 sxs Class "G" cement wI Gasblok at 15.8 ppg I BPM 5 I PP 210 Kick out closing plug wI 5 bbls water Displace cement wI 156 bbls 9.8 ppg brine water I BPM 7 I PP 190 Slowed pump to BPM 2 I PP 600 at 1400 stks Bump plug wI 1440 psi Increased pump pressure to 1800 psi to close ES cementer Bled off pressure - Check ES cementer - No returns - CIP @ 0500 hrs. 05:00 - 06:30 1.50 REMCM P DECOMP Pump fresh water to flush cement fl stack - RD cement head - Blow down lines - Void fluid from landing jt. 06:30 - 09:00 2.50 BOPSU DECOMP ND BOPs - Pull 150k on 9 5/8" casing - Install emergency slips - Set slips - Cut off landing jt. 09:00 - 11 :30 2.50 CASE DECOMP Install tubing spool - RILDS - Energize seal - RU Test equip. - Test to 2400 psi f/30 min. - Recorded on chart 11 :30 - 13:30 2.00 BOPSU DECOMP NU BOPs I choke I flow line - Install test plug - PJSM - Change out 9 5/8" rams to 3 1/2" x 6" VBRs - RU test equipment 13:30 - 16:30 3.00 CASE P DECOMP Test 3 1/2" x 6" rams to 250 psi low - 3500 psi high fl 5 minutes Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X -08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 10/1/2006 13:30 - 16:30 3.00 CASE P DECOMP each test - Recorded on chart - RD test equip. - Install wear ring 16:30 - 17:30 1.00 MOB P DECOMP Change out bales - Mobilize BHA to rig floor - MU cleanout assy. 17:30 - 20:00 2.50 CLEAN P DECOMP RIH f/307' to 2108' - Tag cement at 2108' 22' above ES Cementer - Drill shoe track and HES cementer at 2130' - Drill cement to top of baffle plate at 2138' I BPM 10 I PP 750 / UPWT 97k I SOWT 95k I ROT 95k I WOB 15k I TQ 1 k I ROT 80 20:00 - 20:30 0.50 CLEAN P DECOMP Pump 40 bbls high viscosity polymer sweep - Circulate sweep surface to surface GPM 580 - PP 1520 - RPM 80 20:30 - 21 :30 1.00 CLEAN P DECOMP Drill baffle plate at 2138' / GPM 580 I PP 1560 - RPM 80 21 :30 - 22:00 0.50 CLEAN P DECOMP RIH f/2139' to 2921' - Tag I drill junk fl 2921' to 2950' I BPM 11 PP 280 22:00 - 23:00 1.00 CASE P DECOMP Pump 40 bbls high visc polymer sweep - Displace well wI 8.5 ppg hot sea water - GPM 580 - PP 23:00 - 00:00 1.00 CASE P DECOMP RU test equipment - Test 9 5/8" casing to 3500 psi f/30 minutes - Recorded on chart (bled down 300 psi over 25 min. test) - Stop test 10/2/2006 00:00 - 03:00 3.00 CASE P DECOMP Continue to test 9 5/8' casing - Change configuration to isolate surface equipment - Pressure to 3500 psi fl 30 min - Lost 150 psi in 30 min. - Bump pressure back up to 3600 psi - Lost 125 psi in 30 min. - Observe OA & well bore - No fluid movement 03:00 - 04:30 1.50 CASE P DECOMP POH to DC's 04:30 - 05:30 1.00 CASE P DECOMP Stand back DC's - LD BHA - Clean junk baskets - Recovered ( 4 brass shear pins 1 "x1 ") 05:30 - 06:00 0.50 CASE P DECOMP MU 8 1/2" reverse circ. basket BHA 06:00 - 07:00 1.00 CASE P DECOMP Close blind rams - Test 9 5/8" casing to 3500 psi f/1 hr - Lost 300 psi 07:00 - 08:30 1.50 CASE P DECOMP RIH - Tag top of sand at 2950' 08:30 - 09:30 1.00 CASE P DECOMP Circulate surface to surface to remove any air from system - 7.3 bpm, 3150 psi 09:30 - 10:30 1.00 CASE P DECOMP PU to 2930' - RU to test 9 5/8" - Close bottom pipe rams (to eliminate kill line & choke line valves) - Open OA valve - Pressure test casing to 2500 psi f/30 min. - Lost 100 psi - No fluid movement from well bore or OA valve. 10:30 -11:30 1.00 CASE P DECOMP Tag top of sand wI reverse basket - Circulate and wash through sand f/2950' to 2986' (10' from top of RBP) - 8 bpm, 3500 psi- CBU to remove sand from well bore 11 :30 - 13:00 1.50 CASE P DECOMP POH to BHA at 307' 13:00 - 14:00 1.00 CASE P DECOMP Stand back DC's - LD Reverse basket - Clean same - Recovered (4 3"x4" chunks plug rubber) 14:00 - 15:00 1.00 CASE P DECOMP Clear rig floor - Mobilize RTTS to floor 15:00 - 16:00 1.00 CASE P DECOMP MU RTTS - RIH to 2118' PUWT 78k I SOWT 78k - RU test equipment 16:00 - 22:30 6.50 CASE P DECOMP Set RTTS @ 2118' - Pressure test 9 5/8" casing below packer to 3500 psi (bled down 300 psi I 30 min. I test record on chart ) - Re-configure lines - Test 9 5/8" annulus above packer to 3500 psi fl 30 min. (good) record on chart - RIH to 2151' - Set RTTS @ 2151' - Pressure test 9 5/8" casing below packer to 3500 psi ( bled down 200 psi over 10 min.) - Bump up pressure to 3500 psi ( bled down 300 psi over 15 min.) record on chart - Re-configure lines - Test 9 5/8" annulus Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X -08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 101212006 16:00 - 22:30 6.50 CASE P DECOMP above packer to 3500 psi fl 30 min. (good ) record on chart - RIH to 2907' - Set RTTS @ 2907' - Test 9 5/8" annulus above packer to 3500 psi f/15 min. (good) record on chart- Re-configure lines - Test 9 5/8" casing below packer to 3500 psi ( 15 min. test! bled down 300 psi) Record on chart RD test lines and equipment 22:30 - 23:30 1.00 CASE P DECOMP POH fl 2907' to surface - LD RTTS 23:30 - 00:00 0.50 CASE P DECOMP MU - HES RBP retreivin9 tool - RIH to 946' 10/3/2006 00:00 - 01 :00 1.00 CASE P DECOMP Cont. RIH from 946' to top of sand 2986' 01 :00 - 01 :30 0.50 CASE P DECOMP Circulate sand off top of RBP to 2996' - CBU - 7.6 BPM @ 530 psi - Latch RBP - Pull free 01 :30 - 03:00 1.50 CASE P DECOMP POH - LD RBP - Retrieving tool - Clear floor of HES tools - RBP I RTTS - Retrieving tool 03:00 - 03:30 0.50 CASE P DECOMP Close Blinds - Test 9 5/8" casg to 3500 psi for 30 mins - Record on chart - Test good 03:30 - 04:00 0.50 CASE P DECOMP Mobilize BHA to rig floor 04:00 - 06:00 2.00 CASE DECOMP MU reverse basket BHA 06:00 - 09:30 3.50 CASE P DECOMP RIH wI 4" DP - Tag top of 41/2" tubing stub at 8749' 09:30 - 10:30 1.00 CASE P DECOMP Screw in TD - Rotate to enter stub wI 30 - 50 rpm, 3k torque - Wash down to 8812' - Stop pumps & rotary - PU singles & tag top of "sluggits" at 8825' - Circulate down wI 7.5 bpm, 2080 psi to top of 4 1/2" XX plug at 8836' - PU & rotate wI 40 rpm - Set down w/1 k weight to verify no sluggits or junk. 10:30 - 12:00 1.50 CASE P DECOMP CBU x 1.5 wI 8.5 bpm, 2700 psi - Monitor well fl flow - Pump dry job 12:00 - 15:00 3.00 CASE P DECOMP Blow down top drive - POH fl 8836' to 161' 15:00 - 16:30 1 .50 CASE P DECOMP Stand back collars - LD BHA I jars I 2 7/8" pac drill pipe I Clean out jet basket - Recovered (1 1 "x1" metal screw, 1 circular chunk metal 1/2" x 1 1/2" diameter) 16:30 - 18:00 1.50 BOPSU P DECOMP Clear rig floor - Pull wear ring - Install test plug - Ru test equipment 18:00 - 00:00 6.00 BOPSU P DECOMP Test BOP's -Test performed wI 4" test joint - Annular - Top 3 1/2" x 6" VBR's failed low test - Attempt to isolate leak - Resume test I Blind rams - HCR Choke I Kill valves - Upper I Lower IBOP - Lower 2 7/8" x 5" VBR's - 250 Low 3500 High - 5 mins. each test (prepare to pull upper 3 1/2" x 6" VBR's to inspect) 10/4/2006 00:00 - 02:30 2.50 BOPSU P DECOMP PJSM - Change out 3 1/2" X 6" Top VBR's to 4" solid rams (remove hard cmt fl ram cavity and inside doors) - Test Manual kill, Top rams, Choke manifold, TIW floor valve, dart valve, 250 low - 3500 high - 5 mins. each test - Performed Accumulator test - All test witnessed by WSL - Jeff Jones with AOGCC waived witnessing of test 02:30 - 03:00 0.50 BOPSU P DECOMP RD test equipment - Install wear ring 03:00 - 04:30 1.50 MOB P DECOMP Mobilize BHA to rig floor - MU 4" GS spear assy, 4 jts. 2 7/8" pac drill pipe, bumper jar, oil jar, pump out sub 04:30 - 09:00 4.50 FISH P DECOMP RIH wI 4" drill pipe f/158' to 8200' - Slip and cut drilling line- Service top drive 09:00 - 10:00 1.00 DHB P DECOMP MU HES storm packer - RIH set storm packer at 102' - Pressure test packer to 1000 psi fl 15 mins. 10:00 - 11 :00 1.00 BOPSU P DECOMP Pull wear ring - Install test plug - Pull 4" solid top rams I install 3 1/2" x 6" VBR's 11 :00 - 13:00 2.00 BOPSU P DECOMP RU test equipment - Test top rams to 250 psi low - 3500 psi Printed: 10/9/2006 10:32:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X -08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: high I each test 5 mins with 4" and 4 1/2" test joints - record on chart (good) - RD test equip. - Pull test plug - Install wear ring 13:00 - 13:30 0.50 DHB P DECOMP MU HES storm packer retreiving tool - Pull storm packer - LD same 13:30 - 16:00 2.50 FISH P DECOMP RIH f/8200 ' to 4 1/2" stump at 8749' - Sting into stump - RIH to plug @8836' - POW 182 - SOW 150 - ROTW 165 - 40 RPM - TQ 3 - GPM 170 - PP 1920 - Engage plug - Pull plug free wI 20K over - Slack off to 8851' - Drop ball - Shear circ sub 16:00 - 18:00 2.00 FISH P DECOMP Attempt to fill hole - Pump 150 bbls in annulus - No returns - Fill 10 bbls every 15 mins - Shoot fluid levels - 1st 636' - 2nd 960' - 3rd 930' - 4th 1068' - 5th 1160' 18:00 - 18:30 0.50 FISH P DECOMP POH LD 4" DP - LD 30 joints - Filling hole every 15 mins 15 bbls 18:30 - 19:00 0.50 FISH P DECOMP Wait 30 mins - 6th Fluid shot 1440' - RD DHD tool 19:00 - 00:00 5.00 FISH P DECOMP Con't POH LD 4" DP - Filling hole every 15 mins 15 bbls 10/5/2006 00:00 - 01 :00 1.00 FISH P DECOMP POH LD 4" DP - Filling hole every 15 mins 15 bbls 01 :00 - 02:30 1.50 FISH P DECOMP POH LD BHA - Clear rig floor - Filling hole every 15 mins 15 bbls 02:30 - 03:30 1.00 P DECOMP RIH with 2 stands 4" DP - 3 stands of 6 1/2" DC's - LD Same 03:30 - 05:30 2.00 RUNCMP Pull wear ring - Moblize Tubing equipment to rig floor - RU to run 4 1/2" completion 05:30 - 16:30 11.00 RUNCMP PJSM - PU I Run 4 1/2" completion 16:30 - 17:30 1.00 RREP RUNCMP Tighen fittings on skate 17:30 - 19:00 1.50 RUNCMP Con't running 4 1/2" tubing completion 19:00 - 20:00 1.00 RUNCMP De-Ice Derrick 20:00 - 22:00 2.00 RUNCMP Con't running 4 1/2" Tubing completion 22:00 - 23:00 1.00 RUNCMP De-Ice Derrick 23:00 - 23:30 0.50 RUNCMP Con't Run 4 1/2" tubing completion 23:30 - 00:00 0.50 RUNCMP RIH to shear off pins to confirm string on depth and space out - No indication of shear out - Set 25K down weight (Pipe tally 8756') - PU 10K overpull - Attempt to shear out pins 6 times with no other indication or overpull after 1 st attempt - Can not confirm shear out 10/6/2006 00:00 - 01:30 1.50 RUNCO RUNCMP LD 3 joints - PU 3 space out pups total 22' - Joint 201 - RIH 01 :30 - 03:00 1.50 RUNCO WAIT RUNCMP Wait on TC11 landing joint from API 03:00 - 04:00 1.00 RUNCO RUNCMP MU Hanger I Landing joint - RIH - Land - RILDS 04:00 - 05:30 1.50 RUNCO DPRB RUNCMP PJSM - RU Slickline BOP's I Lubricator - Pump in sub 05:30 - 08:30 3.00 RUNCO DPRB RUNCMP RIH wI slickline to pull RHC valve - Pull RHC plug at 8684' - POH wI slickline 08:30 - 10:00 1.50 WAIT RUNCMP RIH w 3.8" Slickline drift, Work through tight spot @ 8857' - Slickline drift to 8882' - POH wI slickline 10:00 - 12:00 2.00 RUNCO DPRB RUNCMP Wait on SLB Set memory tool to arrive location 12:00 - 17:00 5.00 RUNCO DPRB RUNCMP RIH wI memory tool on slickline - Log 4.5 tubing fl 8500' to 8950' 17:00 - 18:00 1.00 DPRB RUNCMP POH wI slickline - Down load I Analyze logs 18:00 - 20:30 2.50 DPRB RUNCMP RIH wI RHC plug on slickline - Set 1 shear off RHC plug at 8687' - POH wI slickline (left 5/16" shear pin in hole) 20:30 - 22:00 1.50 DPRB RUNCMP RD slickline BOP's I Lubricator 22:00 - 00:00 2.00 RUNCMP Pump I fill 9 5/8" x 4.5" IA wI 400 bbls inhibited seawater 45 bbls seawater ( no returns) - Drop ball and rod 10m2006 00:00 - 02:30 2.50 RUNCMP RU test lines - RU test equipment - Lubricate and bleed to remove air fl tubing - Pressure up on 4 1/2" tubing to 3500 psi I Observed leak on XO - Bleed off pressure - Disconnect lines - Printed: 10/9/2006 10:32:42 AM & Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08A X-08 WORKOVER DOVON DRILLING INC. DOVON14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 02:30 - 05:00 05:00 - 08:30 08:30 - 10:00 10:00 - 12:00 12:00 - 16:00 16:00 - 20:30 20:30 - 21 :30 21 :30 - 22:30 22:30 - 00:00 10/8/2006 00:00 - 01 :00 01 :00 - 03:30 03:30 - 05:30 05:30 - 08:00 2.00 4.00 1.50 RUNCO 1.00 RUNCO 2.50 RUNCO 2.00 RUNCO 2.50 RUNCO Tighten up XO - Hook up lines - Pressure up to 3500 psi - Observed leak on XO - Bled off pressure - RD test line - (break out XO inspect - replace seal ring in cross over re-dope) Pressure test 41/2" tubing to 3550 psi / lost 850 psi over 30 min. - record on chart - DPRB RUNCMP Bled down tubing to 2000 psi Hold for 10 mins lost 150 psi - Pressure up on tubing to 2500 psi I shut in - Pressure up on IA to 3475 psi (tubing pressure increased to 3000 psi) - Tubing pressure increased to 3175 psi (175 psi) - Annulus decreased to 3375 psi (lost 100 psi) - Bled off IA - Pressured up tubing to 3680 - lost 980 psi in 40 mins - Bled off tubing pressure DPRB RUNCMP Bleed IA - Fluid pack IA DPRB RUNCMP Pressure test tubing to 3500 - Lost 800 psi in 30 mins - Bled tubing to 1900 psi - Pressure up IA to 3500 - (190 stks = 19 bbls to gain 3500 psi) - Tubing increased 2450 from 1900 - (15 mins TBG 2450 to 3100 - IA 3500 - 3300) (30 mins TBG 3100 to 3250 - IA 3300 - 3275) - RD Slickline while testing DPRB RUNCMP RU Slickline DPRB RUNCMP RIH with Slickline to retrieve Rod I Ball - POH - RIH to retrieve RHC plug - POH - Did not recover RHC - RIH to retrieve RHC plug - POH - Plug recovered DPRB RUNCMP RIH with PXX plug set @ 8684' - POH - RIH with equalizing prong install plug - POH DPRB RUNCMP RD Slickline Lubricator / BOP's - RU test lines to Tubing I IA - IA total fluid added 17 bbls during slickline work Tubing total fluid added 87 bbls DPRB RUNCMP Pressure up tubing to 3500 psi - Hold for 30 mins - (Lost 900 psi) - 2.75 bbls to obtain 3500 psi - Bled off tubing to 1800 psi- Pressure up IA to 3500 psi - 6.5 bbls to obtain 3500 psi - Shut in IA - Shut in pressure Tubing 2700 / IA 3510 - 15 mins Tubing 3200 IIA 3410 - 30 mins Tubing 3300 I IA 3390 - 40 mins Tubing I IA 3325 - DPRB RUNCMP Bled off IA I Tubing to change out Howco valve leaking in grease cert - Change out valves - RU test lines DPRB RUNCMP Pressure up tubing 3000 psi - Pressure up IA to 3000 psi - Tubing pressure increased to 3350 - Con't pressure up tubing to 4000 psi with rig test pump - 5 mins IA 3025 gained 25 psi / Tubing 3900 lost 100 psi - Bump tubing back to 4000 psi - 15 mins IA 3050 gained 25 psi I tubing 3900 lost 100 psi - Bump tubing back to 4000 psi - Held 30 mins tubing 3625/1A 3150- Decrease tubing to 375 psi IIA increase 100 psi - Bled off IA I Tubing DPRB RUNCMP RD testing lines - RU Slickline BOP's / Lubricator - RIH with Slickline retrieving tool to pull DCR-1 shear valve - POH - RIH set blank valve - POH - RD Slickline Lubricator I BOP's - RU testing lines DPRB RUNCMP Pressure up tubing 3500 psi - Hold for 15 mins - Lost 450 psi - Bleed off - Call town - RD test lines - RU test lines - Pressure Tubing 3500 psi - Pressure IA 3500 psi - Hold 30 mins - Good Test - Bled down tubing I IA DPRB RUNCMP Wait 1 hour - Test IA 3500 psi - tubing 1100 - 6.5bbls to obtain 3500 - 15 mins tubing 1400 IA 3425 - 30 mins tubing 1800 - IA Printed: 10/9/2006 10:32:42 AM & Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X -08A X-08 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 8/18/2006 Rig Release: 10/8/2006 Rig Number: 14 Spud Date: 5/10/1980 End: 21 :30 - 23:00 23:00 . 