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203-194
RECEIVED STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS N OCT 11 2016 WELL OMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned m - Suspended 0 1b.Well AOGCC 20AAC 25.105 20AAC 25.110 Development m Exploratory 0 GINJ 0 WINJ 0 WAG ❑ WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: ,` 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc -9114/2646 91 t'3)Zf t LQ 203-194 - 316-279 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 1/1/2004 50-029-22448-02-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: LAr 4 Sl4( l e ii 1/5/2004 PBU 15-33B Surface: 559'FNL,488"ANL,Sec.22,T11N,R14E,UM ^ 9 Ref Elevations KB 69.6 17. Field/Pool(s): Top of Productive Interval: 2672'FSL,3346'FEL,Sec.16,T11N,R14E,UM GL 32.6 - BF 33.5 ' PRUDHOE BAY,PRUDHOE OIL Total Depth: 2609'FSL,5227'FEL,Sec.16,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 10690'/8765' r ADL 028306 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 676021 • y- 5960923 ' Zone - ASP 4 , 12699'/8842' • 78-084 TPI: x- 672488 y- 5964075 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/TVD: Total Depth:x- 670609 y- 5963968 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ® 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top window Submit electronic and printed information per 20 AAC 25.050 MD/TVD:N/A (ft MSL) 10354'/8650' • 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary SGRC Combined GR&EWR,MGR/CCL/CNL 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 39' 119' 39' 119' 30" 260 sx Arctic Set(Approx.) 13-3/8" 68# NT-80 38' 3607' 38' 3546' 17-1/2" 1205 sx PF'E',375 sx Class'G' 9-5/8" 47# NT-80 36' 9686' 36' 8294' 12-1/4" 751 sx Class'G' 7" 26# L-80113cre0 9520' 10354' 8204' 8650' 8-1/2" 286 sx Class'G' 3-1/2"x3-1/4" 9.3#/6.2 L-80 10077' 12699' 8516' 8842' 4-1/8'x3-3/4" 127 sx Class'G' x2-7/8" /6.16# 24. Open to production or injection? Yes 0 No ® 25. TUBING RECORD If Yes,list each interval open(MDiRtD of+ and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#L-80 10164' 10158'/8561' L '`'l 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 3Z017, , cf//3/((� Was hydraulic fracturing used during completion? Yes 0 No Q SCANNED- MAR ) Per 20 AAC 25.283(i)(2)attach electronic and printed r• / yt1 ;F:.i;' information LV DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10767' Set CIBP 10690' Set Whipstock t 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ...► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate "".4► Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only ATL /471;+3l j‘- ,It /ei1f S13 RBDM7�/7 2016 4 28: CORE DATA Conventional Core(s) Yes El No H • Sidewall Cores Yes 0 No m If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes ❑ No 10 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 10748' 8783' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 22TS 10450' 8684' 21 TS-Zone 2A 10606' 8735' Zone 1B 10748' 8783' TDF-Zone 1A 10884' 8823' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Browning,Zachary H Email: Zachary.Browning©bp.com Printed Name: Joe Lastu a k Title: Drilling Technologist Signature: hone: +1 907 564 4091 Date: JO/II 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.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Altemating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.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 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • 15-33B Well History (Pre-Rig Sidetrack) AC 'T!Y r t-re T/I/0=2500/300/80, Temp=S/I, Assist E-line with load and kill. (Pre CTD) Pumped 5 bbls neat and 250 bbls of 110*F 1%KCL w/safelube down the tubing for load. ***Job 9/3/2016 Continued on 09-04-2016*** ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE - PLUG/WHIPSTOCK) INTIAL T/I/O =2500/300/100 PSI RIG UP SLB AND LRS. PRESSURE TEST. MU BAKER CIBP. LRS PUMP 250BBL SAFE LUBE FOR L& K PRIOR TO RIH WITH CIBP. RUN 1: RIH WITH GR/CCL/BAKER CIBP (MAX RUNNNING OD 2.56") FOR SETTING 9/3/2016 IN 3 3/16" LINER. ***JOB CONTINUED FROM 3-SEP-2016*** (SLB ELINE -CIBP/WHIPSTOCK) SET 2.56" OD BAKER 033 CIBP IN 3-3/16" LINER AT 10767.75' (MID-ELEMENT) 10767'TOP OF PLUG. CCL STOP DEPTH = 10757.5', CCL TO ME = 10.25'. CORRELATED TO PDS COIL FLAG DATED 19-JAN-2009. LRS PERFORMED MIT-T AFTER PLUG SET BUT UNABLE TO GET PASSING RESULTS. SEE LRS WRS FOR DETAILS. PER PROGRAM: DUE TO FAILING TEST, LRS OBTAINED LLR. DID NOT SET WHIPSTOCK. 