00:00 3350 - Bled off pressure - RD testing lines RU Slickline BOP's I lubricator - RIH - Pull dummy gas lift valve @ 3200 - RD Slickline equipment RUNCMP Install TWC - Test from below to 1000 psi for 15 mins RUNCMP Remove all rams - Clean ram bodies - ND Stack RUNCMP NU Adapter flange - Tree RUNCMP Test Adapter with Cameron to 5K 10 mins - Test tree to 5K 15 mins RUNCMP RU DSM - Pull TWC - RD DSM RUNCMP RU Little Red Hot Oil RUNCMP PJSM - Pressure test lines to 3000 psi - Pump 145 bbls diesel @ 3 bpm @ 500 psi RUNCMP U-tube well RUNCMP Install BPV - Test from bottom 1000 psi 10 mins - Secure Well - Release rig @ 24:00 hrs 10/8/2006 10:30 - 11 :00 11 :00 - 16:00 16:00 - 18:00 18:00 - 19:00 0.50 P 5.00 BOPSU P 2.00 WHSUR P 1.00 WHSUR P 19:00 - 19:30 19:30 - 20:00 20:00 - 21 :30 Printed: 10/9/2006 10:32:42 AM Well Job # Loa DescriDtion Date BL Color CD 1-21/K-25 11226008 LDL 10/02/06 1 B-27A 11414394 LDL 09/30/06 1 M-24A 11216213 MEM PROD PROFILE 09/30/06 1 MPB-09 11212889 PROD PROF/GLS 10/06/06 1 X-08A 11414278 USIT 09/26/06 1 C-01A 11414279 USIT 09/27/06 1 K-11 11414765 USIT 10/01/06 1 A-17A 11414283 USIT 10/02/06 1 -.' ,.., Schlumbepgep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth (:~)é):3 ~ 1/7- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 "i!l.U::':'¡ \ fl...... 900 E. Benson Blvd. SCA:"'~riJb~) . Anchorage, Alaska 99508 Date Delivered: 10119106 NO. 4001 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . Alaska Data & Consulting 2525 Gambell Street, S . Anchorage, AK 99503-' ATTN: Beth î\ Received "'---- STATE OF ALASKA ~ OCT 0 [-; "¡H;~ ALASKA OIL AND GAS CONSERVATION COMMISSION ,- . REPORT OF SUNDRY WELL OPEMI ~~asCÜ;b L>;iTìlni:' I'U\ . . v." ~nchr.rage 1. Operations Performed: Abandon D Alter CasingD Change Approved ProgramD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 73.48 8. Property Designation: ADL-028313 11. Present Well Condition Summary: Repair WellŒ! PluQ PerforationsD Pull Tubing 0 Perforate New PoolD Operation Shutdown 0 Perforate 0 Stimulate D WaiverD 4. Current Well Class: Development 00 ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: X-08A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth measured 11691 feet true vertical 8904.2 feet Effective Depth measured 11658 feet true vertical 8901.0 feet Casing CONDUCTOR SURFACE PRODUCTION LINER LINER LINER LINER Perforation depth: Length 110 2646 9316 673 8 782 2054 Plugs (measured) Junk (measured) Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 3-1/2" 8.81# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 MD TVD 143 - 2678 - 9347 - 9532 - 8855 - 9637 - 11691 33.0 32.0 31.0 8185.0 8174.0 8181.0 8907.0 143.0 2678.0 8640.0 8816.0 8181.0 8907.0 8904.0 33 32 31 8859 8847 8855 9637 Measured depth: Slotted Liner --- 9640-10127,10233-10568,10974-11658 Otherl!] PRE-RWO Time Extension D Re-enter Suspended WellD 5. Permit to Drill Number: 203-1170 6. API Number 50-029-20463-01-00 None At Approx 9600 Burst Collapse 1490 470 5380 2670 6870 4760 8160 7020 10160 10530 8520 7660 10570 11160 ~CAANED OCT ;J : 2006 True vertical depth: Slotted Liner --- 8909-8915, 8903-8883, 8855-8901 Tubing ( size. grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ 31 8907 9-5/8" DV Packer 9-5/8" Baker SAB-3 Packer @ 2609 @ 8798 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: R8DMS 8Ft 0 CT 0 9 2006 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ Oil-Bbl 774 SI Representative Dailv AveraQe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 6898 4950 o 0 Tubing Pressure 266 o 15. Well Class after proposed work: Exploratory(] 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ) ServiceD WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. SUndry Number or NIA if C.O. Exempt: N/A Contact DeWayne R. Schnorr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Petroleum Engineer Phone 564-5174 Printed Name De~a:j R. Schnorr ) Ð Signature .Æ~~ ~~ Form 10-404 Revised 4/2004 (J RIG I N A L Date 10/4/06 .~- ',- X-OBA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/18/2006 PULLED BPV AFTER THE RIG MOVED OVER THE WELL 09/15/2006 TIIA/OA = SI/O/O (Pre Rig Inspection) PPPOT-T = Passed Bled tubing hanger void to 0 psi. Functioned and torqued 550 fUlbs. Rigged up equipment and pumped until clean fluid returns were achieved. Pressured up tubing hanger to 5,000 psi. for 30 mins. = (Passed) 09/14/2006 TII/O= 30/55/55. Temp= SI. ALP= 20 psi (81 at the lateral and casing valves). Bleed WHP's to 0 psi (pre-PPPOT-T, IC). Bled IAP/OAP from 57 psi to 0 psi in 2.5 hrs. TP went on a vac during bleed. Monitored WHP's for 30 minutes. Final WHP's= Vac/O/O. 09/14/2006 TIIA/OA = SI(vac)/O/O ( Bad Lockdown Screws) PPPOT-IC = Passed / Changed Out Lockdown Assemblies DHD Tech- Grant Chiacchia on site monitoring bled on IA and OA. Removed (12) Lockdown screws, chased lockdown and gland threads, installed new lockdown pins, packing, junk rings and gland nuts. Torqued to 500 fUlbs. Rigged up test equipment, pumped until clean fluids were achieved. Pressured up void to 3,800 psi. for 30 mins. - Passed. 09/10/2006 T/I/O= XXX Circ Wellbore & Freeze Protect TxlA (Shut In)( Circ-Out RWO) Pumped into TBG Takeing Returns from IA to Flowline. 5 bbls 60/40 Meth, 1120 1 % KCL, 27 bbls Meth, 8 bbls Diesel, 82 bbls 60/40 Meth, 8 bbls Diesel, 27 bbls Meth ....Let U-tube,...Bleed Tubing down to 0 psi....Freeze protect flowline with 7 bbls methanol and 83 bbls crude....FWHP = 50 /20 /80 09/07/2006 T/I/O=80/130/130, Temp=SI. Bleed Well pressures to 0 psi (for PPPOT). AlLP= 20 psi, shut- in @ casing valve. Bled OAP from 130 psi to 0 psi in 15 min (fluid to surface). Monitored pressure for 30 min, OAP remained at 0 psi. FWHP=80/130/0. 09/06/2006 BEGIN CHEM CUTTING 4-1/2" TUBING. WELL SHUT IN ON ARRIVAL. INITIAL T/I/ 0 = 0/180/170. JOB CONTINUED ON 6-SEP-2006 AWGRS. CUT TUBING AT 8748' TUBING TALLY DEPTH. SEVERING HEAD LOOKS GOOD. JOB COMPLETE. 09/05/2006 SPOT EQUIPMENT.SIMOPS, TGSM, PRESSURE TEST, RIH W/TUBING PUNCH. WELL SHUT IN ON ARRIVAL. INITIAL T/ II 0 = 0/180/170. 09/05/2006 (Pre RWO) DUMP BAILED TWO BAGS OF SLUGGITS ON TOP OF 41/2" XX PLUG @8,819' SLM. (TOP OF SLUGGITS @8,805' SLM) RDMO. ****4" 1/2" XX PLUG IN HOLE, NOTIFIED DSO OF WELL STATUS**** 09/04/2006 T/IIO=11 00/1250/900 Assist S/L [CTD Screen] Pumped 440 bbls down IA and 200 bbls down tbg. CMIT TxlA to 3500 psi. [PASSED]. Bled pressures down Final WHP= 125/140/320. Page 1 ~ - X-OBA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/04/2006 (Pre RWO) RAN SHIFTING TOOL, CAME BACK W/ PIN SHEARED, SSD WON'T OPEN. RAN 41/2" BRUSH & 3.805 GAUGE RING, TAG DEPLOYMENT SLEEVE @8,832'WLM, =25' CORRECTION. LRS LOADED IA & TBG W/ DEAD CRUDE, SEE LRS PUMP REPORT. SET 41/2" "XX" PLUG IN "X" NIPPLE @ 8,819' WLM, HUNG NO-FLOW / PLUG SET TAG ON THE WING VALVE. LRS PERFORMED CMIT T X IA TO 3,500 PSI. CMIT PASSED. DUMP BAILED SLUGGITS ON TOP OF 4 1/2" XX PLUG BODY. **** JOB STILL IN PROGRESS**** 09/03/2006 *** WELL SHUT IN *** (pre rwo) RECOVERD WFD UPPER PATCH SECTION FROM THE TREE TESTED OK FOR NORM, PAPER WORK TURNED IN TO WFD. MADE DRIFT RUN TO RECOVER MISSING RUBBER ELEMENTS (NO RECOVERY) PULLED LOWER SECTION OF PATCH AND RECOVERED ALL ELEMENTS. MADE SEVERAL ATTEMPTS TO SHIFT OTIS SLIDING SLEEVE. ****JOB STILL IN PROGRESS**** 08/31/2006 CTU #5. Fish Eclipse Patch. RU CTU. MU BHA #1: Weatherford fishing string w/ hydraulic 4-1/2" GS. Latch fish at 8566' ctm. Pull Free after 21 jar licks(22k overpull). POOH. Trap fish in master. Freeze protect well with 40bbls 50:50 MeOH. RDMO. Pad Operator notified of well status Note: Patch was released but remained in wellbore for S/L to remove. Lower packer will still need to be fished. *** CT operation completed *** 08/30/2006 CTU #5. Rig up. MIRU CTU. 08/25/2006 (pre rwo) JARRED ON PATCH @ 8537' SLM FOR ANOTHER 4 HRS @ 4000#, UNABLE TO PULL W/ BRAIDED LINE ----- JOB INCOMPLETE----- TURN WELL OVER TO CTU *** WELL LEFT SI *** 08/24/2006 (pre rwo) JARRED ON PATCH W/ BRAIDED LINE FOR APPROX 7.5 HRS @ 4000#, NO MOVEMENT *** JOB IN PROGRESS*** 08/23/2006 *** WELL SI ON ARRIVAL *** ( pre rwo) RIG UP BRAIDED LINE EQUIP & EXTRA RISERS *** JOB IN PROGRESS *** 07/31/2006 TII/O=1180/830/830. Temp=SI. T BG & IA FL's. (Pre-EL, SCMT). TBG FL @ 3100' (48 bbl). IA FL @ 81951 sta#3 (439 bbl). 07/29/2006 *** WELL SI ON ARRIVAL *** (pre rwo) UNABLE TO PULL PATCH W/ .125 WIRE @ 8548' SLM, UNABLE TO GET THIRD PARTY CRANE FOR B/L TILL AFTER MIDNIGHT & RIG MOVING TO WELL NEXT DOOR IN A.M. JOB CANCELED.RDMO NOTE: 4 1/2" ECLIPSE PULLING TOOL SET IN PATCH @ 8548' SLM ***LEFT WELL SHUT IN*** 07/02/2006 TIO = 1540/800/800. Temp = SI. Monitor WHP's post bleed (Rapid IAxOA comm, AL FP IA). TBGP & lAP unchanged, OAP increased 400 psi overnight. AL SI, ALP = 0 psi. 07/01/2006 TIO = 1540/1510/950. Temp = SI. Bleed IA & OA < 1000 psi (rapid IAxOA comm, AL FP IA). Well SI. AL casing & lateral valves SI. TBG FL @ 6400'. IA FL @ SO @ 7567'. OA FL @ surface. Bled lAP from 1510 psi to 800 psi in 2.75 hrs (bled slowly, FO request). IA FL unchanged. OAP decreased 100 psi. Bled OAP from 850 psi to 400 psi in 5 mins. FWHPs = 1540/800/400. 06/27/2006 BOPD: 774 BWPD: 4,950 MCFPD: 6,898 AL Rate: 3,310 Page 2 ..,.~/ '-- X-OBA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 7 Diesel --- PT Surface Equipment 51 Methanol 50 50/50 Methanol Water 82 60/40 Methanol Water 16 Diesel 661 Crude 1120 1 % KCL Water 1987 TOTAL Page 3 " TREE = ~ELLHEAD := ~tTUATOR= KB. ELEV = SF. 8...EV = KOP= Max Angle := Datum MD = Datum TV D = 6" CrN MCEVOY OTIS 73.48' 40.03' 3100' 98 @ 10172' 9592' 8800' SS X-DBA - - - 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2678' I~ Minimum ID = 2.380" @ 9637' 3-3/16" X 2-7/8" XO I CHEM CUT (09/06/06) 1-1 I TOP OF 1" LNR l-i 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 8748' 8859' 8907' 9347' I TOP OF WHIPSTOCK l-f 9535' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" l-i 10331' ~ ÆRFORA TION SUMMARY REF LOG: EWR-GR ON 08/13/03 A NGLE AT TOP PERF: 52 @ 9640' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLOTTED LINER 9640 - 1 0127 10233 - 10568 10974 - 11658 4 4 4 C C C DA TE REV BY COMMENTS 05/31/80 ORIGINAL COMPLETION 08/19/03 JLM/KK CTD SIDETRACK (X-08A) 01/02/05 RWUTLP GLV C/O 01/24/05 LDKlPJCQ SIT BKR IBP 08/09/05 EZUPJC DELETE WAIVER SFTY NOTE 04/26/06 JPKlPJC GL V TV D CORRECTIONS L I I .~. :8: :8: I~. . ~ SAFETY NOTES: *** 4-1/2" ECLIPSE PATCH COVERS GLM #1.*** 2117' H 4-1/2" OTIS SSSV NIP, 10:= 3.813" I ~ 2609' ~19-5/8" DV A<R 1 I 8712' ~loTlS SLIDING SLEEVE, 10= 3,813" I 8775' I 8798' ~ 8844' 1 8844' ~I SIT XX PLUG (09/04/06) I ~ 1 -885F- ~3.7" BKRDEPLOYMENT SLV, ID::: 3.0" '-.:.- 8 a~'7 ' 1 8855' ~13-1 /2" X 3-3/16" XO, ID := 2.80" 1 1 8875' ~ ST MD TVD 5 2972 2971 4 5170 4974 3 7567 7021 2 8366 7735 1 8598 7945 I .. 8907' GAS LIFT MANDRB....8 DEV TYÆ VLV LATCH 8 OTIS DOME T2 31 OTIS DOME T2 28 OTIS SO RM 26 OTIS DMY RA 24 OTIS DMY RA PORT DA TE 16 04/27/06 16 04/27/06 20 04/27/06 o 06/30/03 o II r I ~ ~I TBG SEAL ASSY I ~19-5/8" X 4-1/2" BKRSAB-3 A<R, ID = 3.813" ~14-1/2" OTIS X NIP, ID = 3.813" I ~ 4-1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND CT LNR) ~ 4-1/2" TBG TAIL ID::: 3.958" (BEHIND CT LNR) MILLOUT WINDOW 9532' - 9539' H3-3/16" X 2-7/8" XO, ID = 2.380" 1 1 3-3/16" LNR, 6.2#, L-80, .0081 bpf, 10 = 2.880" l-i 9637' 1 11658' ~IPBTD I 08/18/03 08/18/03 08/18/03 .. '7 2-7/8"SLTO/SOLlDLNR,6.16#,L-80,.0555bPf,10:::2.372" 1-1 11691' 1 DA TE REV BY COMMENTS 04/27/06 OA V /PJC GL V C/O 07/28/06 RRDlPAG PULL IBP@ 8830' (04/26/06) 09103/06 JCMlPA G PULL PATCH @ 8578' 09/04/06 JRP/PAG SIT XX PLUG @ 8844' 09/06/06 GJB/PJC CHEM CUT @ 8748' PRUDHOE SAY UNIT WElL: X-08A ÆRMIT No: "2031170 API No: 50-029-20463-01 SEC 7, T10N, R14E, 432' FSNL & 264' FWEL BP Exploration (Alaska) @. up.. I ~rr. re @ûJiJUlb '~n / i ¡ j liJJ: i I L ,U· ,.." \' <' U e n '/ ¡ ¡ ! ! ! LS (ñ) n n .':1' I.'.' '.Vi !¡~j. '\'. '. "'...11\\.. ¿' ,.i, ",\ ¡, .... f1ji;¡\\ r'~ .>..::::./ uU . U FRANK H. MURKOWSKI, GOVERNOR A)',ASIiA. OIL AlWD GAS CONSERVA.TlON COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-08A Sundry Number: 306-251 p n ~) "ì i...) t) L. l~,' Ç) Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisHday of July, 2006 Enc!. ¿jÓZ:,-II"1- JUL 2 5 2006 ~ 'êt.. rlLlCA TION ~~~;2~.~~RY APPROV A~aSka Oil & Gas Cons. Commission o Abandon ' 0 Suspend 0 Operation Shutdown 0 Perforate 0 Time ExteAd16liOrage o Alter Casing 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well / o Change Approved Program 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes ~ No 9. Property Designation: 110. KB Elevation (ft): ADL 028313 KBE = 73.48' i.?> ......../..y../,.'......,,/.j.. ·..n..·.·....!· .....,........... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 11691 8904 I 11691 / Casina Lenath Size MD / Structural Conductor Surface Intermediate Production Liner Perforation Depth MD~' I Perforation Depth TVD (ft): I 9640' - 11658' 8909' - 8901' Packers and SSSV Type: 9-518" x 4-1/2" Baker 'SA B-3' packer; 4-1/2" Tubing Patch: 8578' - 8613' 13. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for CommencinQ Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certifY that the foregoing is true and correct to the best of my knowledge. Printed Nan(é'\pavid Reem Title Drilling Engineer Signature lJ-(1 h.// A ./ Phone 564-5743 Commission Use Onlv ¡;JTS 1. Type of Request: 110' 2678' 9347' Liner 1472' 2840' j)fc. 7/:U1o&. . STATE OF ALASKA . AlA~ Oil AND GAS CONSERVATION COM~SION ~Ä-- 7lYø/1..o0(, REt.;t::IVED 4. Current Well Class: ,,/ 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 203-117 / 6. API Number: ,./' 50-029-20463-01-00 8. Well Name and Number: PBU X-08A ,,/ 11. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool .Ò n' .. . . '.' . . Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8904 8830 None TVD Burst CollaDse 20" x 30" 13-3/8" 9-518" 110' 2678' 8640' 110' 2678' 9347' 4930 8150 2670 5080 7" 8859' - 9539' 8851' -11691' 8160 7020 3-1/2" x 3-3/16" x 2-7/8" 8185' - 8823' 8177' - 8904' Tubing Grade: Tubing MD (ft): L-80 8907' I Packers and SSSV MD (ft): 8798' / 14. Well Class after proposed work: ,/ o Exploratory 181 Development 0 Service Tubing Size: 4-1/2", 12.6# / AU9U~O,~06 Dåte: 16. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Prepared By Name/Number: Date ::¡../'1t/ lOb' Terrie Hubble, 564-4628 I Sundry Number: L~ · c:J51 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Other: Te-ç t- 13 0 P E Subsequent Form Required: Approved By: Form 10-403 Revised 06/2006 to '3 5"00 f ~4 . 10- 4-e.¥' Ú é/ fAv f4~oMMrssrONER \.../ -- L. ORIGINAL RBDMS BFL JUL 2 '1 2006 Date ~ íb~Þ s'ubmit (n Duplicate ~ ~61t1{; APPROVED BY THE COMMISSION e e X-DB Rig Workover Scope of Work: Pull 4-W completion, cut and pull 9-5/8" production casing above top of cement, run and cement new 9-5/8" casing with premium connections to surface, and run 4-W' 13Cr80 stacker packer com pletion. MASP: 2315 psi / Well Type: Producer - On Gas Lift Estimated Start Date: August 10, 2006 Pre-ri o 1 E 4 re work: Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is NOT secured at this time. PPPOT-T & IC. RU, RIH with Weatherford SL Retrieval Ada ter and retrieve tubin atch set -8578' to , Open Sliding Sleeve @ 8712. Drift for 4-1/2" XX plug to -8850'. Opening the sliding sleeve is to for:ego tubing punches for the chem. cut. Slope discretion on either opening the sleeve or s óting ,holes. Set 4 }'2" XX plug @ -8844' (Ref. 5/31/80 Tubing Summary). Dump 10-15' J u its ón to of XX lu . CMIT TxlA to 3500 si to confirm mechanical seal. et /2" XX plug @ -8844', Chem cut @ 8730'. (Ref: 5/31/80 Tubing Summary). Chem cut desired to be in the middle of the first full 'oint below slidin sleeve. Circulate well with seawater and FP w/ diesel thru the cut. MITOA to 2000 psi Bleed WHP's to o si. Bleed WHP's to zero. Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the ad as needed for the ri S 2 S 3 F 5 o 6 ProDosed Procedure 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-}'2" tubing string to the cut. 3. Run USIT to determine top of cement in the 9-5/8" x 13-3/8" annulus. /' 4. Recover 9-5/8" casing above TOC. 5. Run and cement new 9-5/8" casing with premium connections to surface. 6. Run 4-}'2" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -8635' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 9. Set BPV. NO BOPE. NU and test tree. RDMO. / ,/ ,/ TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 6" CrN MCEVOY OTIS 73.48' 40.03' 3100' 98 @ 10172' 9592' 8800' SS e X-08A SAa NOTES: *** 4-1/2" ECLIPSE PATCH COVERS GL rJIIIr. *** 2117' 4-1/2" OTIS SSSV NIP, ID = 3.813" . GAS LIFT MANDRELS DEV TYÆ VLV LATCH 8 OTIS DOME T2 31 OTIS DOME T2 28 OTIS SO RM 26 OTIS DMY RA 24 OTIS DMY RA PORT DATE 16 04/27/06 16 04/27/06 20 04/27/06 o 06/30/03 o 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.25" @ 8578' 4-1/2" ECLIPSE PATCH ST MD TVD 5 2972 2971 4 5170 4974 3 7567 7021 2 8366 7735 1 8598 7945 I TOP OF WHIPSTOCK I 4-1/2" ECLlPSEPATCH,ID=2.25" I 8712' OTIS SLIDING SLEEVE, ID = 3.813" 8775' TBG SEAL ASSY 8798' H9'5/8" x 4-1/2" BKR SAB-3 PKR, ID - 3.813" 8830' 2.125" BAKERIBP (1/24/05) 8844' H4'1/2" OTIS x NIP, ID = 3.813" I 8857' 3.7" BKR DEA..OYMENT SLY, ID = 3.0" I TOP OF 7" LNR I 3-1/2" X 3-3/16" XO, ID = 2.80" 8875' 4-1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND CT LNR) 4-1/2" TBG TAIL ID = 3.958" (BEHIND CT LNR) 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 8907' I MILLOUT WINDOW 9532' - 9539' 3-3/16" X 2-718" XO, ID = 2.380" 7" LNR, 29#, L-80, .0371 bpf, ID=6.184" I ÆRFORA TION SUMMARY REF LOG: EWR·GR ON 08/13/03 ANGLEATTOPÆRF: 52 @ 9640' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SLOTTED LINER 9640 - 10127 10233 . 10568 10974-11658 10331' 1 3-3/16" LNR, 6.2#, L-80, .0081 bpf, ID = 2.880" I 4 4 4 12,7/8" SLTD/SOLlD LNR, 6.16#, L-80, .0555 bpf,ID= 2.372" I o o o 08/18/03 08/18/03 08/18/03 DA TE REV BY COMMENTS 05/31/80 ORIGINAL COMPLETION 08/19/03 JLM/KK CTD SIDETRACK (X-08A) 08/21/03 RWL/KK GLV C/O 09/02/03 BJM'KK SET ECLIPSE PA TCH 01/02/05 RWLffLP GLV C/O 01/24/05 LDKlPJC SET BKR IBP DATE 08/09/05 04/26/06 04/27/06 REV BY COMMENTS EZLlPJC DELETE WAIVER SFTY NOTE JPKlPJC GLV TVDCORRECTIONS DA V /PJC GL V C/O PRUDHOE BAY UNIT WELL: X·08A ÆRMIT No: "'2031170 API No: 50-029-20463-01 SEC 7, T10N, R14E, 432' FSNL & 264' FWEL BP Exploration (Alaska) ,. ru:c: - <> UV' \ÆLLHEAD ~ W'CBIOy -08A Propose CTl.IA TOR .. OTIS ,/ æ. a.et = 73.48' IF. 8...et .. 40.03' op= 3100' 11II R =-I -2200' 9-518" CSG, 40#, L-80, TC-II, .0758bpf, ID = 8.835" lax Angle = ~ @ 10172' ÞC . 4-1/2" HES "X" NIP, 10 = 3.813" 1 aturn I'vD = 9592' ~ 'IIi turn lVD = 8800' SS ~ 1-2210' f-ICALCULA TED TOC I ".-/ - - GAS LIFT IW\I\IJRELS I 13-318" CSG, 72#, L-80,ID ..12.347" H 2678' I~ ~ ST I'vD lYPE VlV U 4 3002 4-1/2' 1-1/2' 3 5200 4-1/2 1-112' 2 6967 4-1/2 1-1/2' 1 8535 4-112' 1-1/2' I 4-1/2" HES "X" NIP, ID = 3.813 1-1 I I I 9-5/8" X 4·1/2" BKR S-3 PKR, 10 = 3.813" 1-1 I VII' ;8 ......,. I / I 4-1/2" HES "X" NIP, ID = 3.813" 1-1 I I'" UNIQUE MACHINE OVERSHOT I 14-112" TBG, 12.6#, 13Cr-80, VAMTOP 1 8775' TBG SEAL ASSY I ~ -- I 8798' H9-518" X 4-112" BKR SAB-3 PKR, ID" 3.S13" I ~ I 8844' H4-112" OTIS X NIP, ID = 3.813" I . II I 8857' 3.7" BKR DEPLOYMENTSLV,ID= 3.0" I . I 8855' 3-1/2" X 3-3/1&" XO, ID" 2.80" I I TOP OF 7" LNR 8859' I I 8875' 4-112" OTIS XN NIP, MILLED ID = 3.SO" I (B81IND CT LNR) 4-112" TBG, 12.6#, L-SO, .0152 bpf, ID= 3.95S" 8907' I 8907' 4-112" TBG TAIL ID = 3.958" I I 9-5IS" CSG, 47#, L-80, ID = 8.681" I .41 ~ (BEHIND CT LNR) 9347' I ......... I TOP OF WHIPSTOCK 9535' I I I MlLOUT W'NOON 9532' - 9539' .. .. .. l 9637' 3-3116" X 2-7/S" XO, ID = 2.3S0" I .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. H .. .. 7" LNR, 29#, L-SO, .0371 bpf, ID = 6.184" 10331' .. .. J .. .. .. .. PERFORATION SUMMARY ......:...... I 11658' ~ REF LOG: EWR-GR ON 08113JC3 ...r I'<:-j ANGLE A T TOP PERF: 52 @ 9640' I 3-3116" LNR, 6.2#, L-SO, .OOS1 bpf, ID = 2.880" .. .. Note: Refer to A'oduction DB for historical peri data .. .. SIZE SPF INTERVAL Opn/Sqz DATE SLOTTBJ LINER 4 9640 - 10127 0 08118103 12-7/S" SL TDlSOLID LNR, 6.16#, L-80, .0555 bpf, ID" 2.372" 11691' I 4 1 0233 - 1 0568 0 08118/03 4 10974 - 11658 0 08118/03 DATE RBI BY COM'ÆNTS DATE RBI BY COIIIWéNTS PRUDHOE SAY UNIT 05131/80 OAGlNAL COMPLETION 08I09J05 EZLJPJC Œl.ETEWAIVERSFTY NOTE W8...L: X-Q8A 08119/03 JLM/KK CrD SlŒTRACK (X-08A) 04126/06 JPKlPJC GLV iVD CORRECTIONS PERMT No: '"¿œ1170 08121/03 RWLIKK GLV C/O 04127106 DWIPJC GLV C/O API No: 50-029-20463-01 09102/03 BJMKK SET ECLIPSE PATCH see 7, T10N, R14E, 432' FSNI.. & 264' FW8.. 01102105 RVVLITLP GLV C/O 01/24105 LDKlPJCCI SET BKR IBP BP exploration (Alaska) · STATE OF ALASKA . AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o o o .. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 73.48 KB 8. Property Designation: ADL-028313 11. Present Well Condition Summary: Total Depth measured 11691 true vertical 8904.17 Effective Depth measured 11658 true vertical 8901.3 Casing Conductor Surface Production Liner Liner Sltd/Solid Liner Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 Length 110 2646 9316 673 787 835 Perforation depth: Measured depth: 9640 - 10127 slotted liner True Vertical depth: 8908.61 - 8915.11 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 608 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R] Stratigraphic fJ feet feet ,;¡,(".~ ¡\~ NJ~; r ~V7\W:: -",~ 'Jj~~ feet feet MD 33 - 143 32 - 2678 31 - 9347 8859 - 9532 8857 - 9637 9637 - 11691 10233 - 10568 slotted liner 8903.02 - 8882.89 4-1/2" 12.6# Stimulate 0 Other 0 Bradenhead weld WaiverD Time Extension 0 & pulllBP Re-enter Suspended Well 0 Fis in hole 5. Permit to Drill Number: 203-1170 6. API Number: 50-029-20463-01-00 9. Well Name and Number: Exploratory Service Colt 'It:" I» ~ c...... c: X-08A ;:, n =r . 10. Field/Pool(s): ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool C1Þ Plugs (measured) Junk (measured) TVD 33 - 143 32 - 2677.88 31 - 8639.53 8184.85 - 8815.87 8183.01 - 8906.59 8906.59 - 8904.17 10974 - 11658 slotted liner 8854.55 - 8901.3 L-80 9-5/8" DV Packer 4-1/2" Eclipse Patch Packer 4-1/2" Eclipse Patch Packer 4-1/2" Baker SAB-3 Packer None -9600 Burst Collapse 1490 470 5380 2670 6870 4760 8160 7020 13450 13890 31 - 8907 2609 8578 8613 8798 RBDMS 8FL ,UN 2 1 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure shut-in 1501 6577 320 231 15. Well Class after proposed work: Exploratory Development R] Service 16. Well Status after proposed work: Oil R] Gas fJ WAG fJ GINJ fJ WINJ WDSPL fJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu~ -lA Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 ORIGINAl Tubing pressure Sundry Number or N/A if C.O. Exempt: N/A Date 6/12/2006 Submit Original Only # . X-08A I ~ESCRIPTION OF WORK COMPLET NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 25 Meth 143 Crude 580 1 % KCL 748 TOTAL I ACTIVITYDATE I StJMMARY+'íl1 4/17/2006 T/I/O=10/35/6. Temp=SI. Bleed WHP's & Prep for BH weld. (Pre-Rig). Bled TP from 10 psi to 0 psi in 10 minutes. Bled lAP from 35 psi to 0 psi in 15 minutes. Bled OAP from 6 psi to 0 psi in 5 minutes. OA FL @ 45' (2.61 bbl). Pressure up OA W/N2 and bleed pressure off. R/U tree cap to bleed trailor, RIU N2 to IA (no GLV in sta#4) and U tube 7+ bbls fluid from TBG to slop trlr. R/U jumper from IA to tree cap and let fluid Ivls equalize. TBG FL @ 180' (3 bbl). IA FL @ 150' (8 bbl). AL & Prod lateral valves closed and flagged. Bled Prod riser to 0 psi. AL line @ 0 psi. Final WHP's=OIOIO. 4/18/2006 T/I/O=1/3/6. Temp=SI. Bradenhead weld. (Pre-Rig). Bled WHP's tp 0 psi in 2 minutes. Kept a 10 psi N2 purge on the OA void for the duration of the job. Welders made 3 passes on both the upper and lower bradenhead threaded connections. Welders re-heated weld areas and installed insulated fire blanket on the well head. Re-installed the cellar boards and rigged down. Final WHP's=OIOIO. 4/21/2006 T/I/O= 01010. MIT-OA to 2500 psi.(post braiden head repair) [PASSED on the second attempt] Lost 40 psi I 1st 15 min & 20 psi 12nd 15 min. Pumped 4.4 bbls of 50* crude to achieve test pressure. Final WHP= 01010. 4/26/2006 ***WELL SI ON ARRIVAL ***(post bh repair) VECO REMOVED VR PLUG FROM IA. PULLED 2 1/8" BAKER IBP FROM 8810' SLM - LOST ALL 3 RUBBER ELEMENTS (BEAT PLUG THRU PATCH @ 8571' SLM). RAN 3.75" WIRE GRAB - FISHING RUBBERS AT REPORT TIME. ***CONT ON 4-27-06*** 4/27/2006 ***CONT FROM 4-26-06*** (post bh repair) DRIFTED SEVERAL TIMES W/2 7/8" BLB, 2.15" CENT & 2.0" SPEAR TO 9600' SLM, RECOVERED 6" RUBBER ELEMENT & SEVERAL SMALL RUBBER PIECES. PULLED STA#3 @ 7547' SLM & STA#5 @ 2951' SLM, STA#4 @ 5151' SLM EMPTY. SET GL DESIGN AS PER PROCEDURE. PULLED EMPTY WHIDDON CATCHER @ 8519' SLM. RAN SBHPS GAUGES AS PER PROCEDURE. ***GIVE WELL BACK TO DSO, LEFT SI*** NOTE: 6" IBP RUBBER ELEMENT LEFT I.H. 4/30/2006 TIIIO = 220/1200/380. SI. 80 deg. WHPs post POP (evallA x OA). AL line shut-in (0 psi). Note: Jumper hose on IA to S riser on flowline? 6/9/2006 T/I/O= 260/1120/540. Temp= Hot. Eval bradenhead leak (FO call in). Bradenhead appears to be leaking from the 6 o'clock position. Cleaned to be evaluated at a later date. 6/10/2006 T/I/O=300/16801710 Temp=HOT Evaluate for possible continuing bradenhead leak. BH is definitely leaking @ 6 o'clock position. The leak is tiny with a 1" wide x 6" long path of oily residue on surface casing post cleaning of 06/09. Re-cleaned casing for further evaluation. 6/11/2006 T/I/O=280/1640/830. Temp=HOT. Eval continuing Bradenhead leak. (Post BH weld). Well head is still leaking from the upper weld. I will take Pic's and send to the WIE & WIC. Cleaned wellhead for further evaluation. ') ) WELL LOG TRANSMITTAL dD~-1I1 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 ":S",:JO RE: MWD Fonnation Evaluation Logs X-08A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 X-08A: LAS Data & Digital Log Images: :tjCJ\NNEL)¡ MAH 0 ~) 2005 50-029- 20463-01 1 CD Rom ~~~1ì 9'1 ~ò1íCti J7¥ DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permitto Drill 2031170 Well Name/No. PRUDHOE BAY UNIT X-OBA Operator BP EXPLORATION (ALASKA) INC .J'f'J "'" c!. , ) ~"'1 :t~ d.J API No. 50-029-20463-01-00 MD 11691 / TVD 8904" Completion Date 8/17/2003 ~ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ DATA INFORMATION Types Electric or Other Logs Run: EWR, GR Well Log Information: Log/ Electr Data Digital Dataset Type MedlFrmt 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 -e6 D .~ l.~ 12209 Rate of Penetration .,.- w.'" 1 ED D 12209 Induction/Resistivity 4pt 12209 Rate of Penetration ~pt 12209 Induction/Resistivity E6 . . D .¡aefM,,~ l Directional Survey ~pt Directional Survey Name 9527 11665 Open 1 0/1 0/2003 GR, ROP, EWR4 9527 11665 Open 10/10/2003 GR, ROP, EWR4 9527 11665 Open 1 0/1 0/2003 GR, ROP, EWR4 9527 11665 Open 10/10/2003 GR, ROP, EWR4 9500 11691 9/24/2003 9500 11691 9/24/2003 Sample Interval Set Start Stop Sent Received Number Comments . Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y@ Daily History Received? <$N (b Chips Received? £è1',' N>-' Formation Tops Analysis Received? - Y I N Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 PermittoDrill 2031170 Well NamelNo. PRUDHOE BAY UNIT X-08A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20463-01-00 MD 11691 TVD 8904 .p:;:;tion Date 8/17/2003 Completion Status 1-01L Current Status 1-01L UIC N Date: ;2) NOv a.t\i\ \- Compliance Reviewed By: . . X-08A (PTD #2031170) Internal Waiver Cancellation It Sub,icet: X-08A (Pl~tf6;\Hq'O)mtemal Waiver Cancellation From: "DlIbc, Anna T" <Anna.DlIhe({?)BP.com> Hate: TlIC, 09 AlIg 2005 11 :30:52 -0800 To: "AOGCC - Winton Aubert (E-rnail)..<winton_aubcrt@admin.statc.ak.us>. j i m.._rcgg@admin.statc.ak.lIs cc: "NSLJ, ADW Well Integrity Engineer" <NSUADWWellJntcgrityEngincer@BP.com>, "Luckett, Ely Z. (VECO)" <luckcz@BP.com> e ~~ rlq lot; Winton and Jim, The internal BP waiver for IAxOA communication on well X-08A (PTD #2031170) has been cancelled. The well is shut-in and secured in preparation for a rig workover and bradenhead weld. Please let me know if you have any questions. Thank you, )lnna CJJu6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 8/10/20054:15 PM . . aO,3--} )T WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska October 02, 2003 RE: MWD Fonnation Evaluation Logs X-08A, AK-MW-2600190 1 LDWG fonnatted Disc with verification listing. J 8 8-C51 JlPI#: 50-029-20463-01 \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LEITER TO THE AITENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: _.< o,',~ Signed~e\~'j~~~QL~/Y,,- ~~~Ç\,\~ ... STATE OF ALASKA .- ALAS~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 430' SNL, 264' WEL, SEC. 07, T10N, R14E, UM Top of Productive Horizon: 1993' SNL, 2275' EWL, SEC. 08, nON, R14E, UM Total Depth: 843' SNL, 3824' EWL, SEC. 08, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 665631 y- 5939693 Zone- ASP4 TPI: x- 668209 y- 5938188 Zone- ASP4 ---~ Total Depth: x- 669728 y- 5939372 Zone- ASP4 ~_._._-~ 18. Directional Survey a Yes 0 No 21. Logs Run: EWR, GR 22. CASING SIZE 20" x 30" 13-3/8" 9-5/8" One Other 5. Date Comp., ~~sp., or Aband. 8/~/2003 6. Date Spudded 8/13/2003 7. Date T.D. Reached 8/17/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 73.48' 9. Plug Back Depth (MD+ TVD) 11691 + 8904 Ft 10. Total Depth (MD+TVD) 11691 + 8904 Ft 11. Depth where SSSV set (Nipple) 2117' MD 19. Water depth, if offshore N/ A MSL GRADE Conductor L-80 SOO-95 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPtH HOLE lOP BOTTOM SIZE Surface 110' 36" Surface 2678' 17-112" Surface 9347' 12-1/4" 8859' 9539' 8-1/2" 8851' 11691' 3-3/4" x 4-1/8" CEMENtiNG RECORD 8.5 cu yds Concrete 3913 cu ft Permafrost 1310 cu ft Class 'G', 130 cu ft PF 'C' 366 cu ft Class 'G' Uncemented Slotted Liner WT.PERFT. Insulated 72# 47# 29# 8.81# /6.2# /6.16# 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Slotted Section MD TVD MD TVD 9640' - 10127' 8909' - 8915' 10233' - 10568' 8903' - 8883' 10974' - 11658' 8855' - 8901' 26. Date First Production: September 6,2003 Date of Test Hours Tested 9/11/2003 4 Flow Tubing Casing Pressure Press. 214 PRODUCTION FOR TEST PERIOD + CALCULATED + 24-HoUR RATE OIL-BBL 24. SIZE 4-1/2", 12.6#, L-80 Tubing Patch 25. DEPTH INTERVAL (MD) 2000' 1 b. Well Class: a Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-117 303-235 13. API Number 50- 029-20463-01-00 14. Well Number PBU X-08A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028313 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) * 3-1/2" x 3-3/16" x 2-7/8" TUBING DEPTH SET (MD) 8907' 8578' - 8613' PACKER SET (MD) 8798' 8578' & 8613' AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH ORIGINAL CHOKE SIZE I GAS-OIL RATIO 960 2,009 OIL GRAVITY-API (CORR) 25.2 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attaclÌseparatesh$t,ifriecessary). Submit core chips; if none, state "none". GAs-McF 1,997 GAs-McF W A TER-BBL 6,000 W A TER-BBL PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BBL 994 .f'-C:j~.::·i_:-C;~~_·;~J ¡ .__ í.~~'¿.:>. ')'TE / ' ~¡ '~J , I _________ __11 Form 10-407 Revisëcf 2/2003 None 8 CONTINUED ON REVERSE SIDE GF R8DMS BfL SEP 21 tIJU3 NAME MD TVD 129. .RMATION TESTS Include and brietlY!iúmmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. GEOLOGIC MARKER~ Sadlerochit 9630' 8902' None 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~AItt W. dH" Title Technical Assistant Terrie Hubble . . (/. NtU7T.J'-t_ PBU X-08A 203-117 303-235 Well Number Date ()Q./8"03 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mark Johnson, 564-5666 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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 2/2003 ~ .. Page 1 of 10 BP EXPLORATION Operati·ons Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date X-08 X-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 8/8/2003 From - To : Hours : Task Code NPT Phase 00:00 - 06:00 6.00 MOB P PRE 06:00 - 06:30 0.50 MOB P PRE 06:30 - 08:30 2.00 MOB P PRE 08:30 - 09:30 1.00 MOB P PRE 09:30 - 11 :00 1.50 MOB P PRE 11 :00 - 15:00 4.00 MOB P PRE 15:00 - 15:30 0.50 MOB P PRE 15:30 - 17:30 2.00 MOB P PRE 17:30 - 19:00 1.50 MOB N PRE 19:00 - 20:00 1.00 MOB P PRE 20:00 - 22:00 2.00 MOB N PRE 22:00 - 00:00 2.00 MOB P PRE 00:00 - 01 :00 1.00 MOB N WAIT PRE 01 :00 - 02: 15 1.25 MOB P PRE 02:15 - 02:35 0.33 MOB P PRE 02:35 - 06:00 3.42 MOB P PRE 06:00 - 06:30 0.50 MOB P PRE 06:30 - 14:00 7.50 MOB P PRE 8/9/2003 14:00 - 14:30 0.50 MOB P PRE 14:30 - 15:00 0.50 MOB P PRE 15:00 - 18:00 3.00 BOPSUR P PRE 18:00 - 18:30 0.50 BOPSURP PRE 18:30 - 20:30 2.00 BOPSURP PRE 20:30 - 00:00 3.50 BOPSURP PRE 8/10/2003 00:00 - 02:15 2.25 BOPSUR P PRE 02:15 - 04:00 1.75 RIGU P PRE 04:00 - 06:00 2.00 RIGU P PRE 06:00 - 06:30 0.50 RIGU P PRE 06:30 - 08:00 1.50 RIGU P PRE 08:00 - 09:00 1.00 RIGU P PRE 09:00 - 13:30 4.50 RIGU N RREP PRE 13:30 - 14:15 0.75 STWHIP P WEXIT 14:15-15:30 1.25 STWHIP N DFAL WEXIT 15:30 - 15:50 0.33 STWHIP N DFAL WEXIT 15:50 - 18:20 2.50 STWHIP N DFAL WEXIT 18:20 - 19:00 0.67 STWHIP N DFAL WEXIT Start: Rig Release: Rig Number: Spud Date: 5/10/1980 End: 8/18/2003 8/7/2003 8/18/2003 N1 Description of Operations ____n______.__ _._..._. ....------- Continue rig move from W Pad to Price Pad. Arrive on Price pad at 06:00 Crew Change. Safety meeting on Price Pad, discuss plan forward for installing bogeys. Remove BOP stack from cellar. Prep cellar for Bogeys. Remove reel from reel house place on lowboy trailor. Install Bogeys in cellar. Scope down derrick adn layover in pipeshed Safety mtg for rig move Move rig off Price Pad and onto Spine and head to X Pad Standby at GC-3 for crew change traffic Resume move to X Pad Standby at X Pad access road and wait for TS to fin laying rig mats Resume move down X Pad road Arrive on X Pad. Standby while TS moves rig mats to cover access road to back of Pad Move rig to back Pad and position near well for RU Safety mtg re: raise/scope out derrick Open pipeshed roof. Rasie derrick. Close roof. Scope out derrick. Raise windwalls. Tighten guy wires. TS set rig mats in front of well. TL meeting/crew change, review written procedure for removing bogeys. Tieback bridle lines. Remove Bogeys from cellar. Install mousehole, stairs and platforms in cellar. Place BOP stack in cellar, MU hydraulics, position & secure stack. Prepare rig to move over well. PJSM, discuss pulling over well. Review Schlumberger/Nordic procedure. Spot rig over well. NU BOPE. Rig Accepted at 17:00 hrs. TL meeting/crew change Fin NU BOPE. Hook up sensors to lA, OA. IA=422, OA=500 DS techs fine tune rig data acquisition systems Initial BOPE test. Witness waived by AOGCC Set reel in reel house w/140T Peak crane. Hook up harline Unload trailers and spot equipment Finish initial BOPE test PJSM. Pull injector out of box and prep. Install gooseneck PJSM. Pull CT off reel and begin stab into injector Tech Limits, crew change Stab injector. Troubleshoot CTDS II outputs. PU injector. Install Schlumberger CTC. Pull test, pressure test same. Pump coil dart, CT vol=56.4 Trouble shoot CTDS II Outputs Pre-Spud meeting with team. Discuss well objectives, hazards and plan forward. PU BHA #1: Nozzle, 5' stinger, checks. Stab injector. PT hardlines to 4500psi. RIH with BHA #1. WHP=Opsi. Attempt to fill well down backside with 2% KCI 3 bpm/O psi w/ 232 bbls Park at 8730' End liquid pack. RIH pumping down CT w/ KCI Printed: 8125/2003 9: 1 0:00 AM ..... . Page 2 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date --...-... 8/10/2003 8/11/2003 X-08 X-08 REENTER+COMPLETE Start: NORDIC CALISTA Rig Release: NORDIC 1 Rig Number: I From - To Hours Task' Code ¡ NPT I Phase .J_...