9/4/2016 FINAL T/I/O = 0/146/0 ***Job Cont from 09-03-2016 WSR*** MIT-T FAILED to 2500 psi (Pre CTD) Pumped 49 bbls of 90* 1%KCL w/safelube down Tbg followed by 38 bbls of ambient DSL for FP. Pumped a total of 51.4 bbls of ambient DSL down Tbg for MIT-T to 2500 psi. 1st attemp Tbg lost 250 psi in 10 mins. Pumped .4 bbls on 3 LLR tests and got a LLR of-.42 gpm. Performed MIT-T to 2500 psi off a bump up for LLR. Took Tbg to 2760 psi. 1st 15 mins Tbg lost 217 psi. 2nd 15 mins Tbg lost 173 psi. Total Test Tbg lost 390 psi. FAIL. Started 3rd MIT-T at 2756 psi. 1st 15 minst Tbg lost 202 psi. 2nd 15 mins Tbg lost 167 psi. Total Test Tbg lost 369 psi. FAIL. Bled down Tbg (-1.7 bbls). E-line rigged down, Rig up to P- sub. Pumped a total of 3 bbls diesel for a 7th test pressured up Tbg to 2738 psi. MIT-T lost 172 psi in 1st 15 minutes and 150 psi in 2nd 15 minutes for a total loss of 322 psi in 30 minute test. Pumped 10 bbls diesel down IA through jumper hose via lube and bleed method to get positive pressure on IA. Pressured up tubing with additional 1.6 bbls diesel to reach 2755 psi. MIT-T lost 216 psi in 1st 15 minutes and 176 psi in 2nd 15 minutes for a total loss of 392 psi in a 30 minute test. Established an average LLR of.42 GPM throughout MIT-T represurization. Bled Tbg psi (-2.7 bbls diesel) E-line has well control, 9/4/2016 hung tag on wing with test results. FWHP's=0/140/0. ***WELL SHUT IN UPON ARRIVAL***(SLB ELINE-WELLTEC TRACTOR/ WHIPSTOCK) INITIAL T/IA/OA= 150/300/100 ARRIVE AT WELLSITE AND BEGIN SWAP FROM .23 TO .32 LINE TO RUN TRACTOR WHIPSTOCK. RIG UP ON WELLHEAD AND LAY DOWN LUBRICATOR TO MAKE UP WELLTEC TRACTOR AND DO TOOL CHECKS. SPOT IN THIRD PARTY CRANE. PERFORM WIND READINGS AND RISK ASSESSMENT DUE TO WINDS PICKING 9/6/2016 UP. • 15-33B Well History (Pre-Rig Sidetrack) ***JOB CONTINUED FROM 6-SEP-2016***(SLB ELINE -WHIPSTOCK) RUN 1: RIH W/WELLTEC TRACTOR, BAKER 3-3/16" MONOBORE WHIPSTOCK TO 2600'. SLB ORIENTING TOOL SHORTS OUT. POOH. SWAP TO BACKUP TOOLS RUN 2: RIH W/WELLTEC TRACTOR, BAKER 3-3/16" MONOBORE WHIPSTOCK OAL=72' OAW= 550# MAXOD=2.7" SET DOWN 10125'. TRACTOR TO 10190' . UNABLE TO TRACTOR FURTHER. MADE 2 ATTEMPTS WITH SAME RESULTS. POOH. DECISION MADE TO RIG DOWN DUE TO INABILITY TO ACQUIRE TARGET DEPTH. FINAL T/IA/OA= 0/200/0 9/7/2016 ***JOB COMPLETE. WELL SHUT IN UPON DEPARTURE*** CTU #9 w/ 1.75" ct : Job objective Whipstock Drift 9/9/2016 Pumped 1 1/4" ball to drift coil/ Perform weekly BOP test CTU #9 w/ 1.75" ct : Job objective Whipstock Drift RIH w/2.63"x 27.80'whipstock drift. Drifted clean to CIBP @ 10767' POOH freeze 9/10/2016 protect well w/37 bbls of 50/50 methanol ****Job complete**** T/I/O = 0/173/0. Set 4" TWC#434 ©125"Through tree. Conducted LTT on TWC Passed. Installed White TS#06 W/4x7 XO#06. Installed CV W/4" Int. Temp#12 . RU Blowdown line off Companion Int. Installed slip blind in WVxFL. Torqued and PT'd to API specs. (PASS) Serviced tree pre CTD. Removed platforms and installed nordic platform. 9/10/2016 RDMO. ***Job Complete*** FWHP = TWC/0/0. See log for details. • S North America-ALASKA-BP Page 1' Operation Summary Report Common Well Name:15-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) j Start Date:9/11/2016 End Date:9/18/2016 X3-0182L-C:(2,133,427.00) Project:Prudhoe Bay J Site:PB DS 15 Rig Name/No.:NORDIC 2 j Spud Date/Time:2/24/1994 12:00:00AM Rig Release:9/21/2016 Rig Contractor:NORDIC CALISTA UWI:500292244800 Active datum:Kelly Bushing/Rotary Table @69.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/11/2016 05:00 - 05:30 0.50 MOB P PRE RIG DOWN ANCILLARY EQUIPMENT PREPARE TO MOVE RIG OFF WELL 05:30 06:00 0.50 MOB P PRE 1PJSM WITH CREW TO MOVE OFF WELL I-TESTED AND VERIFIED ESD WAS FUNCTIONALAND IS MANNED BY TOOLPUSHER I-VERIFIED 12 X 12 WHEEL CHOCK IN PLACE -ASSIGNED SPOTTERS TO AREA OF RESPONSIBILITY -AGREED ON STOP WAS THE COMMAND TO STOP RIG. -PERFORMED RADIO CHECK PRIOR TO MOVING RIG. -DISCUSSED WITH CREW THAT THERE WAS NO BPV INSTALLED j MOVE RIG OFF WELL. SET DOWN 06:00 - 06:40 0.67 MOB P PRE CREW CHANGE 06:40 - 08:30 1.83 MOB P PRE PERFORM ROUTE DRIVE CLEAN UP SUPPORT EQUIPMENT AND RIG MATS UPDATE SECURITY FOR 8:30 MOVE TIME 08:30 - 09:00 0.50 MOB P PRE HOLD A PJSM TO MOVE RIG 09:00 - 11:15 2.25 MOB- P PRE MOVE RIG TO DS 15 11:15 - 14:00 2.75 MOB P PRE I STOP AT OXBOW INTERSECTION TO MOVE ---_-_ RIG MATS 14:00 - 16:00 2.00 MOB P PRE RIG MATS IN PLACE,CONTINUE MOVING TO DS 15 16:00 - 17:45 1.75 MOB P PRE RIG ON DS 15 LOADERS SPOTTING RIG MATS ON THE ACCESS ROAD TO THE BACKSIDE OF I THE PAD SPOT OUR T-MATS AND RIG MATS AROUND AND IN FRONT OF OUR WELL 17:45 - 18:00 0.25 MOB P PRE RIG MATS SPOTTED,MOVE RIG TO BACKSIDE OF PAD 18:00 - 19:30 1.50 MOB P PRE RIG ON BACKSIDE OF PAD AND LINED UP, STOP FOR CREW CHANGE PJSM WITH CREW TO MOVE OFF WELL. VERIFIED ALL WELLS LOCKED OUT -TESTED AND VERIFIED ESD WAS FUNCTIONAL AND IS MANNED BY TOOLPUSHER -VERIFIED 12 X 12 WHEEL CHOCK IN PLACE ,-ASSIGNED SPOTTERS TO AREA OF RESPONSIBILITY -AGREED ON STOP WAS THE COMMAND TO STOP RIG. -PERFORMED RADIO CHECK PRIOR TO MOVING RIG. RIG ACCEPTED AT 19:30 19:30 - 00:00 4.50 MOB P PRE RIG UP SIMOPS-INSTALL REEL AND REEL HARDLINE SIMOPS-PERFORM LTT OF SWAB/TWC FOR THERMAL EXPANSION. NIPPLE DOWN TREE CAP. NIPPLE UP BOPE SIMOPS MAKE UP GOOSENECK/STUFFING BOX TO INJECTOR Printed 10/3/2016 4:09:20PM *AII depths reported in Drillers Depths* 110 • North America-ALASKA-BP Page 2 ce2- Operation Summary Report Common Wet Name: 15-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/11/2016 End Date:9/18/2016 X3-0182L-C:(2,133,427.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:2/24/1994 12:00:00AM Rig Release:9/21/2016 Rig Contractor:NORDIC CALISTA UWI:500292244800 Active datum:Kelly Bushing/Rotary Table©69.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/12/2016 00:00 - 02:00 2.00 MOB P PRE PJSM, PULL COIL ACROSS TO INJECTOR. REBOOT E-LINE. SET OFF TO SIDE FLOOD STACK. PERFORM 300 LOW/4500 HIGH SHELL TEST. GOOD 02:00 - 04:45 2.75 BOPSUR P PRE TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -TEST WITNESS WAIVED BYAOGCC REP BRIAN BIXBY 04:45 - 07:00 2.25 BOPSUR P PRE ,TESTED ANNULAR WITH 2"TEST JOINT VISUAL FLOW FROM ABOVE ANNULAR. BLED DOWN. CYCLE ANNULAR AND RETEST. FAILED. CARRY ON WITH REMAINING TESTS. PREPARE TO REPLACE ANNULAR ELEMENT. SIMOPS-LOAD REEL WITH FRESHWATER FOR IRV/PACKOFF TESTS 07:00 - 07:35 0.58 ( BOPSUR P PRE TEST IRV AND PACK OFF TO 250 LOW AND 3500 HIGH 07:35 - 08:00 0.42 BOPSUR P PRE REVERSE SLACK 08:00 - 08:45 0.75 BOPSUR P PRE RU CUTTER TO CUT PIPE GREASE CREW CHECK TREE BOLTS WHILE CUTTING PIPE 08:45 - 09:00 0.25 BOPSUR P PRE CUT 260'OF COIL,NO ELINE,RD CUTTER AND SET INJECTOR OFF TO THE SIDE HOLD A PJSM TO REPLACE THE ANNULAR ELEMENT 09:00 - 09:40 0.67 BOPSUR P PRE REPLACE ANNULAR ELEMENT 09:40 - 11:50 2.17 BOPSUR N RREP PRE ELEMENT REPLACE,REINSTALL LUBRICATOR,FLUID PACK STACK,SHELL TEST LUBRICATOR AND RETEST ANNULAR 11:50 - 12:15 0.42 BOPSUR P PRE TEST COMPANION IRON 12:15 - 12:30 0.25 BOPSUR P PRE HOLD RIG EVAC DRILL BEFORE PULLING TWC 12:30 - 12:45 0.25 BOPSUR P PRE PJSM TO RU VALVE CREW LUBRICATOR AND PULL TWC 12:45 - 15:00 2.25 BOPSUR P PRE LOAD LUBRICATOR ON RIG AND PULL TWC 15:00 - 15:30 0.50 BOPSUR P PRE TWC PULLED,LOAD OUT LUBRICATOR 15:30 - 15:40 0.17 BOPSUR P PRE HOLD A PJSM TO MU THE CTC 15:40 - 16:00 0.33 BOPSUR P PRE MU THE CTC 16:00 - 17:00 1.00 BOPSUR N SFAL PRE PT CTC,LEAKING CUT OFF CTC AND REINSTALL PT TO 250 AND 4300 PSI 17:00 - 17:25 0.42 BOPSUR P PRE PJSM FOR Z HP TEST 17:25 - 18:00 0.58 BOPSUR P PRE ONLINE WITH LRS FORA LOW PT 17:35 START 300 PSI LOW PT 17:40 GOOD LOW,GO TO HIGH 17:50 START HIGH PT 17:55 GOOD HIGH PT BLEED OFF PRESSURE 18:00 - 18:30 0.50 BOPSUR P PRE LINEUP DOWN THE COIL AND PUMP SLACK FORWARD 18:30 - 21:00 2.50 CONDHL P PRE TEST E-LINE. GOOD TEST MAKE UP BHI UQC W/FLOATS TEST FLOATS TO 250#/3500# Printed 10/3/2016 4:09:20PM *All depths reported in Drillers Depths* • • • North America-ALASKA-BP Page 3`0` Operation Summary Report Common Well Name:15-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/11/2016 End Date:9/18/2016 X3-0182L-C:(2,133,427.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:2/24/1994 12:00:00AM Rig Release:9/21/2016 Rig Contractor:NORDIC CALISTA UWI:500292244800 Active datum:Kelly Bushing/Rotary Table©69.60usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 CONDHL P PRE PJSM, MAKE UP BHA. OPEN WELL TO CLOSED CHOKE. 18#ON WELL COME ONLINE AT MINIMUM WITH 10 BBLS METHANOL/FOLLOWED BY 120°1%KCL. TAKE ALL RETURNS TO TIGER TANK STARTED GETTING GASEOUS RETURNS. STOP EVERY 1000'TO STRAP TANK 9/13/2016 00:00 - 04:30 4.50 CONDHL P PRE CONTINUE TO CIRCULATE AT MINIMUM. TAKING ALL RETURNS TO FLOWBACK TANK RIH TO 10765' TAG CIBP WITH NO ISSUE. INCREASE RATE TO 2.6 BPM. CIRCULATE 1.5 • BOTTOMS UP WITH 120 DEG 1%KCL.FLUIDS CLEAN UP AT BOTTOMS UP. OPEN CHOKE. SWAP TO 9.5 PPG QUICKDRIL MUD. CIRCULATE SURFACE TO SURFACE. VERIFY LUBRICATOR FLUID PACKED. LINE UP THROUGH MGS.PUMP 30 BBLS. RETURNS LOOK GOOD. LINE UP NORMAL FLOW PATH. 04:30 - 04:40 0.17 CONDHL P PRE PERFORM 10 MIN FLOW CHECK. WELL STATIC. 04:40 - 06:45 2.08 CONDHL P PRE LINE BACK UP THROUGH MGS. POOH 9.53 PPG IN /9.51 PPG OUT 1.98 BPM IN/1.52 BPM OUT PULLING OUT OF HOLE. 06:45 - 07:00 0.25 CONDHL P PRE FLOW CHECK WELL HOLD A PJSM TO LAD THE NOZZLE BHAAND MU THE WS BHA 07:00 - 07:15 0.25 CONDHL P PRE GOOD NO FLOW,TAG UP,REMOVE THE INJECTOR AND LD THE NOZZLE BHA 07:15 - 07:50 0.58 WHIP P WEXIT LOAD WS ON RIG&SCRIBE MU WS BHAAND STAB ON FLUSH MGS BACK TO FRESH WATER 07:50 - 10:30 2.67 WHIP P WEXIT RIH 10:30 - 12:10 1.67 WHIP P WEXIT WT CK ABOVE THE TOL LOG TIE IN,-6'CORRECTION LOG CCL 12:10 - 12:20 0.17 WHIP P WEXIT SET WHIPSTOCK: -PRESSURE UP TO 4600 PSI AND RELEASE FROM WHIPSTOCK -TOWS:10690'MD -BOWS:10698.73'MD -SET 30 DEG ROHS -CONFIRM SET WITH 5.0K DOWN WEIGHT 12:20 - 12:30 0.17 WHIP P WEXIT MONITOR WELL FOR 10 MINUTES 12:30 - 14:05 1.58 WHIP P WEXIT STATIC POOH -MUD WEIGHT:9.5 PPG IN,9.5 PPG OUT -RATE:1.42 BPM IN,0.92 BPM OUT 14:05 - 14:15 0.17 WHIP P WEXIT MONITOR WELL FOR 10 MINUTES -CLOSE EDC,POWER DOWN 14:15 - 14:40 0.42 WHIP P WEXIT STATIC,TAG UP -INJECTOR OFF:14:20 Printed 10/3/2016 4:09:20PM 'All depths reported in Drillers Depths* S • North America-ALASKA-BP Page 4 oEA-- Operation Summary Report Common Well Name:15-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/11/2016 End Date:9/18/2016 fX3-0182L-C:(2,133,427.