__ __~._... !..___~_____.__... 18:20 - 19:00 0.67 STWHIP N DFAL WEXIT 19:00 - 20:55 1.92 STWHIP N DFAL WEXIT 20:55 - 22:20 1.42 STWHIP N DFAL WEXIT 22:20 - 22:45 0.42 STWHIP N DFAL WEXIT 22:45 - 00:00 00:00 - 00:20 00:20 - 01 :30 01 :30 - 03:00 1.25 STWHIP N 0.33 STWHIP N 1.17 STWHIP N 1.50 STWHIP N DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT 03:00 - 04:00 1.00 STWHIP N DFAL WEXIT 04:00 - 05:05 05:05 - 05:30 1.08 STWHIP N 0.42 STWHIP N DFAL WEXIT DFAL WEXIT 05:30 - 07:00 1.50 STWHIP N DFAL WEXIT 07:00 - 07:30 0.50 STWHIP N DFAL WEXIT 07:30 - 08:00 0.50 STWHIP N DFAL WEXIT 08:00 - 10:00 2.00 STWHIP N DFAL WEXIT 10:00 - 12:00 2.00 STWHIP N DFAL WEXIT 12:00 - 13:00 1.00 STWHIP N DFAL WEXIT 13:00 - 18:00 5.00 STWHIP N DFAL WEXIT 18:00 - 21 :30 3.50 STWHIP N RREP WEXIT 21 :30 - 21 :50 0.33 STWHIP N DFAL WEXIT 21 :50 - 22:35 0.75 STWHIP N DFAL WEXIT 8/7/2003 8/18/2003 N1 Spud Date: 5/10/1980 End: 8/18/2003 Description of Operations .... u_._.__. .._ ....-...-..- 2.0/480 psi to WS and tag at 9547' CTD w/ 3k-no returns. Swap to 200+K LSRV mud down CT. PUH 40k to 9500' Park at 9500' CTD 2.0/1300 30 bbls into mud dn CT-no returns. PVT 269 Mud at nozzle (CTV=60 bbls) 2.0/1930-no returns. IA 565, OA 600 After 30 bbls of mud out nozzle 2.0/2050-no returns. SI at choke and bullhead mud down CT 2.0/2080 psi CT/O psi WHP/IA 632 After 100 bbls mud out nozzle 2.0/2200 psi CT/O psi WHP/IA 720 Open choke to take returns-none After 150 bbls mud out nozzle 2.0/2170-no returns IA 700 Swap to KCI to displace mud PVT 269 With 10 bbls KCI out noz 2.0/800-no returns IA 778 POOH 35k 70'/min diluting any mud in 7" liner 2.0/780 then POOH Total fluid lost to formation about 500 bbls 2% KCI, 200 bbls mud Tag up at 2.0/850-no returns. SI swab. IA 600 Do circ test thru 'out' MM. Needs a little work, may be electrical prob LD nozzle assy. MI HOWCO WL unit X Pad SD for welding work tomorrow-Pad oper bleeding MI gas Fin spot HOWCO WL unit and gather tools Safety mtg re: RU WL tools Bring WL tools to floor and RU Open swab-well sucked grease off the 4" Otis connection to packoff! RIH wI BOT WS retrieval tool w/ bait sub + spangs + oil jars Fill hole w/ 2% KCI w/ charge pump at 1.4 bpm Tag at 9510' BLM. Work to bait fish, but kept missing FN and stopping at pinch point POOH w/ WL to check tool OOH w/ tools. SI swab. Remove bait sub and inspect. Found marks on bottom of OS indicating contact w/ top of FN. Also mark inside on BOT latch assy showed it contacted top of WS. IA 520, OA 600 WO BOT to take retrieval tool to shop to change dogs on tool PJSM with slickline crew. PU Baker retrieval tool and bait sub. Wait on orders. Repair wear ring on mechanical depth counter wheel on CT reel. RD slickline Confirm MM in/out readings are consistent. RU 400bbl open top tank. Position trucks. Continue to troubleshoot CTDS II, MM in and out rates. Receive orders to pump cement Wait on DS techs to troubleshoot CTDS II and get most fixed. Still have problems w/ 'out' MM, OA. Chk IA at 500 psi and fluid Safety mtg re: Nordic crew change/Prespud MIRU cementers. Bypass inlet filters. Install cementing assy and stab onto lub. Pump fluid to flowback tank to chk line Printed: 8/25/2003 9: 1 0:00 AM ..... . Page 3 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08 X-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task I Code NPT Phase I 8/11/2003 22:35 - 00:00 1.42 STWHIP N DFAL WEXIT 0.25 STWHIP N DFAL WEXIT 0.08 STWHIP N DFAL WEXIT 0.42 STWHIP N DFAL WEXIT 0.17 STWHIP N DFAL WEXIT 0.75 STWHIP N DFAL WEXIT 8/12/2003 00:00 - 00:15 00: 15 - 00:20 00:20 - 00:45 00:45 - 00:55 00:55 - 01 :40 01:40 - 02:00 0.33 STWHIP N DFAL WEXIT 02:00 - 02:55 0.92 STWHIP N DFAL WEXIT 02:55 - 03:05 0.17 STWHIP N DFAL WEXIT 03:05 - 03:25 0.33 STWHIP N DFAL WEXIT 03:25 - 05:30 2.08 STWHIP N DFAL WEXIT 05:30 - 05:50 0.33 STWHIP N DFAL WEXIT 05:50 - 06:45 0.92 STWHIP N DFAL WEXIT 06:45 - 08:00 1.25 STWHIP N DFAL WEXIT 08:00 - 09:00 1.00 STWHIP P WEXIT 09:00 - 10:30 1.50 STWHIP P WEXIT 10:30 - 12:15 1.75 STWHIP P WEXIT Start: Rig Release: Rig Number: Spud Date: 5/10/1980 End: 8/18/2003 8/7/2003 8/18/2003 N1 Description of Operations Open swab-on vac. IA 490, OA 600. RIH w/ BHA #2 at 0.5 bpm/30 psi PVT 296 Safety mtg re: cement Continue RIH w/ cement assy. 8900' 34.4k 0.5/0 psi Tag WS at 9544' CTD, corr to pinch pt at 9536' ELMD PVT 240, IA 540 PUH 36.4k to 9400' EOP (9407.7') and flag CT PT DS at 3000 psi. DS load CT w/ 5 bbls neat, 40 bbls 15#/bbl aggregate, 5 bbl neat 13.8 ppg 'G' cement w/ bentonite 2.2/980 RIH 26.5k from 9400' after 30 bbls pumped 2.1/850. DS displace w/ 5 bbl FW Swap to rig pump w/ KCI 2.0/640 and displace cmt. PUH 42.6k 3'/min from 9510' with cmt at nozzle and with open choke. Cement was running away at 2.0/350 psi until caught pressure (fluid in CT) at 40 bbls cmt out nozzle w/ CT at 9400'. Also, started getting air/crude/KCI returns at same time. Ship to flowback tank. Incr pulling speed to 10-30'/min while lay in cement in liner. Last bbl out at 9080' 2.0/1130. CIP 0125. PUH at max speed to safety at 2.0/1135 Cmt TT 4:20 (an eternity) Park at 8000' and red rate to 0.5 bpm and guesstimate nearly full returns (air/crude/KCI). Swap to bio water. IA 960 Pressure up wellbore to 200 psi and IA rose to 1140. Circ 1/1. Bleed fluid, then gas off IA to tiger tank until getting fluid returns. RIH to maintain WHP IA 760 Park at 8580' and pressure wellbore to 500 psi with choke SI. IA rose to 1265 psi. Lost 40 psi each (thru pump) in 10 min. Bleed off press RIH 1.6/1060 circ'ing bio to nozzle. Jet from assumed WCTOC at 9080' 2.0/1280 at 35'/min to 9400'. Jet OOH 2.25/1340 displacing wellbore to bio water. Got cement back 20 bbls earlier than expected. .. Swap from flowback tank to cuttings box while POOH IA 815 Jet stack LD cementing BHA. IA 560 Cut off DS CTC. Install BOT CTC. Pull test, pressure test same. Wait on Cement compressive strength. Expect to have 200-300psi in 6hrs. Hole is full, no drop in fluid level. PU BHA #3, Window Milling assembly: HCC diamomd window mill, Xtreme MM, circ sub, hyd disconnect, XO, 2jts PH6, XO, Dual Back press valve, Baker eTC. RIH with BHA #3. IA=570psi, OA=560psi. Bring pumps on to 0.5bpm once inside 7" liner. UP wt at 9400' =39K. Add bio to KCL in pits to bring system concentration to approx 1.5ppb. Tag cement top at 9433'md, uncorrected. (Cement has been in place 9hrs) PVT=296bbl. PU, 2.5bpm/1870psi off bottom. IA=840psi,OA=600psi. Mill to 9460', 2.5bpm 1900psi with very little motor work or resistance. Short trip to 9400', clean PU. Circ press drops to 1570psi at 2.5bpm as we resume milling. Hmm, slick fluid coming around? IA press=785psi. PVT=296bbl. EOP FLAG, subtract 10'. Mill to 9493'. PU=40K, short trip up to 9400'. TOC=9423'md, corrected. Mill Printed: 8/25/2003 9: 1 0: 00 AM ,.,. .. BP EXPLORATION Operations Summary Report Legal Well Name: X-08 Common Well Name: X-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 I Date ! From - To Hours Task Code NPT Phase ....--.. ..----------. --~-_. 8/12/2003 10:30 -12:15 1.75 STWHIP P WEXIT 12:15 -14:40 2.42 STWHIP P WEXIT Page 4 of 10 Start: 8/7/2003 Rig Release: 8/18/2003 Rig Number: N1 Spud Date: 5/10/1980 End: 8/18/2003 Description of Operations ...----... to 9511', short trip back to 9400'. PU still clean. Cement getting harder to mill near 9525'md. Stall motor, tag whipstock at 9532'md. (Did not correct depth to pinch point) PU and backream cement pilot to 9400'. PVT=294bbl. Freespin= 1520psi @ 2.5bpm. RIH wt=21.8K Start milling at 9531.8'md. 2.5/2.5/1600psi. CT in out string Time Depth Prog BPM BPM Press wt 12:56 9532.8' l' 2.5 2.5 1685 21.0K 13:28 9533.3' 1.5' 2.5 2.5 1780 19.1 k 14:00 9533.8' 2.0' 2.5 2.5 1920 17.6K 14:30 9534.3' 2.5' 2.5 2.5 1967 16.3k PVT=290 WEXIT PU to check parameters, up wt=39K, pull up to 9528'. RIH wt=17K, Freespin=1750 @ 2.5bpm. PVT=290. Continue Milling CT in out string Time Depth Prog BPM BPM Press wt 15:10 9534.8' 3.5' 2.5 2.5 1941 15.9k PVT 294 16:20 9536.7' 5.4' 2.5 2.5 1940 15.4k PVT 291 chk FS at 1750 17:25 9537.8' 6.5' 2.5 2.5 2080 16.0k PVT 291 chk FS at 1830 17:50 9539.6' 7.9' 2.5 2.5 2100 15.3k PVT 290 stall, FS 1880 18:30 9540.0' 8.2' 2.5 2.5 2050 18.7k PVT 288 end l' of OH POOH for string reamer. Bottom of window at 9539.0', drilled l' of formation to 9540'. Flag at 9540' bit depth IA 910, OA 625 Tag up at surface with BHA #3. Stand back injector. Safety meeting prior to changing out BHA. Break out window mill. Gauged at 3.80". Found swirl pattern on mill face. PU string reamer. Gauged 3.77". Make up string reamer and same window mill. Locktight both connections below motor. WEXIT RIH with BHA #4 to dress window and drill rathole. WEXIT Bring on pumps to full rate. Free spin 2.5 bpm, 2000 psi. RIH, tag up 7' shy of TD flag. Probably top of window. Make -16' correction. Mill down thru top of window. Pump 20 bbl sweep of 2# biozan to clean hole of cutting. Grabby at top of window, then got thru it. Continue dressing window, swapping to mud. 9540', back at TD. Begin milling rat hole. Continue milling rathole from 9544'-9550'. Backream window. Dry drift down and back up. No weight bobbles or problems. POH for build section BHA. Tag up, stand back injector. Lay down Baker motor. Check mills. Both mills recovered with no change in gauge. Window 14:40 - 18:30 3.83 STWHIP P 18:30 -19:55 1.42 STWHIP P WEXIT 19:55 - 20:05 0.17 STWHIP P WEXIT 20:05 - 20:15 0.17 STWHIP P WEXIT 20:15 - 20:30 0.25 STWHIP P WEXIT 20:30 - 22:00 22:00 - 22:50 1.50 STWHIP P 0.83 STWHIP P 22:50 - 23:30 0.67 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 8/13/2003 00:00 - 00:50 0.83 STWHIP P WEXIT 00:50 - 01 :20 0.50 STWHIP P WEXIT 01 :20 - 02:40 1.33 STWHIP P WEXIT 02:40 - 03:20 0.67 STWHIP P WEXIT Printed: 8/25/2003 9: 1 0:00 AM ..... . BP EXPLORATION Operations Summary Report Page 5 of 10 Legal Well Name: X-08 Common Well Name: X-08 Spud Date: 5/10/1980 Event Name: REENTER+COMPLETE Start: 8/7/2003 End: 8/18/2003 Contractor Name: NORDIC CALISTA Rig Release: 8/18/2003 Rig Name: NORDIC 1 Rig Number: N1 , From - To ; Hours Code! NPT ; I Description of Operations Date Task Phase I ---.... -..---..- n_______n ..------...--" 8/13/2003 02:40 - 03:20 0.67 STWHIP P WEXIT mill=3.80", SR=3.77". 03:20 - 03:50 0.50 DRILL P PROD1 Pre spud safety meeting with all rig hands and contractors. Discussed unusual aspects of this well, the hazards, and mitigations. 03:50 - 04:30 0.67 DRILL P PROD1 Cut Baker CTC, install SWS eTC. Pull test to 35klbs. PT to 3500 psi. 04:30 - 05:10 0.67 DRILL P PROD1 Make up drilling BHA. (BHA #5). 3.75" M-09 bit, 2.83 deg motor, Directional-GR, MHA. 05:10 - 05:45 0.58 DRILL P PROD1 RIH with BHA #5 to begin drilling build and turn section of hole. 05:45 - 06:25 0.67 DRILL N DFAL PROD1 3100', While RIH to do shallow hole test BHA plugged off. Can't pump. Can't blow it free with pump pressure. POH to troubleshoot BHA. 06:25 - 07:25 1.00 DRILL N DFAL PROD1 OOH. Check BHA. Found Sperry hex driver used to tighten 13/32" jet in bleed sub was still attached to jet. MU BHA 07:25 - 08:00 0.58 DRILL N DFAL PROD1 RIH w BHA #1 RR. SHT pulse at 800' 08:00 - 09:05 1.08 DRILL P PROD1 3100' Continue RIH. Bring KG up to 8 ppb 09:05 - 09:20 0.25 DRILL P PROD1 9500' CTD Check TF 2.5/3100/167L. Orient to high left and get 53L. RIH thru window, clean (see flag -15.5' off and did not correct) and tag at 9563' CTD 09:20 - 09:50 0.50 DRILL P PROD1 PUH 38k and chk TF at 111 R. RIH and tag at 9561' CTD, corr to 9550'. Orient around. Toggle MWD 09:50 - 11 :30 1.67 DRILL P PROD1 Drill from 9561' 2.6/3150/36L to 9585' and see RA marker. Corr +5' to BHCS. Official depths to PDC log are TOWS 9535', TOW 9539', BOW 9545', RA marker 9545' 11 :30 - 14:15 2.75 DRILL P PROD1 Drill from 9585' 2.6/3200/3L to 9620' and slow digging in Shublik. Wiper to window PVT 340 14:15-15:15 1.00 DRILL P PROD1 Orient a bunch to keep HS TF after getting into Z4 15:15 - 16:30 1.25 DRILL P PROD1 Drill from 9620' 2.6/3140/10L Will be landing up to 16' deep, but okay w/ geo. Drll to 9696'. Wiper to window 16:30 - 17:30 1.00 DRILL P PROD1 Drill from 9696' 2.5/3020/3L to 9755' 17:30 - 17:40 0.17 DRILL P PROD1 Survey at 9755' 2.6/2960/5R PVT 336 17:40 - 17:50 0.17 DRILL P PROD1 Drill from 9755' 2.6/2970/3R to 9769' and landed at 8872' (12' deep) 17:50 -18:10 0.33 DRILL P PROD1 Wiper to window. Orient around to add some footage to turn 18:10 -18:25 0.25 DRILL P PROD1 9769', Drill at 90L tool face to line up with polygon prior to tripping for motor and RES tool. Free spin=3300 psi at 2.7 bpm. Pit vol=334 bbls. IAP=1100 psi, OAP=750 psi. 18:25 - 18:50 0.42 DRILL P PROD1 Pull up to the shoe to orient 1 click. 18:50 - 19:15 0.42 DRILL P PROD1 Resume drilling at 90L. 19:15 - 20:45 1.50 DRILL P PROD1 9790'. POH for lateral section BHA and RES tool. 20:45 - 21 :00 0.25 DRILL P PROD1 Tag up at surface. Hold PJSM re BHA swap. 21 :00 - 23:00 2.00 DRILL P PROD1 Lay down BHA #5. M09 bit recovered in good shape at 1,1. Lay down motor. Pick up new motor, bit and RES tool. Program RES tool. 23:00 - 00:00 1.00 DRILL N RREP PROD1 Schlumberger technicians working to get micro motion meters repaired. 8/14/2003 00:00 - 00:45 0.75 DRILL N RREP PROD1 Continue working on rig repairs. 00:45 - 01 :00 0.25 DRILL P PROD1 Pickup injector. 01 :00 - 02:30 1.50 DRILL P PROD1 RIH with BHA #6, Shallow hole test at 500' passed ok. 02:30 - 03:30 1.00 DRILL N RREP PROD1 8150', POOH. Motor man found an apparent leak from the mud pits. Need to repair prior to continuing with operations. POOH with drilling BHA to make repairs. Motor man reports Printed: 8/25/2003 9: 1 0: 00 AM /- ~ ~ . Page 6 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: i Date ! From - To _1 n X-08 X-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Phase 8/7/2003 8/18/2003 N1 Spud Date: 5/10/1980 End: 8/18/2003 RREP PROD1 that a small amount of leaking mud was contained in secondard containment, there has been no release of mud to the environment at this time. RREP PROD1 Tag up at surface. Hold PJSM to discuss plan forward to resolve leak in pits. Have Vac truck on location to drain pits. We have pit liner to make a dike beneath pits to prevent spills while making repair. We have a man lift in route, and vent fans should confined space entry be required. The BHA will be stood back and the well secured while the welder makes repairs. Confined space entry may be needed to analyze leak or make repairs. Hazards of job and mitigations to hazards reviewed. Clean pits, build spill dyke under pits. Safety meeting prior to confined space entry into pits. Inspect pits for leaks. Narrow it down to pit #2 Crew change/safety mtg Remove skin below pit #2 using manlift and find leak in sump. Appears to be corrosion at lowest point. Rig welder make temporary repairs (will replace with new sump assy during rig move). Will leave outer skin and insulation off until final repairs are made DS grease and inspect injector Fill pits with mud. RD equipment MU drilling BHA. Upload res tool RIH w/ BHA #7 SHT 8150' Continue RIH. RIH thru window, clean. Precautionary ream to TD and tag at 9801' CTD. Corr to 9790' PVT 313 Log MAD pass up 2.6/2930/115L 120'/hr to 9570' and tie-in, add 1.0' RIH to TD and tag at 9790' Drill from 9790' 2.6/3000/97L to 9820' PVT 310 Attempt to orient and can't get a click. Go to window to get it. Have to red rate thru 9730-70' (low point in wellbore-solids bed) or SS tool shuts off in 39 deg DLS area Drill from 9820' 2.6/3000/75L to 9880' holding 95 deg and stacking Wiper to window while DS tech fix MM's and work on CT speed output Drill from 9880-9900' 2.7/3040/70L and see incl drop. Orient to 33L. Drill from 9900' PVT 295 (all mud loss is mostly from centrifuge, the rest from shaker). Drill to 9935' and have 95 deg at bit Orient around 9935', Resume drilling in shale. Free spin 3050 psi at 2.65 bpm. Pit vol=291 bbls. Drilling at 2.65/2.65/3300 psi. Take 1 click. Resume drilling. 9982', Pick up for 1 click to maintain 90L toolface and an inclination of 95 degrees. Resume drilling. 10011', Wiper trip to shoe. Resume drilling. Pit vol=282 bbls. Not getting very good weight transfer. Add 40 bbls of mud with i Hours I Task Code NPT 8/14/2003 02:30 - 03:30 1.00 DRILL N 03:30 - 04:15 0.75 DRILL N 04:15 - 04:40 0.42 DRILL N RREP PROD1 04:40 - 05:00 0.33 DRILL N RREP PROD1 05:00 - 06:00 1.00 DRILL N RREP PROD1 06:00 - 06:30 0.50 DRILL N RREP PROD1 06:30 - 08:30 2.00 DRILL N RREP PROD1 08:30 - 09:15 0.75 DRILL N RREP PROD1 09:15 - 10:00 0.75 DRILL N RREP PROD1 10:00 -11:15 1.25 DRILL N RREP PROD1 11:15 -11:40 0.42 DRILL P PROD1 11:40 - 13:40 2.00 DRILL P PROD1 13:40 - 13:50 0.17 DRILL P PROD1 13:50-14:15 0.42 DRILL P PROD1 14:15-15:00 0.75 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 16:40 0.67 DRILL P PROD1 16:40 - 17:55 1.25 DRILL P PROD1 17:55 - 18:30 0.58 DRILL P PROD1 18:30 - 18:35 0.08 DRILL P PROD1 18:35 - 18:50 0.25 DRILL P PROD1 18:50 - 19:30 0.67 DRILL P PROD1 19:30 - 19:40 0.17 DRILL P PROD1 19:40 - 20:00 0.33 DRILL P PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 23:00 2.50 DRILL P PROD1 23:00 - 23:15 0.25 DRILL P PROD1 Description of Operations -----------.