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:2/24/1994 12:00:00AM Rig Release:9/21/2016 Rig Contractor:NORDIC CALISTA 11UWI:500292244800 Active datum:Kelly Bushing/Rotary Table©69.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ` (usft) 14:40 - 15:20 0.67 WHIP P WEXIT MAKE UP MILLING BHA 3 -PICK UP 2-3/8"XTREME MOTOR(0.6 DEG AKO)AND COILTRAK TOOLS -MAKE UP 2.74 HCC WINDOW&STRING MILLS -SURFACE TEST TOOL.GOOD TEST. i-PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES/3800 PSI HIGH FOR 5 MINUTES -INJECTOR ON:15:15 • 15:20 - 18:00 2.67 WHIP P WEXIT RIH. ITIE IN DEPTH,DRY TAG WHIPSTOCK AT 10 691 FT. ♦• t�� 18:00 - 00:00 6.00 STWHIP P WEXIT MILL2.74"WINDOW IN 3-1/4"LINER PER J BAKER REP AND WELL PLAN. ' r)- 3C, 3 -MILL WINDOW FROM 10,690.6 TO 10,695.4 FT THEN MILL RATHOLE TO 10,705.5 FT. MUD WEIGHT: 9.52 PPG IN,9.48 PPG OUT DWOB AROUND 2.5K WHILE MILLING WINDOW,1K DURING RATHOLE. CIRC PRESSURE 3700 PSI OFF BOTTOM. 9/14/2016 00:00 - 02:00 2.00 STWHIP P WEXIT REAM WINDOWAT 1 FT/MIN. NO MOTOR WORK SEEN ON ANY OF THE PASSES. -REAM DOWN AT 30R TF(AS MILLED). -REAM UP,3 PASSES AT: AS MILLED,+15 I DEG,-15 DEG TF. -RATE:1.80 BPM IN,1.80 BPM OUT -PU:30K,SO:20K -SHUT DOWN PUMPS,DRY DRIFT WINDOW AS MILLED TF,NOTHING SEEN -BLEED OA FROM 900 PSI TO ZERO,BLEED IA 200 PSI TO ZERO. -10 MIN DYNAMIC FLOW CHECK AT WINDOW IS GOOD -PUMP 10 BBLS HI-VIS SWEEP AROUND. 02:00 - 03:30 1.50 STWHIP P WEXIT POOH 1-MUD WEIGHT:9.51 PPG IN,9.48 PPG OUT -RATE:2.14 BPM IN,1.67 BPM OUT -OPEN EDC,POH FROM 10,650'MD TO 200' IMD -RATE:2.14 BPM.CIRC PRESSURE:3,470 PSI 03:30 - 04:20 0.83 STWHIP P WEXIT AT SURFACE,10 MIN PUMPS OFF FLOWCHECK IS STATIC. -REMOVE INJECTOR,OFF AT 03:40. -L/D MILLING BHA. MILLAND STRING REAMER GAUGE IS 2.74 GO 2.73 NO GO 04:20 - 04:55 0.58 DRILL P PROD1 MAKE UP DRILLING BHA#4 -PICK UP(0.98 DEG AKO)AND COILTRAK !TOOLS -MAKE UP 3.25"<HYC DURAFORCE XD> BICENTER BIT -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS -INJECTOR ON:04:45 04:55 - 06:45 1.83 DRILL P PROD1 RIH 06:45 - 07:30 0.75 DRILL P PROD1 PERFORM LONG TIE IN FOR GEO 07:30 - 07:45 0.25 DRILL P PROD1 CORRECT DEPTH-8'AND RIH TO START DRILLING Printed 10/3/2016 4:09:20PM `AII depths reported in Drillers Depths* Tri= Flus = ..... ... • NOTES: ORIGINAL ° ATORBAKERC 15-33B a, „ W &S � � OKB aEV= 69.6' NOT SHOWN"' TAIL 1994 REF ELEV= 69.6' I I ST,IS SOPA " r WS @ 10350'." BF.ELEV= 33.5,': KOP= 2522' Max Angle= 950 @ 12391 2204' —4-1/2'CAAACO TRDP-4A SSSV NP,D=3,855" Datum MD= 12317'! • LOCKED OUT(12/18/11) 120'CONDUCTOR,91.5#,H-40,D=19.124" — 112' GAS LFT MAACRELS 13-3/8'CSG,68#,PIT-80 CY I-E ID=12.415' — 3603' I ST MD ME TVD DFV TYPE V LV LATCH FORT DATE 1 3023 3001 19 OTIS DOT2 16 "04/21/16 Minimum ID =2.377" 10948' 2 5165 4997 22 OTIS SO T2 20 04/21/16 3 7055 6703 37 OTIS DMY T2 0 05/11/14 3-3/16" X 2-78" XO 4 9405 8142 57 OTIS DMY' T2 0 10/05/03 9-5/8'CSG,47#,NT-80 NSCC,D=8.681" — 9683' i 9520' }--9-5/8'X T TWW LTP&LNR HGR,D=? } 1007T —3.70 BKR DEPLOY SLV,I)=3.00" 10096' —3-1/2"HES X NP,ID-2.813' 3-1/71_142,8.61#,L-80 STL,.0081 bpf,D=2.880' — 10127' �--- 1012T -{3-1/2'X3-3/16'XO,D=2,786' € 10138' ]H -1/2"OTIS X PP,D=3.813' 4-1/2'TBG, 12.6#.L-80 NSCT,.0152 bpf,D=3.958' — —10155' E. 10155 —7'X 4-1/Y BKR SABL-3 PKR BEHIND x [ CTLNR ML LOUT WWDOW(15-33B) 10354'- 10360' 7'LIQ 26#,L-80 NSCT,.0383 bpf,I)=6.276" —1 10246' 1—x TOP OFWHPSTOCK H 10350'^\ 10690' H3-3/16'WI-PSTOCK(09/16/16) 7"LAIR,26#, 13CR-80 NSCT,.0383 bpf,13=6.276" }— —10360 10767' —BKR 003 C8P(09/04/16) ORATION StR A ARY .;.;.;.;������� •/ 1081 T }-3.3/16'HES C 8 P(06/22/11) WetetsteV FE LOG: ANGLE AT TOP PERF: 73'@ 10791' Ile41110818' 3-3116'X 2-78"XO,D=2.37T Note:Refer to Ptoductior 0B for historical perf data SIZE SPF t4TERVAL Opn/Sgz SHOT SQZ 2' 6 10791 -10806 C 06/23/11 11030' _—2-7/8'HAL CI3P 2' 6 10830-10855 C 06/24/10 Sp (06/24/10) 2' 6 10885- 10905 C 01/21/09 2' 4 10926- 10973 C 01/08/04 3-3/16"LIQ 6.2#,L-80 TC11, — 10948' St 2' 4 11196- 11345 C 01/08/04 .0076 bpf,ID=2.805" ` 2" 4 11378-11473 C 01/08/04 2" 4 11506- 11580 C 01/08/04 Six, 2' 4 11634-11698 C 01/08/04 ". PBTD — 12658' 2' 4 11719- 11787 C 01/08/04 2' 4 11901 - 11929 C 01/08/04 2' 4 11969-1204.9 C 01/08/04 2-7/8'LTJ,6.16#,L-80 STL,.0055 bpf,D=2.377" — 12699' 2" 4 12079-12189 C 01/08/04 2" 4 12380-12420 C 01/08/04 2' 6 12460-12485 C 01/20/09 2' 4 12590-12650 C 01/08/04 - DATE REV BY COMANTS DATE REV BY COMABNTS FRLDHOE BAY UNIT 03/31/94 D-9 ORIGINAL COMPLETION 0422/16 TBDIJAAD RULED WRP(04/20/16) WELL: 15-33B 08/13/99 N4/3E'S SIDETRACK(15-33A) 04/25/16 TBD'JMD GLV 00(04/21/16) PERMT No:`1031940 01/09/04 NORDIC 1 CTD SIDETRACK(15-33B) 09/07/16 CJS/JMD SET BKR CBP(09/04/16) API No: 50-029-22448-02 10/02/15 JMG/JMD SET MP(09/30/15) 10/10/16 JMJTLH M-t STOCK SET(09/13/16 ON RIG) SEC 22,T11 N,R14E,560'FTL&106'PML 03/08/16 CRR/JMD EDITED TBG TAL 10/10/16 JNJTLH REF ELEV&BF E UPDATE 04/11/16 JAO REVIEWED WBS BP Exploration(Alaska) OF rip, • • 1/ 7 THE STATE Alaska Oil and Gas �, of f A �C' Conservation Commission iJi iV 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^•? Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin SCANNED SEP 2,8 2016 Engineering Supervisor BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-33B Permit to Drill Number: 203-194 Sundry Number: 316-279 Dear Mr. McLaughlin: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Cathy P oerster Chair DATED this day of May, 2016. RBDMS 1,t.- WI( 3 1 2016 STATE OF ALASKA ' •ALASKA OIL AND GAS CONSERVATION COMM411!)N APPLICATION FOR SUNDRY APPROV�S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill El. Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 203-194 Exploratory 0 Development p- 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-22448-02-00 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No IZI PBU 15-33B FRO 9. Property Designation(Lease Number): 10. Field/Pools: �t j C ADL 028306 . PRUDHOE BAY,PRUDHOE OIL - MAY 1 8 2fl i6 11. PRESENT WELL CONDITION SUMMARY 975 SI / Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ✓ Plugs(MD): <A' • • 12699 8842 , 10041 8496 2493 10041,10817,1103 None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 39-119 39-119 1490 470 Surface 3568 13-3/8" 38-3607 38-3546 5020 2260 Intermediate 9832 9-5/8" 36-9868 36-8396 6870 4760 Liner 834 7" 9520-10354 8204-8650 7240 5410 Liner 2622 3-1/2"x3-3/16"x2-7/8" 10077-12699 8516-8842 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10791 -12650 8796-8843 4-1/2"12.6#L-80 L-80 34-10164 Packers and SSSV Type: 4-1/2"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 10158/8561 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary Il Wellbore Schematic El 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch El Exploratory 0 Stratigraphic 0 Development RI - Service 0 14.Estimated Date for Commencing Operations: June 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended l 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Browning,Zachary H be deviated from without prior written approval. Email Zachary.Browning@bp.com Printed Name Sean McLaughlin Title Engineering Supervisor Signature S r- P i l (`- Phone +1 907 564 4387 Date Si t,7/ 6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test t! Mechanical Integrity Test 0 Location Clearance 0 Other: [BOP 1-c51 -f-o 3570 0 p S '' G `J' 1Post Initial Injection MIT Req'd? /Yes No Ir" rpvt / Spacing Exception Required? Yes 0 No 2 Subsequent Form Required: /Q _ 40,'7 SApproved by: /7 APPROVED BYTHE COMMISSIONER COMMISSION Date: -1 27--/6a 41$1_, 5726/HD ORIGINAL RBDMS t,L' MAY 3 1 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • i To: Alaska Oil & Gas Conservation Commission bp From: Zach Browning CTD Engineer Date: May 16, 2016 Re: 15-33B Sundry Approval Request Sundry approval is requested to plug the 15-33B perforations as part of the preparation, drilling and completing the proposed 15-33C coiled tubing sidetrack. History of 15-33B: 15-33B was completed as a CTD sidetrack in 2004 targeting reserves in Z1A/1 B sand in the NW portion of DS 15. After just under a year the well was shut in due to marginal production and high gas. It was cycled and two perf intervals added with minimal production. In 2009 a CIBP was set above the perfs and heel perforations were added. This initially had good results but the well • gassed out by 2011. Unfortunately the well is no longer competitive and has no future weliwork • options. The well passed integrity screening and is fit for sidetrack. Proposed plan for 15-33C: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around October 1st, 2016. A packer whipstock will be set with the rig isolating the 15-33B perforations and allowing a 2.74"window to be milled through the 3-3/16" liner. The well kicks-off in Zone 2A, and will land at the base of Zone 1 targeting reserves in Zone 1A/1 B on the western part of DS-15. The proposed sidetrack is a -2500' horizontal Ivishak producer to be completed with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated. This Sundry covers plugging the existing • 15-33B perforations via the packer WS, the liner cement iob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). 1 The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. d N.,' ,•' Nr t Pre-Rig Work(scheduled to begin June 15 .2016) 1 d 1. C Drift for WS h ', 2. S Set LGLVs o b � , . s �a 3. V Pre-CTD tree work. Set TWC. a +- I-14AS ..4o �� � Rig Work(scheduled to begin October 14Y,2016} 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,493 psi). 2. Set a 3-3/16" Packer Whipstock. Z. 3. Mill 2.74"window+ 10' of rathole. ,''`� 4. Drill Build and Lateral: 3.25" OH, 2510' (12 deg DLS planned) 3 ' 0 5. Run 2-3/8" L-80 liner leaving TOL at-10,050' MD. ! O d 6. Pump primary cement job: 18.7 bbls, 15.3 ppg Class G, TOC at TOL(10,050' D).