------..... Printed: 8/2512003 9:10:00 AM ~ . BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: X-08 X-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/7/2003 8/18/2003 N1 Spud Date: 5/10/1980 End: 8/18/2003 Date From - To Hours ¡ Task Code NPT Phase Description of Operations .-.----.--.----.--- ----- ------------..-- 8/14/2003 23:00 - 23: 15 0.25 DRILL P PROD1 lubetex to bring concentration in system to 4% lubetex. 23:15 - 23:40 0.42 DRILL P PROD1 Continue drilling. Pit volume after adding mud=314 bbls. As soon as 5 bbls of new mud was out the bit ROP took off. 23:40 - 23:45 0.08 DRILL P PROD1 10115', Pick up for 1 click. 23:45 - 00:00 0.25 DRILL P PROD1 Resume drilling. 8/15/2003 00:00 - 00: 10 0.17 DRILL P PROD1 Drill ahead. 00:10 - 00:45 0.58 DRILL P PROD1 10165', Wiper trip to shoe. 00:45 - 01 :00 0.25 DRILL P PROD1 10180', Orient to 90L. 01 :00 - 02:05 1.08 DRILL P PROD1 Resume drilling. Pit volume=312 bbls. 02:05 - 02:15 0.17 DRILL P PROD1 10240', Orient to 120L to reduce build angle slightly. 02: 15 - 03:00 0.75 DRILL P PROD1 Resume drilling. Pit vol=306 bbls. 03:00 - 03: 15 0.25 DRILL P PROD1 10300', orient to 90R. 03: 15 - 03:30 0.25 DRILL P PROD1 Resume drilling. 03:30 - 04:10 0.67 DRILL P PROD1 10316', wiper trip to shoe. 04: 1 0 - 05:00 0.83 DRILL P PROD1 Resume drilling. Pit vol=295 bbls. 05:00 - 05:05 0.08 DRILL P PROD1 Orient 1 click. 05:05 - 06:00 0.92 DRILL P PROD1 Resume drilling. Pit level indicators are not working properly. Having the driller strap the pits by hand. 06:00 - 07:00 1.00 DRILL P PROD1 Drill from 10430' 2.6/3300/87R holding 92.5 deg to 10484' 07:00 - 07:25 0.42 DRILL P PROD1 Wiper to window 07:25 - 07:45 0.33 DRILL P PROD1 Log tie-in up from 9600' 2.7/3260/52R. Add 4.0' 07:45 - 08: 15 0.50 DRILL P PROD1 RIH, clean. Tag TD at 10486' 08:15 - 10:30 2.25 DRILL P PROD1 Drill from 10486' 2.7/3280/87R at 93 deg PVT 286. Drill to 10650' 10:30 - 11 :30 1.00 DRILL P PROD1 Wiper to window 11:30-12:00 0.50 DRILL P PROD1 Orient to left 12:00 - 13:50 1.83 DRILL P PROD1 Drill from 10650' 2.7/3460/83L at 93 deg to 10735' and find a hard spot PVT 269 Start losing 0.6 bpm. Work thru hard spot after 8 stalls 13:50 -14:05 0.25 DRILL P PROD1 Drill from 10735' 2.6/3300/83L at 93 deg and losses healed to 0.3 bpm. Drilled to 10747' and had stall and overpull PVT 253 14:05 - 14:15 0.17 DRILL P PROD1 Wiper to 10600' , clean 14:15 - 14:40 0.42 DRILL P PROD1 Drill from 10747' and losses stabilized at 0.5 bpm. Drill to 10760' and stacking-need fresh mud PVT 231 14:40 - 15:50 1.17 DRILL P PROD1 Wiper to window, clean. RIH, start new mud 15:50 - 17:45 1.92 DRILL P PROD1 Resume drilling from 10760' 2.6/2.1/3300/85L Fin add 128 bbls fresh mud PVT 315 Drill to 10848' and stacking PVT 279 17:45 - 18:30 0.75 DRILL P PROD1 Wiper to 10600' 18:30 - 18:45 0.25 DRILL P PROD1 10840', Drilling ahead with losses. Free spin 3300 @ 2.6 bpm. Drilling at 2.6/2.3/3500 psi. Pit vol=259 bbls. 1 truck of new mud on location. 18:45 - 19:00 0.25 DRILL P PROD1 10870', orient around to 80L. 19:00 - 19:40 0.67 DRILL P PROD1 Resume drilling. 19:40 - 20:30 0.83 DRILL P PROD1 10910', Wiper trip to shoe. Clean PU off bottom 20:30 - 20:40 0.17 DRILL P PROD1 Log tie in pass. Made a +2' correction. 20:40 - 21 :15 0.58 DRILL P PROD1 Run back in the hole to resume drilling. 21 :15 - 23:00 1.75 DRILL P PROD1 Resume drilling. 2.6/2.4/3700 psi. Pit vol=206 bbls. Loosing about 20 bbls/hr, or 0.3 bbl/min. This is consistent with what we are seeing on the MM. 23:00 - 00:00 1.00 DRILL P PROD1 11036', Wiper trip to shoe. Pit vol =165 bbls. 8/16/2003 00:00 - 00:20 0.33 DRILL P PROD1 Continue wiper trip to the shoe. 00:20 - 01 :25 1.08 DRILL P PROD1 11036', Back on bottom. Pit vol=138 bbls. 2.7/2.45/3710 psi. Difficult to get weight transfer to bottom. Time for a mud swap. Printed: 8/25/2003 9: 1 0:00 AM . . BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Name: X-08 Common Well Name: X-08 Spud Date: 5/10/1980 Event Name: REENTER+COMPLETE Start: 8/7/2003 End: 8/18/2003 Contractor Name: NORDIC CALISTA Rig Release: 8/18/2003 Rig Name: NORDIC 1 Rig Number: N1 From - To : Hours ¡Task I Code I Date NPT! Phase ! Description of Operations .-------- - 8/16/2003 00:20 - 01 :25 1.08 DRILL P PROD1 New mud on location. 01 :25 - 01 :45 0.33 DRILL P PROD1 11053', Orient to straight down. Mud swap in progress. 01 :45 - 02:20 0.58 DRILL P PROD1 Resume drlling. 02:20 - 02:40 0.33 DRILL P PROD1 11085', Orient to 90R. 02:40 - 03:00 0.33 DRILL P PROD1 Drill ahead. 03:00 - 03:15 0.25 DRILL P PROD1 11120', Losses jumped to about 1 bpm. Pumping 2.7, getting 1.6 back. 03:15 - 03:35 0.33 DRILL P PROD1 11127'. Orient to low side. 03:35 - 05:15 1.67 DRILL P PROD1 11146', Losses increasing. 2.6/1.0. Make a wiper trip to shoe to give cuttings entrained in mud column a chance to get circulated OOH. 05: 15 - 05:20 0.08 DRILL P PROD1 Resume drilling. 2.7/1.7/3700 psi. Pit vol=154 bbls. Vac truck loading with used mud at MI. 05:20 - 05:35 0.25 DRILL P PROD1 11157', Orient to 100R. 05:35 - 06: 15 0.67 DRILL P PROD1 Resume drilling. 1.6/1.6/3500 psi. Pit vol=137 bbls. Drill to 11185' 2.6/1.6/3200/154R and stacking max wt and overpulling 06: 15 - 07:00 0.75 DRILL P PROD1 Wiper to window. Start used mud 07:00 - 07:20 0.33 DRILL P PROD1 Backream 7" to remove solids 07:20 - 08:40 1.33 DRILL P PROD1 POOH to test BOPE and LD res tool 08:40 - 10:30 1.83 DRILL P PROD1 IA 540 LD drilling BHA-bit 1-1-1. Download resistivity tool IA 400 Fill hole w/ 9 bbls IA 530 10:30 - 16:30 6.00 BOPSURP PROD1 Weekly BOPE test. Witness waived by AOGCC 16:30 - 17:00 0.50 DRILL P PROD1 IA 220. Open swab-on vac. Fill hole w/14 bbls. IA 540 PVT 181 17:00 - 17:55 0.92 DRILL P PROD1 MU MWD drilling assy 17:55 - 19:45 1.83 DRILL P PROD1 RIH w/ BHA #8 SHT 19:45 - 20:10 0.42 DRILL P PROD1 Tie in at whipstock. IAP=1100 psi, OAP=217 psi. 2.6/1.5/3300 psi free spin. Still losing fluid at 1 + bpm. Pit vol now at 195 bbls, and a Vac truck of fresh mud is on the way. Zero correction made on tie in. (Even a blind hog finds an acorn now and then...) 20:10 - 20:50 0.67 DRILL P PROD1 RIH to resume drilling. 20:50 - 21 :20 0.50 DRILL P PROD1 Tag bottom, MAD pass missing GR data from dropping off RES tool. 21 :20 - 21 :45 0.42 DRILL P PROD1 Orient to 90R 21:45 - 22:35 0.83 DRILL P PROD1 11192', Begin drilling. TF=90R, Pit vol=109 bbls, ROP=115 fph. 2.6/1.8/3700 psi. 22:35 - 22:40 0.08 DRILL P PROD1 11255', Take a click. Pit vol=155 bbls. Taking on new mud into pits. 22:40 - 23:00 0.33 DRILL P PROD1 Resume drilling. 23:00 - 23:50 0.83 DRILL P PROD1 11270', Drilling ahead. Vac truck empty and round tripping. Pit vol=311 bbls. 2.6/1.7/3650 psi. TF=120R. 23:50 - 00:00 0.17 DRILL P PROD1 11352', wiper trip to shoe. Clean PU off bottom. Pit vol at start of trip=262 bbls. 8/17/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Continue wiper trip to shoe. 01 :30 - 02:00 0.50 DRILL P PROD1 Resume drilling. Pit vol=171 bbls, 2.6/1.75/3680 psi. 02:00 - 02:30 0.50 DRILL P PROD1 11400', Orient to 70R. Pit vol=143 bbls. 02:30 - 03:20 0.83 DRILL P PROD1 Resume drilling. 2.6/1.5/3640 psi. TF=73R, Pit vol=128 bbls. IAP=1090, OAP=220 psi. ROP=137 fph. 03:20 - 04:07 0.78 DRILL P PROD1 Pits topped off with new mud. Pit vol=337 bbls at 03:20 AM. 04:07 - 06:00 1.88 DRILL P PROD1 11550', Wiper trip to the shoe. Clean PU off bottom. Pit vol=288 bbls at 04:07 AM. Still losing at 1 bpm. Printed: 8/25/2003 9:10:00 AM ~ . BP EXPLORATION Operations Summary Report Page 9 of 10 Legal Well Name: X-08 Common Well Name: X-08 Spud Date: 5/10/1980 Event Name: REENTER+COMPLETE Start: 8/7/2003 End: 8/18/2003 Contractor Name: NORDIC CALISTA Rig Release: 8/18/2003 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task I Code NPT Phase Description of Operations ______..__.._n__ --------- -------- 8/17/2003 06:00 - 07:35 1.58 DRILL C PROD1 Drill from 11550' 2.6/1.6/3200/80R to 11700' temporary TD 07:35 - 08:50 1.25 DRILL P PROD1 Wiper to window 08:50 -10:15 1.42 DRILL P PROD1 POOH for resistivity Kick while tripping drill 10:15 -12:00 1.75 DRILL P PROD1 IA 500 Change BHA. Add resistivity tool IA230 Kick while change BHA drill 12:00 - 13:55 1.92 DRILL P PROD1 RIH w/ BHA #9 Took 14 bbls to fill hole SHT 13:55 - 14:15 0.33 DRILL P PROD1 Log tie-in up from 9605' 2.5/1.8/3000/29R Corr -15' 14:15 -15:20 1.08 DRILL P PROD1 Precautionary ream to TD tagged at 11691' three times. PUH 36k, clean 15:20 - 16:00 0.67 DRILL P PROD1 Log MAD pass up at 900'/hr 16:00 -17:00 1.00 DRILL P PROD1 Finish wiper to window 2.4/1.8/2900/167L No overpulls anywhere. Memory log RA marker since TD depth variance and larger than normal correction earlier 17:00 - 18:20 1.33 DRILL P PROD1 POOH for liner 18:20 -19:15 0.92 DRILL P PROD1 Tag up at surface. Stand back injector. Download RES tool. 19:15 - 20:00 0.75 DRILL P PROD1 Lay down remainder of drilling BHA. Bit recovered and graded a 0,0. 20:00 - 22:15 2.25 CASE N WAIT COMP Fax copy of logs to town. Wait on town geologist to confirm picks of liner in lower interval. 22: 15 - 00:00 1.75 CASE N WAIT COMP Rearrange intervals from what was initially given. Bring new pipe in, take old pipe out, re do liner tally. 8/18/2003 00:00 - 00:45 0.75 CASE N WAIT COMP Continue to resolve liner tally. 00:45-01:10 0.42 CASE P COMP Safety meeting prior to running liner. Well kept full by circulating over the top. Total losses to formation during waiting time was 27 bbls. 01:10-04:15 3.08 CASE P COMP Make up combination solid/slotted. STL and FL4S 2-7/8" x 3-3/16" liner as per proceedure. Intervals as per email from town geologist. 04:15 - 05:00 0.75 CASE P CaMP Make up CTLRT and injector. 05:00 - 06:00 1.00 CASE P COMP RIH with liner on coil tubing. 06:00 - 06:35 0.58 CASE P CaMP RIH thru window and open hole, clean. Lost E counter when in open hole 06:35 - 06:45 0.17 CASE P CaMP Tag TD at 8816' Mech or 11691' ELMD. Recip 40' at 44K and retag at same depth. PUH to ball drop. Load 5/8" steel ball. Set liner at TD 06:45 - 07:10 0.42 CASE P CaMP Circ ball to seat with mud 2.3/2.0/2140 and sheared at 3200 psi 07: 1 0 - 07:55 0.75 CASE P CaMP Release from liner and PUH 30k to 8750'. PVT 232 Start KCI 2.6/2.5/2100 07:55 - 09:00 1.08 CASE P COMP POOH fin displ to KCI 09:00 - 10:25 1.42 WHSUR P COMP Displace top 2000' of wellbore w/ MeOH 2.0/1.95/1200. POOH MIRU DS N2 10:25 - 10:45 0.33 CASE P COMP LD BOT CTLRT. SI swab and master 10:45 - 10:55 0.17 RIGD P POST Safety mtg re: N2 10:55 - 12:15 1.33 RIGD P POST Displace KCI in CT w/ N2 and bleed off 12:15 -14:00 1.75 RIGD P POST Cut off eTC. Prep injector to RD. Unstab CT Vac pits. Load trailers. Weld new sump in pit #2 14:00 - 16:30 2.50 RIGD P POST Rig released at 1400 hrs 8/18/2003 Remove gooseneck. Set injector in pipe bay 16:30 - 17:50 1.33 RIGD P POST ND BOPE. NU tree cap and PT to 3500 psi 17:50 - 18:30 0.67 RIGD P POST Crew change/TL mtg 18:30 - 19:45 1.25 RIGD P POST Continue rig down operations and preperations to move off well. Printed: 8/25/2003 9:10:00AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..., . Page 10 of 10 BP EXPLORATION Operations Summary Report X-08 X-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To : Hours Task I Code Start: 8/7/2003 Rig Release: 8/18/2003 Rig Number: N1 Ii, N PT: Phase Date 8/18/2003 19:45 - 20:10 20:10-21:00 21 :00 - 00:00 0.42 RIGD P 0.83 DEMOB P 3.00 DEMOB P POST POST POST Spud Date: 5/10/1980 End: 8/18/2003 Description of Operations ....___..._._..__.._m. Hold PJSM prior to moving the rig off of the well. Move rig off the well and position to install booster wheels and lay down wind wall and derrick. Prep cellar to install booster wheels. Remove mousehole and stairs in cellar. Begin to install boosters. Rest of rig down and prep work will be carried on first Telex for 15-28A. Printed: 8/25/2003 9: 1 0:00 AM Well: Field: API: Permit: Date . . 08/09/03 08/13/03 08/18/03 Nordic #1 09/02103 SET WEATHERFORD PATCH IN TWO RUNS. FIRST RUN: SET LOWER PACKER AT 8613'. CONFIRMED SET BY TAGGING. SECOND RUN: STING UPPER PATCH ASSEMBLY INTO LOWER ASSEMBLY. PULL UP TO VERIFY LATCH. SLACK OFF TO NEUTRAL WEIGHT & SET UPPER PACKER AT 8578'. PACKER SETTING DEPTHS ARE TAKEN FROM WA PL LOG DATED 30 APR 1996 & WERE CHOSEN TO AVOID SETTING ELEMENTSISLlPS AT LOCATION OF PREVIOUS PATCH OR IN COLLARS. X -08A Prudhoe Bay Unit 50-029-20463-01 203-117 Accept: Spud: Release: Rig: POST RIG WORK NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN. PATCH IN HOLE: MIN ID: 2.25". e AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . (~03 --II f 19-5ep-03 Re: Distribution of Survey Data for Well X-08A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,500.00 I MD 9,535.00' MD 11,691.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager Attachment(s) ~~~N\~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_ WOA X Pad X-DBA . Job No. AKMW0002600190, Surveyed: 17 August, 2003 Survey Report 18 September, 2003 Your Ref: API 500292046301 Surface Coordinates: 5939693.00 N, 665631.00 E (70014' 29.3706" N, 148039'44.2616" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 939693.00 N, 165631.00 E (Grid) Surface Coordinates relative to Structure Reference: 2254.74 N, 1012.98 E (True) Kelly Bushing: 73.48ft above Mean Sea Level Elevation relative to Project V Reference: 73.48ft Elevation relative to Structure Reference: 73.48ft Eii-n=1 '...,Y-EiUï! f1 A' L. L.fNG s IS A V' c::&S A Halliburton Company Survey Ref: svy4099 Sperry-Sun Drilling Services Survey Report for PBU_ WOA X Pad - X-OBA Your Ref: API 500292046301 Job No. AKMW0002600190, Surveyed: 17 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9500.00 16.670 132.310 8711.71 8785.19 1538.49 S 2497.04 E 5938209.74 N 668161.24 E 1068.34 Tie On Point MWD Magnetic 9535.00 16.330 132.370 8745.27 8818.75 1545.198 2504.39 E 5938203.21 N 668168.74 E 0.973 1070.18 Window Point 9562.60 19.210 118.930 8771.56 8845.04 1550.008 2511.24 E 5938198.55 N 668175.69 E 18.095 1072.75 . 9591.24 30.040 111.820 8797.56 8871.04 1554.96 8 2522.05 E 5938193.83 N 668186.61 E 39.140 1078.40 9622.72 42.110 107.140 8822.96 8896.44 1561.02 S 2539.52 E 5938188.15 N 668204.20 E 39.304 1088.70 9654.82 53.680 103.900 8844.45 8917.93 1567.32 S 2562.44 E 5938182.35 N 668227.26 E 36.804 1103.21 9684.60 64.580 99.230 8859.71 8933.19 1572.38 S 2587.44 E 5938177.85 N 668252.37 E 38.983 1120.14 9711.72 76.840 97.800 8868.66 8942.14 1576.158 2612.71 E 5938174.63 N 668277.71 E 45.478 1138.05 9738.60 86.080 98.170 8872.64 8946.12 1579.848 2639.01 E 5938171.52 N 668304.08 E 34.402 1156.83 9765.08 96.390 94.650 8872.07 8945.55 1582.798 2665.28 E 5938169.15 N 668330.41 E 41.135 1176.03 9801.27 95.240 86.720 8868.40 8941.88 1583.22 8 2701.25 E 5938169.51 N 668366.38 E 22.029 1204.50 9833.96 94.800 83.720 8865.54 8939.02 1580.51 8 2733.69 E 5938172.94 N 668398.76 E 9.240 1232.05 9865.27 93.570 79.490 8863.25 8936.73 1575.95 S 2764.58 E 5938178.17 N 668429.54 E 14.035 1259.46 9895.09 91.980 75.620 8861.81 8935.29 1569.53 S 2793.66 E 5938185.23 N 668458.47 E 14.016 1286.55 9927.90 95.770 73.330 8859.59 8933.07 1560.77 S 2825.19 E 5938194.68 N 668489.80 E 13.487 1317.00 9958.44 95.680 71.390 8856.55 8930.03 1551.57S 2854.15 E 5938204.52 N 668518.55 E 6.328 1345.67 9990.58 95.330 66.630 8853.46 8926.94 1540.118 2884.01 E 5938216.63 N 668548.15 E 14.782 1376.41 10026.10 94.980 62.750 8850.27 8923.75 1524.99 8 2915.98 E 5938232.45 N 668579.78 E 10.924 1411.05 10068.26 95.860 56.940 8846.28 8919.76 1503.91 8 2952.26 E 5938254.31 N 668615.59 E 13.877 1452.70 10103.66 93.660 51.300 8843.34 8916.82 1483.25 S 2980.83 E 5938275.61 N 668643.70 E 17.049 1487.95 10140.65 95.420 48.480 8840.41 8913.89 1459.49 S 3009.02 E 5938299.97 N 668671.37 E 8.966 1524.77 . 10172.15 97.530 44.430 8836.86 8910.34 1437.94 S 3031.71 E 5938322.02 N 668693.57 E 14.424 1555.86 10208.33 96.560 40.200 8832.42 8905.90 1411.39 S 3055.87 E 5938349.09 N 668717.15 E 11.909 1591.13 10239.33 96.920 37.380 8828.78 8902.26 1387.40 S 3075.16 E 5938373.50 N 668735.90 E 9.108 1620.97 10276.02 94.360 33.680 8825.18 8898.66 1357.69 S 3096.37 E 5938403.67 N 668756.45 E 12.222 1655.79 10321.10 92.780 31.040 8822.37 8895.85 1319.698 3120.45 E 5938442.19 N 668779.69 E 6.815 1697.89 10359.69 93.220 37.030 8820.35 8893.83 1287.77 S 3142.00 E 5938474.58 N 668800.54 E 15.543 1734.32 10402.47 93.040 41.610 8818.01 8891.49 1254.738 3169.06 E 5938508.20 N 668826.87 E 10.698 1775.81 10431.58 92.600 46.190 8816.58 8890.06 1233.798 3189.22 E 5938529.58 N 668846.56 E 15.787 1804.51 10462.31 92.950 47.780 8815.09 8888.57 1212.858 3211.66 E 5938551.01 N 668868.53 E 5.292 1835.04 1B September, 2003 - 10:44 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_ WOA X Pad· X-08A Your Ref: API 500292046301 Job No. AKMW0002600190, Surveyed: 17 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10494.25 93.570 51.120 8813.27 8886.75 1192.12 S 3235.89 E 5938572.26 N 668892.30 E 10.619 1866.86 10524.58 93.040 53.590 8811.52 8885.00 1173.63 S 3259.86 E 5938591.28 N 668915.86 E 8.316 1897.13 10552.73 92.600 57.290 8810.14 8883.62 1157.688 3283.01 E 5938607.73 N 668938.66 E 13.221 1925.22 10581.30 93.040 60.640 8808.73 8882.21 1142.978 3307.46 E 5938622.97 N 668962.77 E 11 .812 1953.60 . 10610.50 93.040 63.630 8807.18 8880.66 1129.358 3333.23 E 5938637.16 N 668988.24 E 10.225 1982.38 10643.99 92.950 70.330 8805.43 8878.91 1116.28 S 3364.00 E 5938650.91 N 669018.71 E 19.980 2014.82 10680.33 92.510 66.630 8803.70 8877.18 1102.96S 3397.76 E 5938664.96 N 669052.17 E 10.242 2049.79 10713.46 92.950 63.110 8802.12 8875.60 1088.91 8 3427.72 E 5938679.66 N 669081.81 E 10.696 2082.17 10742.62 93.040 59.050 8800.60 8874.08 1074.83 S 3453.20 E 5938694.30 N 669106.98 E 13.908 2111.00 10774.38 92.600 54.120 8799.03 8872.51 1057.37 S 3479.67 E 5938712.34 N 669133.06 E 15.566 2142.65 10799.69 92.780 53.590 8797.85 8871.33 1042.46 S 3500.08 E 5938727.70 N 669153.14 E 2.209 2167.93 10832.77 93.040 46.890 8796.16 8869.64 1021.348 3525.47 E 5938749.37 N 669178.06 E 20.243 2200.91 10865.34 95.420 45.480 8793.76 8867.24 998.85 S 3548.90 E 5938772.36 N 669200.99 E 8.487 2233.15 10903.50 96.740 41 .430 8789.72 8863.20 971.32 S 3575.00 E 5938800.47 N 669226.47 E 11.106 2270.57 10936.78 97.000 37.030 8785.74 8859.22 945.73 S 3595.89 E 5938826.51 N 669246.80 E 13.149 2302.65 10968.08 97.360 33.500 8781.82 8855.30 920.38 S 3613.81 E 5938852.25 N 669264.16 E 11.248 2332.22 11008.98 96.390 28.740 8776.92 8850.40 885.63 S 3634.79 E 5938887.45 N 669284.37 E 11.795 2369.89 11079.64 92.250 20.820 8771.59 8845.07 821.71 8 3664.28 E 5938951.99 N 669312.45 E 12.617 2431.91 11114.25 93.040 25.220 8770.00 8843.48 789.90 S 3677.80 E 5938984.10 N 669325.27 E 12.903 2461.85 11153.54 89.340 27.690 8769.18 8842.66 754.74 S 3695.29 E 5939019.63 N 669341.99 E 11.321 2496.98 11198.97 88.280 33.850 8770.12 8843.60 715.738 3718.52 E 5939059.14 N 669364.35 E 13.756 2539.00 . 11242.32 89.430 37.730 8770.99 8844.47 680.59 8 3743.86 E 5939094.84 N 669388.91 E 9.333 2580.39 11278.84 88.280 40.900 8771.72 8845.20 652.34 8 3766.99 E 5939123.58 N 669411.41 E 9.232 2615.86 11316.21 85.370 39.670 8773.79 8847.27 623.88 S 3791.11 E 5939152.57 N 669434.91 E 8.452 2652.26 11346.48 81.850 42.140 8777.16 8850.64 601.15 S 3810.81 E 5939175.73 N 669454.09 E 14.176 2681.66 11380.16 78.500 45.310 8782.91 8856.39 577.17 S 3833.73 E 5939200.20 N 669476.49 E 13.598 2714.41 11416.55 76.650 45.660 8790.74 8864.22 552.268 3859.07 E 5939225.67 N 669501.28 E 5.170 2749.64 11445.69 77.530 48.660 8797.25 8870.73 532.95 S 3879.90 E 5939245.43 N 669521.67 E 10.479 2777.89 11472.69 78.410 52.360 8802.88 8876.36 516.168 3900.27 E 5939262.66 N 669541.67 E 13.793 2804.27 11509.37 80.440 55.350 8809.61 8883.09 494.90 S 3929.39 E 5939284.56 N 669570.31 E 9.738 2840.31 11550.97 82.470 58.520 8815.79 8889.27 472.46 8 3963.86 E 5939307.75 N 669604.28 E 8.977 2881.35 11583.50 83.260 61.700 8819.83 8893.31 456.38 S 3991.84 E 5939324.44 N 669631.90 E 9.999 2913.37 11618.58 83.520 63.630 8823.87 8897.35 440.38 S 4022.80 E 5939341 .12 N 669662.50 E 5.515 2947.72 11659.02 85.020 68.390 8827.91 8901.39 424.02 8 4059.55 E 5939358.27 N 669698.88 E 12.285 2986.91 11691.00 85.020 68.390 8830.69 8904.17 412.298 4089.17 E 5939370.66 N 669728.24 E 0.000 3017.63 Projected 8urvey 18 September, 2003·10:44 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_ WOA X Pad - X-OBA Your Ref: API 500292046301 Job No. AKMW0002600190, Surveyed: 17 August, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 53.000° (True). Magnetic Declination at Surface is 25.748°(11-Aug-03) . Based upon Minimum Curvature type calculations, at a Measured Depth of 11691.00ft., The Bottom Hole Displacement is 4109.90ft., in the Direction of 95.757° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9500.00 9535.00 11691.00 8785.19 8818.75 8904.17 1538.49 S 1545.19 S 412.29 S 2497.04 E 2504.39 E 4089.17 E Tie On Point Window Point Projected Survey Survey tool program for X-DBA From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) . Survey Tool Description 0.00 9500.00 0.00 8785.19 9500.00 11691.00 8785.19 BP High Accuracy Gyro (X-08) 8904.17 MWD Magnetic (X-08A) 1B September, 2003 - 10:44 Page 4 of 4 DrillQuest 3.03.02.005 ~ STATE OF ALASKA , ALASKA ÒIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 ~GA- ,i/~#l.OOl ~.. ( l!J$í93 1. Type of Request: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate o Plug Perforations 0 Stimulate o Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service o Variance o Time Extension Name & API Ext Change o Annular Disposal 5. Permit To Drill Number 203-117 6. API Number: 50- 029-20463-01 IS! Other 99519-6612 KBE = 73.8' 9. Well Name and Number: PBU X-08A 8. Property Designation: ADL 028313 10. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth MD (ft): Total Depth rvD (ft): Effective Depth MD (ft): Effective Depth rvD (ft): Plugs (measured): Junk (measured): 9400' 8690' 9400' 8690' 9400' N/A Structural . Conductor 110' 20" x 30" 110' 110' Surface 2678' 13-3/8" 2678' 2678' 4930 2670 Intermediate 9347' 9-5/8" 9347' 8640' 8150 5080 Production Liner 1472' 7" 8859' - 10331' 8185' - 9590' 8160 7020 Perforation Depth MD (ft): I Perforation Depth rvD (ft): I Tubing Size: None NIA 4-1/2", 12.6# Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'SAB-3' packer 8798'; 4-1/2" Otis SSSV Nipple Tubing Grade: L-80 Packers and SSSV MD (ft): 8798' 2117' Tubing MD (ft): 8907' 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 12, 2003 181 Oil 0 Gas 16. Verbal Approval: Date: 8/12/2003 0 WAG 0 GINJ Commission Representative: Winton Aubert Iv.f.- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mark JOhnso~n Title CT Drilling Engineer Signature ~ O. ~ Phone 564-5666 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 13. Well Class after proposed work: o Exploratory 181 Development 0 Service o Plugged DWINJ o Abandoned o WDSPL Contact Mark Johnson, 564-5666 Date iJ2-~ J I Sundry Number:3:t5, ;;{35 Prepared By Name/Number: Terrie Hubble, 564-4628 Subsequent form required 10- hi 0 7 ~ -I-L ~/~:Þ~. Appro,ed By,' /V,..-.L" ~ "'Î. . COMMISSIONER Frn-m '0403 Re'~ed 21200) 0 RIG I N A ... 1 A .~.~ BY ORDER OF THE COMMISSION RECEIVE :> AUG 1 4 2003 4/ðSKa IJlI t\ Gas r'A~ A \,/UIIS. Comm;..;.. '4f1Chorage '-.ur Dare sf ~~te o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: ø e August 10, 2003 To: Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Attention: Winton Aubert Petroleum Engineer Subject: Well name change to PBU X-08A from X-08Ll (permit 203-117) bp BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Well name X -08 L 1 in drilling permit #203-117 needs to be changed to X -08A since the parent wellbore was abandoned with cement on 8/12/03 (P&A sundry submitted). No other changes to the drilling permit are necessary. ~ O.Q~ Mark O. Johnson 564-~ 240-8034 cell CT Drilling Engineer ¡:;;-::¡ . lID t !Æ ~!Æ~ ~~!Æ . AI,ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR ...i 333 W. JT" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit X-08L1 BP Exploration (Alaska), Inc. Permit No: 203-117 Surface Location: 430' SNL, 264' WEL, Sec. 07, TlON, R14E, UM Bottomhole Location: 868' SNL, 3705' EWL, Sec. 08, TlON, R14E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits 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 terms and conditions of this permit 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, ~~~ Commissioner BY ORDER OF THE COMMISSION DATED this 'lS day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~tVc:'A- {,/'L'i>/z..oO! 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 665631, Y = 5939693 430' SNL, 264' WEL, SEC. 07, T10N, R14E, UM At top of productive interval x = 668164, Y = 5938207 1973' SNL, 2231' EWL, SEC. 08, T10N, R14E, UM At total depth x = 669609. Y = 5939344 868' SNL, 3705' EWL, SEC. 08, T10N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well / ADL 028312, 1575' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9525' MD Maximum Hole Angle 18. Casing Program S ·f· t'o Size pecl Ica I ns Hole Casina Weiaht Grade Couclina Lenath 3-3I4"x4-1/S" 3-3I16"x2-7/S" 6.2#/6.16# L-80 TCIII STL, 2710' _ STATE OF ALASKA ALASKA <:.WAND GAS CONSERVATION COMMI&N PERMIT TO DRILL 20 MC 25.005 11 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 73.8' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028313 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / X-08L 1 9. Approximate spud date 07/08/03 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 r¡ 1570' MD I 8854' TVDss 17. Anticipated pres~e {see 20 AAC 25.035 (e) (2)} 940 Maximum surface 2387 psig, At total depth (TVD) 8800' I 3267 psig Setting Depth Top Bottom MD TVD MD TVD 8860' 8112' 11570' 8854' / 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include staae data) Uncemented Slotted Liner -- 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10331 feet 9590 feet 10286 feet 9546 feet Length Plugs (measured) IBP Set at 9760' (09/90) Junk (measured) J~JN .2 4: lOD3 Detonated Perf Gun at approximately 10186' Size Cemented TVD 110' 20" x 30" 2678' 13-3/8" 9347' 9-518" 1472' 7" 8.5 cu yds Concrete 3913 cu ft Permafrost II 1310 cu ft Class 'G', 130 cu ft PF 'C' 110' 2678' 9347' 110' 2678' 8640' 366 cu ft Class 'G' 8859' - 10331' 8185' - 9590' Perforation depth: measured 9513' - 9535', 9616' - 9650', 9664' - 9679', 9679' - 9689', 9689' - 9700', 9700' - 9750' true vertical 8798' - 8819', 8897' - 8929', 8943' - 8957', 8957' - 8967', 8967' - 8978', 8978' - 9026' 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch III Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report III 20 AAC 25.050 Requirements Contact Engineer NamelNumber: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the foregoing is true$'1correct to the best of my kn~~ledge . ~ / ! Signed Mark Johnson ~ O. ~ Title CT Drilling Engineer Date lo¡ Z 1 . . ó .:'? '. .;--::; ..... ·.·.·':.·c:qmmiSSiop;*.on.ý'· ..':: .. ,.,' .... Permit Number . ? 1 API Nurubér" ... I ~p~- val.98te I See cover letter Z. 03 - / / 50- 029-20463-60 (p U ( ~ for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes JJa No Hydrogen Sulfide Measures BYes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPED 2K D3K D4K D5K D10K D15K 0 3.5K psi for CTU Other:T'è..-sf;. ßoPE ~.~S"o, 'i'.1He'. '~IS For"^- ~o·4o~ to ~~~ ~"stt"'fl tUýW'~~. ~""'1iF""----P e.~ V'~r.v.,r-<- by order of J . I '~ ApprqVl\1~Y a_ (? ~""ß.. ..... ¿--. ~ Commlssione, A [the commission Date II 2.{/ ~ Form ~~i~1-85 ID'n 4 I ... j . ~ u R , G \ N SJ;mit In ripl~te It e BP x-os Ll Sidetrack Summary of Operations: Well X-~ is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on ~7/8/03. The lateral addition, X-08 Ll, will exit.9tlt..efthe existing 7" liner from a through tubing whipstock and target Zone 4 reserves ("When the well is on production, the existing parent wellbore perforations will / continue to be produced through an inflatable packer check valve supplementing production from the new lateral leg. The following describes the planned sidetrack (lateral addition). A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (phase 1) / 1) Slickline -Drift and caliper tubing. Set plug in tubing tail and perform combination test of tubing, IA and OA to 2400 psi. Pull plug. Retrieve tubing patch. Retrieve reducing nipple. Drift tubing and tag bottom. Dummy gas lift valves. Caliper 7" liner. 2) CT - mill XN nipple in tubing tail to 3.80" ID. ./ 3) EL - Set inflatable bridge plug with check valves at 9570' md. Set whipstock at 9525' md. / CTD Sidetrack Summary (phase 2) 1) MIRV CTD rig. 2) Mill 3.8" OD window at 9525' md./ . 3) Drill 3.75 x 4 118" bicenter openhole sidetrack to ~ 11569' TD with MWD/gamma ray/resistivity. / 4) Base case - Run 27/8 x 33/16" pre-drilled liner (slotted liner) completion. Top ofliner will be at -8860' md in 4 Y2" tubing tail. Contin2encv - If crossing a fault expected at 10185' MD results in incurable mud losses, the completion would change to a bonzai cemented/slotted liner to isolate the fault. This would pla7 cement inside the parent wellbore and essentially abandon the parent wellbore perforations. 5) Run liner top packer if necessary. 6) RDMO. Mud Program: · Phase 1: 8.4 ppg seawater · Phase 2: 8.5 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. Drill with seawater if losses to / fault are incurable. 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: / Base case - Run 27/8 x 33/16" pre-drilled liner (slotted liner) completion. Top ofliner will be at ~8860' md in 4 Yz" tubing tail. Contin2encv - If crossing a fault expected at 10185' MD results in incurable mud losses, the completion would change to a bonzai cemented/slotted liner to isolate the fault. This would place cement inside the parent wellbore and essentially abandon the parent wellbore perforations. / 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. / e e Directional · See attached directional plan. Max. planned hole angle is 94 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray log will be ron over all of the open hole section. Resistivity log is optional. · A GRlCCL cased hole tie in log is optional after the liner has been run. Hazards ;: /) · PBU X pad is a H2S pad. Maximum recorded H2S wa~pm from well X-21. X-08 H2S was measured at 30 ppm on 4/8/03. All H2S monitoring equipment will be operational. · One small fault crossing is anticipated at 10185' md. Lost cirClÙation risk is considered "medium" so LCM material will be on location as a contingency. Reservoir Pressure · Res. press. is estimated,be 3267 psi at 8800'ss (7.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2387 psi. MOJ 6/20/03 SAFETY NOTES: 35' OF AVA PATCH SET OVER GLM#1, ID = 2.441" TREE = WaLHEAD = ACTUATOR = ^ _~~_w~'mmw_w"'.ww,'·__, KB. aEV = BF. aEV = U·.~_NA·..,~=.~,...W·',_W~-,_VA"-_V^=_·~ KOP= Max Angle = w"'~·w^,···,··m.··_·___·_,_'______·N^wN"'''',',·,',w"" Datum MD = Datum lVD = 6" CWV MCEVOY OTIS 73.48' 40.03' 3100' 32 @ 6600' y ,,," '0" W','^'^"~~'~'V_WN'_" 9592' 8800' SS e ~5flll~ e /' x-os 2117' H4-1/2"OTlSSSSVNIP.ID=3.813" I . 2609' H 9-5/8" DV A<R I -~ - ~ GAS LIFT MANDRELS ST MD lVD DEV 1YÆ VLV LATCH SIZE DATE 5 2972 2897 8 OTIS 1-1/2" RA 4 5170 4900 31 OTIS 1-1/2" RA 3 7567 6947 28 OTIS 1-1/2" RA 2 8366 7661 26 OTIS 1-1/2" RA 1* 8598 7872 24 OTIS 1-1/2" RA 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2678' ~ L Minimum ID = 2.313" @ 8876' 2-7/8" REDUCING X NIPPLE * 35' AVA PATCH 8591' HAVA PATCH @ #1 GLM STATION.ID= 2.441" I I I . . I g Z--I . I i -. .- I : I I HOTlS SLIDING SLEEVE, [) = 3.813" 8712' HTBG SEAL ASSY I H9-5/8" x 4-112" BKR SAB-3 A<R, ID = 3.813" H4-1/2" OTIS X NIP, [) = 3.813" I H4-1/2" OTIS XN NIP, [) = 3.725"1 t-2-7/8" REDUCING NIP. ID = 2.313" H4-1/2" TBG TAIL [) = 3.958" I rl aMD TT LOGGED 03/30/96 I 8775' 8798' 8844' 8875' 8876' 8907' 8892' I TOP OF 7" LNR H 8859' I 4-112" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 8907' .41 ~ I 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 9347' 9602' H MARKER JOINT I ÆRFORA TION SUMMARY REF LOG: BHCS ON OS/23/80 ANGLEATTOPÆRF: 17 @ 9513' Note: Refer to Production DB for historical perf data SIZE SPF MERV AL Opn/Sqz DA TE 3-3/8" 6 9513 - 9535' 0 05117/96 3-3/8" 18 9616 - 9650' 0 05/17/96 3-3/8" 14 9664 - 9679' 0 05/17/96 3-3/8" 12 9679 - 9689' 0 05/17/96 3-3/8" 14 9689 - 9700' 0 05/17/96 3-3/8" 6 9700 - 9750' 0 05/17/96 9760' 1~3" BAKER IBP- 09/15/90 I 10186' HÆRFGUN"DETONATBY'I -, ~ I PBTD H 10286' 7" lNR. 29#, L-80, 0.0371 bpf,lD = 6.184" H 10331' PRUDHOE BA Y UNIT WaL: X-OS PERMIT No: 180-0360 API No: 50-029-20463-00 Sec. 7, T10N, R14E BP Exploration (Alaska) DATE REV BY COMMENTS 05131/80 ORIGINAL COMPlETION 02121101 SIS-QAA CONVERTED TO CANVAS 02126101 SIS-LG FINAL 06123101 RN/TP CORRECTIONS COMMENTS DATE REV BY TREE<= WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = 6" erN MCEVOY OTIS 73.48' 40.03' 3100' 32 @6600' 9592' 8800' SS .08L 1 Proposed Completion -- SAFElY NOTES: 35' OF AVA PATCH SETOVERGLM#1, D=2.441" ~()fOSED r---J 13-3/8" CSG, 72#, L-80, I) = 12.347" H 2678' Minimum ID = 2.313" @ 8876' 2-7/8" REDUCING X NIPPLE AVA Patch and reducing nipple must be removed prior to the sidetrack. Top of 3 3/16" liner approx. 8860' MD I TOP OF 7" LNR H 8859' I . L I -~ ~ t " ~ ~ I I I - ~H ~~ I 1- -~ I I I g , I 9-518" CSG, 47#, L-80, Ð = 8.681" H H 8907' I 9347' 1_ ~ ëD ..- J-- ('I') ('I') 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, Ð = 3.958" Top proposed whipstock 9525 ~ ,S1f6 /CoP 1'- ìr-e-t....t,;..,.. 