* rt \ 7. Perform Cleanout/Logging run with GR/CCL/RPM. "kR is 8. Perform liner lap test to 2400 psi. � - p 9. Perforate -1000' based on log interpretation. Jk Ct"./ o ® d- 10. Freeze protect well to a min 2,200'TVDss. i2 l0 3 y ` 11. Close in tree, RDMO. -\ '' .. I S L *Approved alternate plug placement per 20 AAC 25.112(i) J . y Ci • • Post-Rig Work: 1. 0: Re-install wellhouse, and flowline if needed. 2. V: Tree work as necessary. 3. S: LTP set post rig if needed and test.* 4. C: N2 lift to POP well if needed. ASRC flowback. Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 ELLFEAD= aW 15-33B SAFETY NOTES: WELL ANGLE>700@ 10503 CTIWTOIZ= BAKES C • 7"LIR ORIGINAL&SIDETRACK"A" I .BEV= 69.6' NO N'*'TBG TAIL FELL OFF BEFORE 1994 _.H.EV= I ( ST.IS SOMEWHERE BELOW 7"WS @ 10350'." DP= 2522'', ax Angle= 95°@ 12391' tum MD= 12317' 2204' -4-1/2"CA MCO TRDP 4A SSSV NP,D=3.$55" gum TVD= 8800'SS' LOCKED OUT(12/18/11) 20"CONDUCTOR 91.5#,H-40,D=19.124" 112' GAS LFT MANDRELS 7471.1 13-3/8"CSG,68#,NT-80 CY HE,D=12.415" H 3603' ST IA) ND DEV TYPE VLV LATCH FORT DATE 1 3023 3001 19 0115 DMY RA 0 08/12/11 2 5165 4997 22 OTIS DMY T2 0 08/12/11 Minimum ID =2.377" @ 10948' 3 7055 6703 37 OTIS MAY T2 0 05/11/14 3-3/16" X 2-7/8" XO 4 9405 8142 57 OTIS DMY T2 0 10/05/03 9520' -9-5!8"X 7-11W LIP&LM HCR D=? 9-5/8"CSG,47#,NT-80 NSCC,i)=8.681" --I 9683' L10041' --{4-1/2"WFD WRP(09/30/15) 1111.-01111 10077' 3.70 BKR DEPLOY SLV,D=3.00" 10096' H3-1/2"I-ES X NP,D-2.813" 3-1/2"LAR 8.81#,L-80 STL,.0081 bpf,D=2.880" 10127' 10127' -13-1t2"X 3-3/16"XO,D=2.786" I I 10138' -14-1/2"OTIS X A6?D=3.813" 4-1/2"TBG, 12.6#,L-8ONSCT,.0152 bpf,D=3.958" I-1 -10155' —g $ 10155' -i 7"X 4 1/2"BKR SABL-3 PKR BEH IND CTLNR 7"LNR,26#,L-80 NSCT,.0383 bpf,D=6.276" -{ 10246' 1-x 1F TOP OF WI N , \ IOCK 10350' MLLOUT WIDOW(15-33B) 10354'-10360' 7"LAR 26#,13CR 80 NSCT,.0383 bpf,D=6.276" -1 -10360 ` 10817' -I3-3/16'FES CBP(06/22/11) PERFORATION SUMMARY ';•;•;•;•;•;9 REF LOG: 4. 10948' -13-3116"X 2-718"XO,D=2.377' ANGLE AT TOP PERF: 73°@ 10791' Note:Refer to Production DB for historical perf data SCE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 10791-10806 0 06/23/1111030' 2-7/8"HAL CB 2" 6 10830-10855 C 06/24/10 y So (06/24/10) 2" 6 10885- 10905 C 01/21/09 2" 4 10926-10973 C 01/08/04 3-3/16"LM,6.2#,L-80 TC11, - 10948' 2" 4 11196-11345 C 01/08/04 .0076 bpf,13=2.805" 2" 4 11378-11473 C 01/08/04 2" 4 11506-11580 C 01/08/04 ,.. 2" 4 11634-11698 C 01/08/04 2' 4 11719-11787 C 01/08/04 PBTD 12656' 2" 4 11901-11929 C 01/08/04 2" 4 11969-12049 C 01/08/04 2-7/8"LNf2,6.16#,L-80 STL,.0055 bpf,D=2.377" 112699' - 2" 4 12079-12189 C 01/08/04 2" 4 12380-12420 C 01/08104 2" 6 12460- 12485 C 01/20/09 2" 4 12590-12650 C 01/08/04 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/31/94 D.9 ORIGINAL COMPLETION 05/19/14 RS/JM) GLV GO(05111/14) WELL: 15-33B 08/13/99 N4/3ES SIDETRACK(15-33A) 10/02/15 JMG/JM3 SET WRP(09/30/15) PERNITNo: 2031940 01/09104 NORDIC 1 CTD SIDETRACK(15-33B) 03/08/16 CRR/JM? EDITED TBG TAL AR No: 50-029-22448-02 '09/21/11 DLK/PJC SUP STOP GSUB SET(8/12/11) SEC 22,T11N,R14E,560'FAL&106'FWL 12/10/11 TA!PJC PULL CS/LOCK OUT TRSSSV 04/21/14 TTR/JMD RLL BKR LIP(03/21/14) BP Exploration(Alaska) IELLI-EAD= CNV= BANOTES: WELL ANGLE>70*@ '*" C1 AT01BAKERC 15-33C S H I .ELEv= 69.6' P R O P O S� CH E 7"LNR'*`TBG TAIL FELL ole BORE 1994 I BEV_ 2 ' ST.IS SOMEWHERE BELOW 7"WS @ 10350'." F.BEV= 2527 2204' 4-1/Z CAMCO TRDR4A SSSV NP,D=3.85` 20-COND,91.5#, H 112' LOCKED OUT(12/18/11) ax Angle= 95"@ 12391' 13-40,D=19.124" atum MD= 12317' GAS LFT MANDRELS atumND= 8800'SS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3023 3001 19 OTIS DMY RA 0 08/12/11 13-3/8"CSG,68#,NT-80 CY t D=12.415" H 3603' --, ' 2 5165 4997 22 OTIS DMY 7'2 0 08/12/11 3 7055 6703 37 OTIS DMY T2 0 05/11/14 4 9405 8142 57 OTIS DMY 12 0 10/05/03 Minimum ID =XX" @ XXXXX' 9520' --i 9-5/8"X 7"TW LTP 8 LNR HGR,D=? 9-5/8"CSG,47#,NT-80 NSCC,D=8.681" 9683' 10050` —�3.70"SCOOP GLADE (2-3/8"T0UT0C! `__/_i --{ 10050' / 10050' 2.70"D�'I_OY MEW sLV,D=2.00• 10077' H3.70 SKR DEPLOY SLV,D=3.00" 1 1 r 100%' H3-1/2"HES X NP,D-2.813" 3-1/2"LNR,8.81#,L-80 STL,.0081 bpf,D=2.880" — 10127' .-----,` 10127' H3-1/2"X 3-3/16"X0,D=2.786" I F--------4 10138' H4-1/2"OTIS X NP,D=3.813' BEHIND 4-1/2"TBG, 12.6#,L-80 NSCT,.0152 bpf,D=3.958" —I ^-10155'= g— 10155' +H7"X 4-1/2"BKR SABL-3 PKR CT LNR 7"LNR,26#,L-80 NSCT,.0383 bpf,D=6.276" — 10246' —>< x MLLOUT WINDOW(15-338) 10354'-10360' TOP OF WHIPSTOCK —I 10360' "LNR,26#,13CR-80 NSCT,.0383 bpf,ID=6.276" H I —10350' 3-3/16'WHIPSTOCK(_/ /_i -1 10690' • MLLOUT WNDOW(15-33C) 10690'--10700' • 3-3/16'LNR,6.2#,L-80 TC11, H -10690' .0076 bpf,D=2.805' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: XX"©XXXOC Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT 507 PBTD —{ • 2-3/8'LNR, #,L-80 H51, bpf,D= ' H 13200' 1-2ii DATE REV BY COMMENTS DATE REV BY COMM NTS PRUDHOE BAY UNTf 03/31/94 D-9 ORIGINAL COMPLETION WELL: 15-33C 08/13/99 N4/3ES SIDETRACK(15-33A) ' FERMT No: r 01/09/04 NORDIC 1 CTD SIDETRACK(15-33B) AR No: 50-029-22448-05 __/ /_ CTD SIDETRACK(15-33C) -- SEC 22,T11N,R14E,560'FNL 8106'ANL 04/11/16 JMD BOLT RTOPOSAL BP Exploration(Alaska) .. ! ! _ _ _ y r I 1 I fa .., , • I 3 I > % I 1 o U a 6 --—— - I w J S i s I, m o m 1 m I Mil I / d1 T ^ - d = ' al CI 1 .. x 1 -F. . I J I a - . a i I = G r.j: : $ G / =1 i a e + i I • I Q 4 1 1 8 S dab t I s� ow 1 I 1 § / my,J N r m r 'sx§> 1 I ' .. _ Am-m I °.4 1 / '' Sidi / I .... 1 11 2 mm n> I I I I 1 1 r Q 1° H I;' I i _ _ y1 I t;0 a II, I O 4,— I w H w ' I I Um I U U U f I Z • I o I -I 1 1 • _,-___?) y siii , iii `'i1 1 _7.z.,, Wt. ____, 1 1,. g i 4 I Z I 8 \ H• ` u _ • Q vl` a.„a..e seg - - 1 J f f 1i II .g I i ♦ • . I Ct . I I ` \ UU • F I 0— 1I \r,, \ : I 2.I ilEF y W 0�,�', I _ x y I \ \ _> 1 \ \ u /?, i I =_ � � jZ I \ I al n. F i:,; /Iri O '• —op- 4 iala = \\ of y Ny x x v c °. A It ¢ U F— 11111 a tN I” . S m x Uf lh4e/all& o €; _., I 1_ o a . _ i r \ i N �� U O O177— I x �I o�!� } I Z f m _ I Ark I I Utc a a I a 2m f R Z u _. c u i is oa - g I 2 a LL U I = E II g 2° m u R I U u ' : F. m33 1 — E 11 I -1 z E 1 0 .. E� x I I I._ q8 a x x a - • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the"Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the"Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July,the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. s STATE OF ALASKA ALASKAIDAND GAS CONSERVATION COMMISSICID REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ..AM Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate n 1 .% ,. Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 203 -194 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 22448 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028305 s PBU 15 -33B 10. Field /Pool(s): . PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12699 feet Plugs (measured) 10817, 11030 feet true vertical 8842 feet Junk (measured) None feet Effective Depth measured 12656 feet Packer (measured) 9520 10069 10155 feet true vertical 8843 feet (true vertical) 8204 8512 8559 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34 - 112 34 - 112 1490 470 Surface 3570' 13 -3/8" 33 - 3603 33 - 3543 5020 2270 Production 9651' 9 -5/8" 32 - 9683 33 - 8292 6870 4760 Liner 808' 7" 9520 - 10360 8204 - 8652 7240 5410 Liner 58' 3 -1/2" 10069 - 10127 8512 - 8544 Liner 58' 3 -1/2" 10069 - 10127 8512 - 8544 Liner 821' 3- 3/16" 10127 - 10948 8544 - 8839 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ - True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 30 - 10354 30 - 8650 Packers and SSSV (type, measured and true vertical depth) 7" TIW Liner To Packer 9520 8204 3 -1/2" Baker KB To Packer - 10069 8512 4 -1/2" Baker SAB -3 Packer 10155 8559 12. Stimulation or cement squeeze summary: Intervals treated (measured): P jUL 1 3 2011 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 497 34286 0 1347 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 — Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager ! / Signature L Phone (907) 564 -5674 Date 7/12/2011 Form 10 -404 Revised 10/2010 RBDMS JUL 13Z01 ��1 7 /31>0 /�� �' bmit Original Only 15 -33B . 203 -194 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15 -33B 1/8/04 PER 10,926. 10,973. 8,833.77 8,843.94 15 -33B 1/8/04 PER 12,590. 12,650. 8,842.78 8,842.79 15 -33B 1/8/04 PER 12,079. 12,189. 8,846.74 8,847.91 15 -33B 1/8/04 PER 11,969. 12,049. 8,839.72 8,846.15 15 -33B 1/8/04 PER 11,901. 11,929. 8,834.7 8,836.36 15 -33B 1/8/04 PER 12,380. 12,420. 8,848.31 8,844.99 15 -33B 1/8/04 PER 11,634. 11,698. 8,832.18 8,831.7 15 -33B 1/8/04 PER 11,506. 11,580. 8,834.9 8,833.98 15 -33B 1/8/04 PER 11,378. 11,473. 8,832.7 8,833.82 15 -336 1/8/04 PER 11,719. 11,787. 8,832.32 8,832.79 15 -336 1/8/04 PER 11,196. 11,345. 8,838.36 8,834.57 15 -33B 6/18/07 BPS 9,978. 12,650. 8,459.7 8,842.79 • 15 -33B 7/2/07 BPP 9,978. 12,650. 8,459.7 8,842.79 15 -33B 1/20/09 APF 12,460. 12,470. 8,842.56 8,842.29 15 -33B 1/20/09 APF 12,470. 12,485. 8,842.29 8,842.16 15 -33B 1/21/09 APF 10,885. 10,905. 8,822.97 8,828.37 15 -33B 6/24/10 APF 10,830. 10,855. 8,807.34 8,814.55 15 -336 6/24/10 BPS 11,030. 12,650. 8,846.64 8,842.79 15 -336 6/22/11 BPS 10,817. 11,030. 8,803.61 8,846.64 15 -33B 6/23/11 APF 10,791. 10,806. 8,796.16 8,800.