1* " ~ ÆRFORA roN SUMMARY REF LOG: BHCS ON OS/23/80 ANGLEATTOPÆRF: 17@9513' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OpnlSqz DA 1E 3-3/8" 6 9513 - 9535' 0 05/17196 3-3/8" 18 9616 - 9650' 0 05117196 3-3/8" 14 9664 - 9679' 0 05/17/96 3-3/8" 12 9679 - 9689' 0 05/17/96 3-318" 14 9689 - 9700' 0 05/17/96 3-3/8" 6 9700 - 9750' 0 05/17/96 I PBTD H 10286' 7" LNR. 29#, L-80. 0.0371 bpf. I) = 6.184" H 10331' DA 1E REV BY COMMENTS 05131/80 ORIGINAL COMR..ETION 02/21101 SIS-QAA CONVERTED TO CANVAS 02/26/01 SIS-LG FINAL 06123101 RNITP CORRECTIONS DA 1E REV BY ~ 2117' H4-1/2" OTIS SSSV NIP, Ð = 3.813" I 2609' H9-5/8" DV A<R GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH SIZE DA1E 5 2972 2897 8 OTIS 1-1/2" RA 4 5170 4900 31 OTIS 1-1/2" RA 3 7567 6947 28 OTIS 1-1/2" RA 2 8366 7661 26 OTIS 1-1/2" RA 1* 8598 7872 24 OTIS 1-1/2" RA * 35' AVA PATCH 8591' HAVA PATCH@ #1 GLM STAroN, 10= 2.441" 8712' HOTlS SLIDNG SLEEVE, ID = 3.813" 8175' HTBG SEAL ASSY I 8798' H9-5/8" x 4-112" BKRSAB-3 PKR ID = 3.813" H4-1/2" OTIS X NIP, ID = 3.813" I H4-1/2" OTIS XN NIP, ID = 3.725"1 t-12-7/8" REDUCING NIP, ID = 2.313" H4-1/2" TBG TAIL 10 = 3.958" I t-I ELMD TT LOGGED 03/30/96 I 8844' 8875' 8876' 890T 8892' Uncemented slotted liner with Banzai contingency 2718" g == - == _ ~ ßt?s£ cAse ; IIi/... §LarT7Ø.) ¿INO( úf"l/lt£TIðN 9602' H MARKER JOINT I ~ Standing Valve on Inflatable Packer / s allo"> J( J .flo"> ,,0 flo'" Jo.#' -, ~ COMMENTS 9760' H3" BAKER IBP- 09/15/90 I 10186' HÆRFGUN"DETONATED" 1 PRUDHOE BAY UNIT WB.L: X-08 PERMIT No: 180-0360 API No: 50-029-20463-00 Sec. 7, T10N, R14E 8P Exploration (Alaska) Created By: Sri¡ Þotnis Azimuths to True North Magnetic North: 25.80' Magnetic Field Stre~th: 57542nT D~at~~;gg68; Model: BGGM2002 T AM ¿ LEGENO Xo08 (x.oo Pl8mu X-08A Plan" - ~!¡, ~,i ',::.; ª~!!i¡ , , '.] , ',; '" Bi. B_ Obp e Direct 1907) 267·6613 Baker Hughes ~i-~~g: {btdj)j~~ö~eQ com ~~_¡______..;_n'_ ..~:-._1~__ --¡----~~_____4 --.--t ,n H~~ --~--I , II! , i ! I i -+-=~=t=~Þ-d-j. ---~---+--~~-l.· --L I I I I I I r ! I ! I illl;$1. i 1 ¡-~--+ ¡ I PIan#4 X-~OA I--j--'_ '---1--+. u__ ' I .. I ! :: ! ! ¡ ! 1 : -t-- I , I 1 '-"r-' .-+- -----r-1 ·1----iU-r'¡--r-r I I I I ' 1 I '. ,I I i I I I I I I I , I I I ¡I' I +-1 I Wç . t:.:..-:--i=-+-+-I-- i---r- -.--+-+-- ~--+-t,-+--¡- i i I i I I I I f ¡-_} i i i I I i 4= ---~ 1~=Trr+t=~-i= ¡ I i·j I II - I I I I--t~~--I I It i ! I I I I I I , I III I I I I I I I I t·· _n I I ---~ I f . J·'·-I 1····1···/·· I .1 I 1 IIII 1111 IIII 1III 1111,1111 !ill IIIIIIII1 !l1,lli, liiilll! III , III "i Ii 28002900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 West(-)/East(+) [100ft/In] I i11 4500 t- I -·--1 I I i I I I I í ' I I i , : I . I I ! . I~" t------ I I I· --t--+ II I ¡ , I I I Î , I ; ¡"'; ¡-~; ; I 'I I I I I 1 I I I 2200 2300 2400 2500 2600 2700 INTEQ -200 J--+--~-t-+-- j I i I : -300+-1 I I I .., !] I -400 ;.+ I --.j--- 1 ! I -500 ~ I-~--I -600::! I -In I - I ! I I -700 -1900 ¡III II 19002000 'C' ~ -800 o =- 'P-900_ .... - - - + -1000 _un :ë -......... t: -1100 ........... o 1-1200 . 1-1300 o rn -1400 500 -1600 700 .80 vs.c T...... '0I&.~1 1oee.e2 "'.... tNa.n 1122.:17 117"" .-.., =:::: ....... ....... ITSOA. .-.. -t-+---l I . ---- --. ..~ e i I -t ' I 'I I 'I ' I I ---!! ¡- .nt' --'.!--.::.: I.::...,j.."j.:.nnt! .nJ I I I- I --1=---1--1- I ---: I ! -w·!---f--f---I-!-+-I---l. --1--+. - r" I.. 1 I I . I I i I.~L I, PI.~X-.' PI.~x-0:RA ... i -.. I I ! I· I l nJ--l:l· ... m I r-¡ -r- I ! , ! I I I i l j Ii! II I' J ¡ ¡ I I I! I I I I I I I I- I I I ! ! ! I "¡ ¡Ii i ¡ r!--i-....:J---~:-.:.l::.-n-I.::.----L·I Ii . .1. . J. f.,... j. I . 2400 2450 2500 2550 2600 2650 27'00 2750 2800 2850 2000 2950 11:17.å.M 6/10/2003 I r I 2350 I I I I ,l ì 2300 1---+-·---1 _I· I ....:.--¡::...---·--r-~ .:.. I I I I I I ..,j' 1 I . I .¡ill¡ I I· 11 I i i-('I ·1 I I I I I I I I' I i I ¡ 1·1 I -I ··1 I l· (n ! I·· I 'I· I . i .j .. ·1 ·1·· I I - I ! . ...., ·1 . .-.-- - .. .. . . I ' " I l I I I !~n!! I rl,:"I" I,,J ,., ,I, ,I,,: , 1650 1700 1750 1800 1850 HieO 1950 2000 2050 2100 2150 2200 2250 Vertical Section at 53.00' [50ft/In] j ttl +--+--1 I I P'I I I I ' I ,. I Iii " , II i , I '. ·:1 ¡- I I I· I I ! . ~ ¡ . ! 1400 1450 1500 1550 1600 TARGET DETAIl TVD ·NI-3 .... 82:. =··---i-·-- - i·· ·t' 8300 ~- -_~'---r.--1c-. - ::. 8350 =-- - -- ----.--.-" 8400-=--- - ....: I C8450- -I I ~ = . I .' II) 8500 . I i8550 ;--.:. -1-------+-- e8600=1 .j ICI = I , 1865~ l----t~---i- i 8700 ~~ . I . ·-----+·--:-f- > = , ¡I e875cr:---- -----,- t ~88~ __I ! 8650. I - I I 8900 _ I = -'1 8950_ II ~·I ~I--_- i 9000 .....,L , . .! ," , 1050 1100 1150 1200 1250 1300 ....NOTATION. TVD MO........ '711.J' ....... TIP .7U.I. 111IM KGI' '711.&' ..a... J .....11 "..... . IMU. "HIt... . ..11.., ..Int... I "OJ", ......... ., 1117... U...... . "IS.n U...... TO BP Amoco .."'.....TH MT'AlUi -........ ...212N1H1 '-',.:--'t.-&: =... 1Ifo· Ref. ..... .... "".,..tIOlt1OI n.lOft v.a.::: : = ::...~ IS...· .... .... '.10 REFERENCE INFORMATION Co-ordtnate ~! R.ference: Wen Centre: X-08. True North v::n (VS =:=:: =~~ ~~~~~o5é)' MellSUted DepIh Refenonce, 9: 08511011980 00:00 73 Calculation Method: Minimum Curvature .1IC'nOtf.1IT..... ... _ 1M &It T¥'t ..,. ...... ft... no._ t ....... t...,. nUt a?U.. ot..... ....... ..00 0.00 · H..... tLG tu.M .,... ot~ :HOa.at .... nOon ! =1 IE 1= as ::= IE: At!! !it.! 1 .,.._... ..... .....t. ·tl'N.O. ......t _a 3H.H , t........sa ....., MG.H .t~ ..t..17 ta.oo t'7O... · 1...... __ Þ.t. HI7.a .t..... ICIID.A tl.OO 170.... · t........_ 't... ....... ot...... uau tl.OO ... t.1t......... ...n ,",.eo .'.0.12 IIn.tl '2.00 :lTt." it tt...... IL,. ... ..,.a .-.... ,,'..n '2.10 US-at t2U........... ..... .....,. ~ .3t... tt..... H'.U n u........ ß.U MAG ..øt.at 1170.01 ta.u U.... I , I ! : I 350 Company: Field: Site: WeD: WeUpatb: BP Baker Hughes INTEQ Planning Report ObP e BP Amoco Prudhoe Bay PB X Pad X-08 Plan#4 X-OBA e .it. ..... INTEQ Date: .611012003 Time: 11:18:03 Page: 1 Co-OntIDatC(N;E).ReI'ereace: Well: X-Q8, True North Vertlc:al(TVl»ReI'erence: System:.Mean Sea Level Section(VS) Reference: Well (0.ooN,O.ooE,53.ooAzi) Survey Cakuiation 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 Modei: Site: PB X Pad TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5937417.97 ft 664667.65 ft Latitude: 70 14 Longitude: 148 40 North Reference: Grid Convergence: Alaska, Zone 4 Well Centre BGGM2oo2 7.207 N 13.706 W True 1.25 deg WeD: X-08 Slot Name: 08 X-08 Well Position: +N/-S 2253.59 ft Northing: 5939692.98 ft Latitude: 70 14 29.370 N +E!-W 1012.87 ft Easting : 665631.00 ft Longitude: 148 39 44.262 W Position Uncertainty: 0.00 ft Wellpatb: PIan#4 X-OBA 500292046301 Current Datum: 9: 08 5/10/1980 00:00 Magnetic Data: 6/10/2003 Field Strength: 57542 nT Verticai Section: Depth From (fVO) ft 0.00 Targets Annotation MD ft 9500.00 9525.00 9543.00 9749.50 10029.50 10269.50 10669.50 11089.50 11569.50 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E!-W ft 0.00 Height 73.80 ft +N/-S ft 0.00 Name Map .Map . Noa1hing EastiDg Description . TVD Dip. Dir. 1M) ft 8711.39 8735.35 8752.53 8860.15 8842.25 8827.43 8802.59 8777.90 8853.63 TIP KOP 3 4 5 6 7 8 TO Plan: Plan #4 Similar to Ted's Case204 Principal: Yes Date Composed: Version: Tied-to: Plan Section Information X-08 9500.00 ft Mean Sea Level 25.80 deg 80.79 deg Direction deg 53.00 <- Latltøde.--> <- Longitude -> Deg Min See Deg Min See 6/10/2003 2 From: Definitive Path MD lad Azim TVD +NI-S +EI-W DI;ß. ..... ·"BuUdJ< ·.·TUrn TFO Target ft deg deg ft ft ft dé9l100ft degl100ft dé9l100ft deg 9500.00 16.67 132.31 8711.39 -1538.42 2496.95 0.00 0.00 0.00 0.00 9525.00 16.43 132.36 8735.35 -1543.22 2502.21 0.96 -0.96 0.20 176.63 9543.00 1B.23 132.31 8752.53 -1546.83 2506.1B 10.00 10.00 -0.28 359.50 9611.83 43.51 110.23 8811.30 -1562.57 2536.96 39.70 36.73 -32.08 325.68 9680.67 68.60 96.82 8849.55 -1574.80 2592.06 39.74 36.45 -19.48 331.97 9749.50 93.59 85.68 8860.15 -1576.05 2659.41 39.62 36.31 -16.18 335.11 10029.50 93.53 52.01 8842.25 -1476.64 2916.27 12.00 -0.02 -12.02 270.98 10269.50 93.40 23.16 8827.43 -1288.82 3060.83 12.00 -0.05 -12.02 270.64 Obp e BP e ... ..... Baker Hughes INTEQ Planning Report INTRQ cOillpalÌy: .~P·Mtoco Date: . 611012003 TIme: 11:18:03 Page: Z FleW: PrUdI'!oø Bay (:o..qnlbl8te(NE)Refereace: WeD: X-08. True North Site: PBX Pad VerdcaI(fVD) Refereaee: System: Mean Sea Level WeD: X-08. SectiOa· (VS) Refereace: Well (O.OON.O.ooE.53.00Azi) WeØ.-tlt: PIan#4.X-08A ~ey Caleuiatloa Method: Minimum Curvature Db: Oracle Plan Seetlon Information DJßW4<.Tura TFO TaJ'get de9J100ft (:leg/100ft degl10Qft deg 10669.50 93.30 71.24 8802.59 -1025.46 3345.24 12.00 -0.02 12.02 88.62 11089.50 93.00 20.76 8777.90 -743.52 3637.16 12.00 -0.07 -12.02 271.17 11249.50 85.35 38.56 8780.22 -605.15 3715.93 12.10 -4.78 11.12 113.21 11409.50 76.45 56.56 8805.70 -498.88 3831.69 12.41 -5.56 11.25 117.83 11569.50 68.95 75.16 8853.63 -436.31 3970.06 12.03 -4.69 11.62 115.49 Survey MapN MapE VS DLS TFO Tool ft ft ft de9J10Qft deg 9500.00 16.67 132.31 8711.39 -1538.42 2496.95 5938209.89 668160.97 1068.31 0.00 0.00 TIP 9525.00 16.43 132.36 8735.35 -1543.22 2502.21 5938205.21 668166.34 1069.62 0.96 176.63 KOP 9543.00 18.23 132.31 8752.53 -1546.83 2506.18 5938201.69 66B170.3B 1070.62 10.00 359.50 3 9550.00 20.58 127.85 8759.14 -1548.32 2507.96 5938200.24 668172.20 1071.14 39.70 325.68 MWD 9575.00 29.57 117.76 87B1.77 -1553.91 2516.91 5938194.85 668181.27 1074.93 39.70 329.89 MWD 9600.00 38.99 112.14 8802.41 -1559.76 2529.69 5938189.28 668194.17 1081.61 39.70 339.06 MWD 9611.83 43.51 110.23 8811.30 -1562.57 2536.96 5938186.63 668201.50 1085.73 39.70 343.72 MWD 9625.00 48.18 106.93 8820.47 -1565.57 2545.91 5938183.83 668210.52 1091.07 39.74 331.97 MWD 9650.00 57.25 101.82 8835.61 -1570.45 2565.16 5938179.38 668229.87 1103.51 39.74 334.27 MWD 9675.00 66.49 97.67 8847.39 -1574.14 2586.87 5938176.16 668251.65 1118.62 39.74 337.38 MWD 9680.67 68.60 96.82 8849.55 -1574.80 2592.06 5938175.61 668256.86 1122.37 39.74 339.34 MWD 9700.00 75.58 93.50 8855.49 -1576.45 2610.37 5938174.37 668275.19 1136.00 39.62 335.11 MWD 9725.00 84.66 89.49 8859.78 -1577.08 2634.96 5938174.28 668299.79 1155.26 39.62 336.13 MWD 9749.50 93.59 85.68 8860.15 -1576.05 2659.41 5938175.85 668324.20 1175.41 39.62 336.82 4 9750.00 93.59 85.62 8860.12 -1576.01 2659.90 5938175.90 668324.70 1175.83 12.00 270.98 MWD 9775.00 93.64 82.61 8858.55 -1573.45 2684.72 5938179.00 668349.45 1197.19 12.00 270.97 MWD 9800.00 93.67 79.61 8856.95 -1569.60 2709.37 5938183.40 668374.01 1219.19 12.00 270.78 MWD 9825.00 93.70 76.60 8855.35 -1564.45 2733.78 5938189.07 668398.30 1241.78 12.00 270.59 MWD 9850.00 93.71 73.59 8853.73 -1558.04 2757.88 5938196.02 668422.25 1264.89 12.00 270.40 MWD 9875.00 93.72 70.59 8852.11 -1550.37 2781.62 5938204.21 668445.81 1288.46 12.00 270.20 MWD 9900.00 93.72 67.58 8850.49 -1541.46 2804.92 5938213.62 668468.91 1312.43 12.00 270.01 MWD 9925.00 93.70 64.58 8848.87 -1531.35 2827.72 5938224.23 668491.49 1336.73 12.00 269.81 MWD 9950.00 93.68 61.57 8847.26 -1520.05 2849.96 5938236.01 668513.47 1361.29 12.00 269.62 MWD 9975.00 93.64 58.56 8845.66 -1507.60 2871.58 5938248.93 668534.81 1386.05 12.00 269.43 MWD 10000.00 93.60 55.56 8844.09 -1494.04 2892.52 5938262.95 668555.44 1410.93 12.00 269.23 MWD 10025.00 93.54 52.55 8842.53 -1479.39 2912.71 5938278.04 668575.31 1435.88 12.00 269.04 MWD 10029.50 93.53 52.01 8842.25 -1476.64 2916.27 5938280.86 668578.80 1440.37 12.00 268.86 5 10050.00 93.55 49.55 8840.99 -1463.71 2932.12 5938294.15 668594.36 1460.81 12.00 270.64 MWD 10075.00 93.57 46.54 8839.43 -1447.03 2950.67 5938311.23 668612.54 1485.67 12.00 270.49 MWD 10100.00 93.59 43.53 8837.87 -1429.40 2968.32 5938329.24 668629.80 1510.37 12.00 270.30 MWD 10125.00 93.59 40.53 8836.31 -1410.87 2985.03 5938348.13 668646.09 1534.87 12.00 270.11 MWD 10150.00 93.58 37.52 8834.74 -1391.49 3000.74 5938367.85 668661.37 1559.08 12.00 269.92 MWD 10175.00 93.56 34.52 8833.19 -1371.31 3015.41 5938388.35 668675.60 1582.94 12.00 269.73 MWD 10200.00 93.53 31.51 8831.64 . -1350.39 3029.00 5938409.56 668688.73 1606.38 12.00 269.55 MWD 10225.00 93.49 28.51 8830.11 -1328.78 3041.48 5938431.43 668700.73 1629.35 12.00 269.36 MWD 10250.00 93.44 25.50 8828.60 -1306.55 3052.81 5938453.91 668711.57 1651.78 12.00 269.18 MWD 10269.50 93.40 23.16 8827.43 -1288.82 3060.83 5938471.81 668719.19 1668.86 12.00 269.00 6 10275.00 93.42 23.82 8827.11 -1283.78 3063.02 5938476.89 668721.27 1673.64 12.00 88.62 MWD 10300.00 93.48 26.83 8825.60 -1261.23 3073.69 5938499.67 668731.44 1695.73 12.00 88.66 MWD 10325.00 93.54 29.83 8824.07 -1239.26 3085.53 5938521.89 668742.80 1718.41 12.00 88.84 MWD 10350.00 93.58 32.83 8822.52 -1217.95 3098.50 5938543.48 668755.30 1741.59 12.00 89.02 MWD 10375.00 93.62 35.84 8820.95 -1197.35 3112.58 5938564.38 668768.91 1765.23 12.00 89.21 MWD 10400.00 93.65 38.85 8819.36 -1177.52 3127.71 5938584.54 668783.61 1789.25 12.00 89.40 MWD 10425.00 93.66 41.85 8817.77 -1158.51 3143.86 5938603.90 668799.33 1813.59 12.00 89.59 MWD 10450.00 93.67 44.86 8816.17 -1140.37 3160.98 5938622.41 668816.06 1838.18 12.00 89.78 MWD ObP e BP e -tIC Baker Hughes INTEQ Planning Report INTRQ ComPIIIIY: BP Amoco i)ate:6I1012003 ... ... . . .. .......TiII1e:11:18:03 Pag~ 3 Field: ProdhoeBay eo-ordlaåte(NE) .R~ert\oCè: Vt~I: x..øs.iJrue North Site: PB X Pad Ve~(TVD)R~erenœ: ~~~:~~S~L~vel Well: X.os SectIon(VS) Reference: VII':" (~).00N.9·00E,53.00Azi) Wellpath: PIan#4X-osA Survey Calculatlott Method: MinimumCUrvature Db: Ol"8Cle Survey MD Joel Azim SS'I'VD NIS FJW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10Qft deg 10475.00 93.67 47.86 8814.57 -1123.15 3179.04 5938640.02 668833.72 1862.96 12.00 89.97 MWD 10500.00 93.65 50.87 8812.98 -1106.91 3197.97 5938656.68 668852.29 1887.86 12.00 90.17 MWD 10525.00 93.63 53.87 8811.39 -1091.68 3217.73 5938672.34 668871.71 1912.80 12.00 90.36 MWD 10550.00 93.59 56.88 8809.81 -1077.50 3238.25 5938686.96 668891.92 1937.73 12.00 90.55 MWD 10575.00 93.55 59.88 8808.25 -1064.42 3259.50 5938700.50 668912.87 1962.57 12.00 90.74 MWD 10600.00 93.50 62.89 8806.72 -1052.47 3281.40 5938712.93 668934.51 1987.25 12.00 90.92 MWD 10625.00 93.44 65.89 8805.21 -1041.69 3303.90 5938724.20 668956.76 2011.71 12.00 91.11 MWD 10650.00 93.36 68.90 8803.72 -1032.10 3326.94 5938734.30 668979.58 2035.88 12.00 91.29 MWD 10669.50 93.30 71.24 8802.59 -1025.46 3345.24 5938741.33 668997.73 2054.49 12.00 91.47 7 10675.00 93.31 70.58 8802.27 -1023.67 3350.43 5938743.24 669002.88 2059.71 12.00 271.17 MWD 10700.00 93.37 67.57 8800.82 -1014.75 3373.74 5938752.66 669025.98 2083.69 12.00 271.13 MWD 10725.00 93.41 64.57 8799.34 -1004.63 3396.55 5938763.28 669048.56 2108.00 12.00 270.95 MWD 10750.00 93.45 61.56 8797.84 -993.33 3418.79 5938775.07 669070.55 2132.57 12.00 270.77 MWD 10775.00 93.48 58.56 8796.33 -980.88 3440.41 5938787.99 669091.89 2157.33 12.00 270.59 MWD 10800.00 93.49 55.55 8794.81 -967.31 3461.35 5938802.02 669112.53 2182.22 12.00 270.41 MWD 10825.00 93.50 52.55 8793.29 -952.66 3481.55 5938817.10 669132.40 2207.16 12.00 270.23 MWD 10850.00 93.50 49.54 8791.76 -936.98 3500.95 5938833.21 669151.45 2232.10 12.00 270.05 MWD 10875.00 93.48 46.54 8790.24 -920.29 3519.51 5938850.30 669169.63 2256.96 12.00 269.86 MWD 10900.00 93.46 43.53 8788.72 -902.66 3537.16 5938868.31 669186.89 2281.67 12.00 269.68 MWD 10925.00 93.43 40.53 8787.22 -884.13 3553.87 5938887.21 669203.19 2306.16 12.00 269.50 MWD 10950.00 93.39 37.52 8785.73 -864.74 3569.58 5938906.93 669218.47 2330.38 12.00 269.32 MWD 10975.00 93.34 34.52 8784.26 -844.56 3584.25 5938927.43 669232.69 2354.24 12.00 269.14 MWD 11000.00 93.28 31.51 8782.82 -823.63 3597.85 5938948.65 669245.83 2377.70 12.00 268.96 MWD 11025.00 93.22 28.51 8781.40 -802.02 3610.33 5938970.53 669257.83 2400.67 12.00 268.79 MWD 11050.00 93.14 25.50 8780.01 -779.78 3621.67 5938993.01 669268.67 2423.10 12.00 268.62 MWD 11075.00 93.05 22.50 8778.66 -756.98 3631.82 5939016.02 669278.32 2444.94 12.00 268.45 MWD 11089.50 93.00 20.76 8777.90 -743.52 3637.16 5939029.60 669283.36 2457.30 12.00 268.29 8 11100.00 92.50 21.93 8777.39 -733.75 3640.97 5939039.45 669286.96 2466.23 12.10 113.21 MWD 11125.00 91.30 24.71 8776.56 -710.81 3650.86 5939062.60 669296.35 2487.93 12.10 113.26 MWD 11150.00 90.10 27.49 8776.26 -688.37 3661.86 5939085.28 669306.84 2510.22 12.10 113.35 MWD 11175.00 88.90 30.26 8776.48 -666.48 3673.93 5939107.43 669318.43 2533.03 12.10 113.39 MWD 11200.00 87.70 33.04 8777.22 -645.21 3687.04 5939128.98 669331.07 2556.31 12.10 113.36 MWD 11225.00 86.51 35.83 8778.48 -624.62 3701.16 5939149.87 669344.73 2579.97 12.10 113.28 MWD 11250.00 85.32 38.62 8780.26 -604.76 3716.24 5939170.05 669359.37 2603.97 12.11 113.24 MWD 11275.00 83.88 41.37 8782.61 -585.69 3732.23 5939189.47 669374.94 2628.21 12.41 117.82 MWD 11300.00 82.45 44.15 8785.59 -567.47 3749.08 5939208.05 669391.38 2652.64 12.41 117.56 MWD 11325.00 81.04 46.94 8789.18 -550.15 3766.74 5939225.76 669408.66 2677.17 12.41 117.23 MWD 11350.00 79.65 49.76 8793.37 -533.77 3785.15 5939242.54 669426.70 2701.73 12.41 116.83 MWD 11375.00 78.29 52.60 8798.16 -518.39 3804.27 5939258.34 669445.47 2726.25 12.41 116.36 MWD 11400.00 76.95 55.46 8803.52 -504.04 3824.02 5939273.11 669464.91 2750.66 12.41 115.82 MWD 11409.50 76.45 56.56 8805.70 -498.88 3831.69 5939278.44 669472.46 2759.89 12.41 115.20 MWD 11425.00 75.65 58.30 8809.44 -490.78 3844.37 5939286.82 669484.95 2774.89 12.03 115.49 MWD 11450.00 74.40 61.13 8815.90 -478.60 3865.22 5939299.45 669505.53 2798.87 12.03 115.08 MWD 11475.00 73.17 63.99 8822.88 -467.53 3886.52 5939310.98 669526.58 2822.54 12.03 114.34 MWD 11500.00 71.99 66.89 8830.37 -457.62 3908.21 5939321.37 669548.05 2845.83 12.03 113.54 MWD 11525.00 70.86 69.83 8838.33 -448.88 3930.23 5939330.59 669569.87 2868.68 12.03 112.68 MWD 11550.00 69.77 72.81 8846.76 -441.34 3952.53 5939338.61 669591.99 2891.02 12.03 111.74 MWD 11569.50 68.95 75.16 8853.63 -436.31 3970.06 5939344.03 669609.42 2908.06 12.03 110.74 TD -- Nordic 2 CTD BOP Detail / aUI I I..... I I ~ t==e= HCR I ~ I I 7-1/16"10,5000 psi working pressure f.,r"- Z'Sideoutlets -t-F I 23/8" x 31/2" VBRs Ram Type Oual Gate BOPE I TOT IF --11 JL-- 23/8" Combi Pipe/Slip Manual over Hydraulic r ' xo Spool as necessary \ / I I ® I I ® I I I, THA I L Tubing 1-0iTL. f .0 J-~ Inner Annulus r Spool ì I i~ Outer Annulus f Methanol Injection .bH.ð Otis 7" WLA Quick " Connect - I 7-1/16" 10, 5000 psi working pressure I r Ram Type Oual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Full production christmas tree MOJ 9/15/02 e °'\ll- CT Injector Head I I -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ 7" Riser I I ~ Annular BOP (Hydril),7-1/16" 10 /. 5000 psi working pressure ./ I I Blind/Shear I / / 123/8" Combi PipeJSli~ Kill line check valve or HeR --¥AO- : Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to StandpipE manifold / 1/ 1/ 2 flanged gate valves P055083 DATE --.-----..--'-- 6/9/2003 INVOICE / CREDIT MEMO DESCRIPTION 6/;/~~03 1 r GROSS VENDOR DISCOUNT INV# CK060403C PERMIT TO DRill FEE O~·() I I ." '(~,.) ·l,~ \ ,.,.} r~ (:::/"'1 "".". C 'I"'" .1. . -v,_ ',",..~ ðf'" ........ ...n!;'!;. ~ ¡.,.,., JU '7 ~'9 b " N .. .... . ""'>L) Akh"t~ 2 1- "%"1 Oi! ö ..~' nlE ATTAGliEIJ Cli~:·I~·~N PAYMENT FOR ITEMS DESC~BED A~----- _·_····_-_·..~·_,···_..._,___·__·__·,·~·,___,v_. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX "196612 ANCHORAGE, AK 99519-f:3612 PAY: TO THE ORDER OF: B fJ C:','; "r . . ".,Jj.. ALASKA Oil & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 -... ->'~--'---"'--"-'-"'--~~-'-'~"-'----'--"-'-'--'-' -,--_._--,._.,,~---_..~_._- II- 0 5 5 0 8 j II- a: 0 l. ~ 2 0 j 8 g 5 I: 0 ¡. 2 7 B '1 b II- NATIONAL CITY BANK Ashland, Ohio No.P CONSOLIDATED COMMERCIAL ACCOl.lNI 055083 AMOUNT ·'---l I'--~::::::$-~~-;~¿o::::::*l I _____________..1 NOT VALlp.A.~I:EB.,12()g~~ ,........ :...:......, ::..;.... '" ..' ."...' 56-389 412 tIlt, 1,"1 I -li"h' DATE June 9, 2003 ...,.... :', {\' ,¡:; .. CHECK NO. 055083 NET ._-,.._-~---~._----,--- -,--_._--~--- Ii e e e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wellbore segment of existing weD-, Permit No, API No. Production sbould continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 Ojody\templates Tbe permit is approved subject to fuD compliance witb 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. ~vvE;.~Ei~I~é~rÇKLI~:r. Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT X-08L 1 Program DEV Well bore seg ~ PTD#:2031170 Field & Pool PRUDHOEBAY,PRUDHOEOIL-640150 InitialClasslType DEV/1-0IL GeoArea 890 Unit 11650 On/OffShore ~ Annular Disposal 0 Administration 1 Permittee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease_number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U.nique weltname_aod lJl!mb.er _ _ _ _ _ _ _ . _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ 4 WelUQcated in_a_d_efil'!eJJ-pooL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WellJQcated prßper _distance_ from driJIing ul'!itb_oUl'!djli:Y_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJQcated prßper _distance_ from Qtber wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S.uffjcieI'!Lacreag.e_aYailjlble inÞilIilJg unJL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jtdeviated, Js_ weJlbQre plç¡til'!cJuJJed _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 90-perator onl}' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-perator bas_appropriateJ)_oI1d lnJQr~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ 11 PelJ'l'lit c.ao be iSSl!ed witbout co_nservaJion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Permitc.ao be iSSl!ed wJtbout admil'!istrative_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 6/24/2003 13 Can permit be approved before 15-daywait Yes 14 WellJQcated within area and_strata jluthorized byJojectiolJ Order # (putlO# in_comm_eotsHFor_ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 _AJlwells_withillJl4_roile.area_ofreyiewidelJtifjed(For~ervJcew.eIlOI'!I}'). _ _. _ _.. _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _.. _ _ _ _. _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _. _ _. _. _. _ _ _ _ _ __ 16 Pre-produ~ediojector; JJuration_ofpre--proJJuctiOI'! less_than 3 months_(For_ser:vicewellQnJy) _ _ Yes _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 17 ACMP_finding _of CQn_si$teocy_h_as Þee_nj~sued.for.tbis project _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 18 _C_ooductor string_prQvided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ 19 .S_urface _casing_pJQtects alLknown USDWs _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ 20 _CMT v_ol adeQl!ate.to circutate_oll_COl'!d_uctor_ & su_rf_C$g . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ . _ _ _ _ _ _ _ _ _ _ 21 _CMTv_oladeQu_ate.totie-inJQng_stringto_surfcsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 22 _CMTwill coyer_aJI klJow_n-productiYe bQrilOnS_ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Slotte_d, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asiog designs adeCua_te for C,_T, B _&_ permafr.ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. . _ _ _ . _Yes _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . 24 _Mequate_tan_kage_oJ re_seIYe pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ CTDU. _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . 25 Jta_re-drilt bas.a to:403 for abandonme_nt beelJ apPJQved _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ NA _ _ _ _ _ _ _ La.teral. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . 26 _Mequatewellboresepªratio.n_pro-posed_ _ _ _ _ _ _ . _ _ _ _ _ . _ . . _ _ _ . . _ _ _ . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ . . _ _ . . _ . _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ 27 Jtdiverter req.uired, dQes it meet reguJations_ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Appr Date 28 .DJilliogf]uid_programsc.hemç¡tic&eq.uipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. Yes_ _ _ _ _ _ _Mç¡xMW_8,5.ppgc _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _. _ _ . _ _ _. _ _ _ _ _ __ WGA 6/25/2003 29 _BOPEs,_do_they meetreguJa.tion _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ 30 _BOPEpress ra_tiog ªp-propriate;test to (put psig ill_commel'!ts)_ _ _ . _ _ _ _ _ _ _ _ _ _ _ Yes. _ _ _ _ Test to_35QO_psi. _MS~ 23_87 psi. _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _C.hokeroanifold cQmpJies_ w/APtR~-53 (May B4). _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 WQrk wiJl occ.ur without.operatioll_sbutdown_ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ 33 Js presence_ Qf H2S gas_ prob.able _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ 34 Mecba_nicaLcOlJdjt[oo of wells within.A.OR yerified (For_s_ervice welJ onJy).. . _ _ _ _ _ _ _ _ _ _ _NA _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Permit c.ao be issued w/o hYdrogen_ s_ulfide meaSures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . 36 _D_ata_preselJted onpote_ntial oveJpressure_zOl'!es_ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Appr Date 37 _Seismic_anç¡lysjs_ Qf sba.llow gas_zooes_ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 6/24/2003 38 _SeabedcOl'!ditiolJ survey _(if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ . . _ _ _ _ _ _ _ _ _ 39 _CQnta_ctnamelphon.eJor_weeklyprogress_reports[exploratoi:Y_only)._ _ _ _ _ _ _ _ _NA _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ Geologic Commissioner: Date: DTS 06/<-.Jp3 Public 'C:4J Commissioner 0 r- Date o/;YO] Engineering Commissioner: jf~ :fß Date . e e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 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. Sperry-Sun Dr~ng Services LIS Sca~ility . 903-l \-=r $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 30 15:51:15 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments..... ........... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA X-08A 500292046301 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 30-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002600190 S. LATZ SEVCIK/SARBE MWD RUN 2 MW0002600190 S. LATZ SEVCIK/SARBE MWD RUN 3 MW0002600190 S. LATZ SEVCIK/SARBE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002600190 S. LATZ SEVCIK/SARBE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 7 ION 14E 430 264 73.48 # WELL CASING RECORD OPEN HOLE CASING DRILLERS R\s~(Y~~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S~(IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9535.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS) . 3. MWD RUNS 1 & 3 COMPRISED DIRECTIONAL AND GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 & 4 COMPRISED DIRECTIONAL WITH GM AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 4 WAS ACTUALLY A MAD PASS TO ACQUIRE EWR4 DATA OVER THE RUN 3 INTERVAL. ONLY EWR4 DATA FOR RUN 4 WERE MERGED WITH RUN 2 DATA FOR THIS PRESENTATION (I.E., THE DRILLED VALUES FOR SROP AND SGRC OVER THE RUN 3 INTERVAL WERE USED). NO SEPARATE MAD PASS IS INCLUDED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP EXPLORATION (ALASKA), INC., DATED 9/5/03. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 4 REPRESENT WELL X-08A WITH API#: 50-029-20463-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11691'MD/8830'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name......... ... .STSLIB.OOl Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ .5000. START DEPTH 9527.5 9540.5 9540.5 9540.5 9540.5 9540.5 9555.5 STOP DEPTH 11665.5 11661.5 11661. 5 11661. 5 11661. 5 11661. 5 11691.0 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 9527.5 9790.5 11191. 0 11159.5 MERGE BASE 9790.5 11191.0 11691.0 11661.5 # Data Format Specification Record Data Record Type.... ........ ......0 Data Specification Block Type. ....0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..... .............. ..60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR MWD MWD MWD MWD MWD MWD MWD Min 9527.5 0.11 21.04 0.29 0.28 0.29 0.03 0.24 Max 11691 1233.61 496.14 2000 2000 2000 2000 34.46 Mean 10609.3 98.169 51.9374 26.3771 22.1336 19.5566 40.536 6.65024 First Reading For Entire File.. ....... .9527.5 Last Reading For Entire File. ......... .11691 Nsam 4328 4272 4277 4243 4243 4243 4243 4243 First Reading 9527.5 9555.5 9527.5 9540.5 9540.5 9540.5 9540.5 9540.5 Last Reading 11691 11691 11665.5 11661.5 11661.5 11661.5 11661.5 11661.5 . . File Trailer Service name........ .... .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record. .65535 File Type............. ...LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9527.5 9555.5 STOP DEPTH 9764.5 9790.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 13-AUG-03 Insite 4.3 Memory 9791.0 9550.0 9791. 0 16.3 86.1 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 10505071 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 9347.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Flo Pro 8.60 65.0 8.5 20000 7.8 RESISTIVITY (OHMM) AT4laPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .140 .000 .250 .190 6. 160.0 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units....... ....Feet Data Reference Point............ ..Undefined Frame Spacing........ ......... ....60 .1IN Max frames per record...... .......Undefined Absent value......... .... ..... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9527.5 9790.5 9659 527 9527.5 9790.5 ROP MWD010 FT/H 0.11 388.58 59.9236 471 9555.5 9790.5 GR MWD010 API 26.81 496.14 105.852 475 9527.5 9764.5 First Reading For Entire File......... .9527.5 Last Reading For Entire File.......... .9790.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name. ........... .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 9540.5 9540.5 9540.5 9540.5 9540.5 9765.0 9791. 0 STOP DEPTH 11159.0 11159.0 11159.0 11159.0 11159.0 11146.0 11191.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 16-AUG-03 Insite 4.3 Memory 11185.0 9791.0 11185.0 89.3 97.5 TOOL NUMBER 82758 126589 3.750 9347.0 Flo Pro 8.60 65.0 8.5 20000 6.4 .140 .060 .270 .180 70.0 165.0 70.0 70.0 Data Format Specification RJllÞd Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value............. ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9540.5 11191 10365.8 3302 9540.5 11191 ROP MWD020 FT/H 1.16 1233.61 97.42 2801 9791 11191 GR MWD020 API 21.04 274.75 42.1447 2763 9765 11146 RPX MWD020 OHMM 0.29 2000 24.2201 3238 9540.5 11159 RPS MWD020 OHMM 0.28 2000 20.7365 3238 9540.5 11159 RPM MWD020 OHMM 0.29 2000 19.3504 3238 9540.5 11159 RPD MWD020 OHMM 0.03 2000 46.2831 3238 9540.5 11159 FET MWD020 HOUR 0.24 28.41 4.17169 3238 9540.5 11159 First Reading For Entire File......... .9540.5 Last Reading For Entire File....... ....11191 File Trailer Service name........ .....STSLIB.003 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation... ... .03/09/30 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name.... ........ .STSLIB.004 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation..... ..03/09/30 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name.. .... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 4 header data for each bit run in separate files. 3 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ .5000 . START DEPTH 11146.5 11191.5 STOP DEPTH 11665.5 11691.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point... ......... ..Undefined Frame Spacing...... .... ......... ..60 .1IN Max frames per record.... ...... ...Undefined Absent value......... ....... ......-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 17-AUG-03 Insite 4.3 Memory 11691.0 11185.0 11691.0 76.7 89.4 TOOL NUMBER 10505071 3.750 8907.0 Flo Pro 8.60 65.0 8.5 20000 7.4 .000 .000 .000 .000 .0 .0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel . DEPT ROP MWD030 GR MWD030 FT FT/H API . 4 4 1 68 1 68 1 68 o 4 8 ;. 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11146.5 11691 11418.8 1090 11146.5 11691 ROP MWD030 FT/H 8.85 950.57 118.281 1000 11191.5 11691 GR MWD030 API 24.26 151. 2 53.3309 1039 11146.5 11665.5 First Reading For Entire File......... .11146.5 Last Reading For Entire File........ ...11691 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number. ......... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record..65535 File Type... ..... ....... .LO Next File Name... ...... ..STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/09/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 11159.5 11159.5 11159.5 11159.5 11159.5 STOP DEPTH 11661. 5 11661. 5 11661.5 11661.5 11661.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17-AUG-03 Insite 4.3 Memory 11661.0 11160.0 11661.0 16.3 MAXIMUM ANGLE: . # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 97.5 . TOOL NUMBER 82758 126589 3.750 8907.0 Flo Pro 8.60 65.0 8.5 20000 7.4 .250 .120 .220 .260 70.0 159.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD040 OHMM 4 1 68 4 2 RPS MWD040 OHMM 4 1 68 8 3 RPM MWD040 OHMM 4 1 68 12 4 RPD MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11159.5 11661.5 11410.5 1005 11159.5 11661.5 RPX MWD040 OHMM 1. 94 2000 33.3266 1005 11159.5 11661.5 RPS MWD040 OHMM 2.38 2000 26.635 1005 11159.5 11661.5 RPM MWD040 OHMM 2.61 2000 20.2212 1005 11159.5 11661.5 RPD MWD040 OHMM 2.99 2000 22.0197 1005 11159.5 11661.5 FET MWD040 HOUR 8.13 34.46 14.6359 1005 11159.5 11661.5 .. '" Fi;st Reading For Entire Fi~.... ... .11159.5 Last Reading For Entire File....... ....11661.5 . File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/30 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ............ .UNKNOWN Continuation Number..... .01 Next Tape Name... ....... .UNKNOWN Comments.... .... ...... ...STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/30 Origin.................. .STS Reel Name.... ........... . UNKNOWN Continuation Number..... .01 Next Reel Name. ......... .UNKNOWN Comments.... .... ........ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File