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 15 -33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY Agriwyptsix ,12314111 6/22/2011 CT -8 1 3/4" SCOPE OF WORK: Drift/depth log, set CIBP, add 15' perfs. Finish WEEKLY BOP TEST, MIRU on 15 -33B, MU & run PDS 2.2" carrier & GR/CCL memory logging /Drift assembly w/2.3" Noz. TOL 16.28'. Drift for Hal CIBP '2.281" OD. Thru LT no indication. Good data on log, +16' correction. Set Hal MAPS CIBP @ 10817', Csg collar @ 10813'. RIH w/ 15' perf gun. Continued on 6/23/11 6/23/2011! CTU #8 w/ 1.75" CT ;Scope: Log /drift, CIBP, add 15' perfs Finish RIH w/ pert gun and perforate 10791 - 10806' w/ SWS 2" guns at 6 spf w/ PJ2006 HMX charge. POH. RDMO to SWS yard for planned maintenance and reel swap Job complete FLUIDS PUMPED BBLS 56 50/50 METH 197 1% XS KCL 253 TOTAL TREE = FMC WELLHEAD = CM/ SAFETY NOT WELL ANGLE> 70 @ 10503' * ** ACTUATOR = BAKER C 15-33B CHROME 7" LNR * ** ORIGINAL & SIDETRACK "A" KB. ELEV = 69.6' NOT SHOWN BF. ELEV = KOP = 2522' Max Angle = 95° @ 12391' Datum MD = 12317' 2204' I 4 -1/2" CAMCO TRDP -4A SSSV NIP, ID = 3.855" Datum TVD = 8800' SS 0 LOCKED OUT (08/01/05) 120" CONDUCTOR, 91.5 #, H -40, ID = 19.124" H 112' GAS LIFT MANDRELS 113 -3/8" CSG, 68 #, NT -80 CYHE, ID = 12.415" H 3603' 1 — , 1 1ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3023 3001 19 OTIS DOME RA 16 01/19/04 Minimum ID = 2.377" 10948' 2 5165 4997 22 OTIS SO T2 20 01/19/04 3 7055 6703 37 OTIS DMY T2 0 10/05/03 3-3/16" X 2 -7/8" XO 4 9405 8142 57 OTIS DMY T2 0 10/05/03 . , 9520' H9-5/8" X 7" TW LTP & LNR HGR, ID = ? I 9 -5/8" CSG, 47 #, NT -80 NSCC, ID = 8.681" H 9683' 1 10069' 1-13.70" BKR KB LTP, ID = 2.560" 2 I 10077' 1 BKR DEPLOY SLV, ID = 3.00" I 10096' H3 -1/2" HES X NIP, ID- 2.813" 13-1/2" LNR, 8.81 #, L -80 STL, .0081 bpf, ID = 2.880" H 10127' 1-- ' 10127' I- -13 - 1/2" X 3- 3/16" XO, ID = 2.786" I N II 1 10138' H4 -1 /2" OTIS X NIP, ID = 3.813" 1 g� 10155' 1 ---17" X4 -1/2" BKRSABL -3 PKR 1 BEHIND E 1 10186' H4- 1 /2 " OTIS X NIP, ID= 3.813 1 CT LNR I I I 10203' H4 -1/2" OTIS XN NIP, ID = 3.725" I (7" LNR, 26 #, L -80 NSCT, .0383 bpf, ID = 6.276" H 10246' 1 >< ITOP WHIPSTOCK 1-1 10350' MILLOUT WINDOW (15 -33B) 10354' - 10360' I4 -1/2" TBG, 12.6 #, L- 8ONSCT, .0152 bpf, ID= 3.958" 1-1 -10350 I 7" LNR, 26 #, 13CR -80 NSCT, ,0383 bpf, ID = 6.276" I—I -10360 1—' PERFORATION H■��j■j�j 1081 T 1 — I 3- 3/16" HES CEP (06/22/11) 1 ERFORATION SUMMARY REF LOG: / 10948' — 3/16" X 2 -7/8" XO, ID = 2.377" I ANGLE AT TOP PERF: 73° @ 10791' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 10791 - 10806 0 06/23/11 A r I 11030' 1 HAL CIBP 2" 6 10830 - 10855 C 06/24/10 (06/24/10) 2" 6 10885 - 10905 C 01/21/09 2" 4 10926 - 10973 C 01/08/04 3- 3/16" LNR, 6.2 #, L -80 TC11, 10948' 1 2" 4 11196 - 11345 C 01/08/04 .0076 bpf, ID = 2.805" 2" 4 11378 - 11473 C 01/08/04 2" 4 11506 -11580 C 01/08/04 `k 2" 4 11634 - 11698 C 01/08/04 I PBTD 1-1 12656' 2" 4 11719 - 11787 C 01/08/04 2" 4 11901 - 11929 C 01/08/04 2" 4 11969 - 12049 C 01/08/04 1 2 -7/8" LNR, 6.16 #, L -80 STL, .0055 bpf, ID = 2.377" 12699' 1 2" 4 12079 - 12189 C 01/08/04 2" 4 12380 - 12420 C 01/08/04 2" 6 12460 - 12485 C 01/20/09 2" 4 12590 - 12650 C 01/08/04 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/31/94 D -9 ORIGINAL COMPLETION 07/03/07 BSE/PJC FISH TOOL STRING (06/16/07) WELL: 15 -33B 08/13/99 N4 /3ES SIDETRACK(15 -33A) 02/05/09 RLM/SV ADPERFS(01 /21/09) PERMITNo: 01/09/04 NORDIC 1 CTD SIDETRACK (15 -33B) 06/27/10 DBM/PJC ADPERFS/ CIBP (06/24/10) API No: 50- 029 - 22448 -02 01/19/04 JBM/KAK GLV C/0 06/25/11 CJS/ PJC CIBP/ ADPERF (06/22 - 23/11) SEC 22, T11 N, R14E, 560' FNL & 106' FWL 05/02/04 TI-I/KAK CASING DEPTH CORRECTIONS 06/25/11 PJC DRAWING CORRECTIONS 06/05/07 RCT /PAG FISH @ 9161' + CORRECTION BP Exploration (Alaska) STATE OF ALASKA v a ALASKAOAND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate el Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ID Exploratory ❑ ■ 203 -1940 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 4 50- 029 - 22448 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028305 .- PBU 15 -33B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12699 feet Plugs (measured) 11030, 10817 feet true vertical 8841.73 feet Junk (measured) None feet Effective Depth measured 12666 feet Packer (measured) 10069 10155 feet true vertical 8842.47 feet (true vertical) 8512 8559 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 34 - 114 34 - 114 1490 470 Surface 3570' 13 -3/8" 68# NT -80 33 - 3603 33 - 3543 5020 2270 Production 9681' 9 -5/8" 47# NT -80 32 - 9683 32 - 8292 6870 4760 Liner 726' 7" 26# L -80 9520 - 10246 8204 - 8604 7240 5410 Liner 104' 7" 26# 13CR80 10246 - 10350 8604 - 8648 7240 5410 Liner 58' 3 -1/2" 8.81# L -80 10069 - 10127 8512 - 8544 Liner 821' 3- 3/16" 6.2# L -80 10127 - 10948 8544 - 8839 Liner 1751' 2 -7/8" 6.16# L -80 10948 - 12699 8839 - 8842 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - - _ - True Vertical depth: _ , S N JUL 1 3 0 I Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 30 - 10354 30 - 8650 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker KB To Packer 10069 8512 4 -1/2" Baker SAB -3 Packer 10155 8559 12. Stimulation or cement squeeze summary: ; E ; i f fI I Intervals treated (measured): Treatment descriptions including volumes used and final pressure: l c. z i 8 l'og (,dos. (- ,9id1ITHSSlOf) ATKV,rilige 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 576 43,399 8 1,096 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil IS Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - oe Last AI. ( Title Petrotechnical Data Technologist Signatur: liumi Phone 564 -4091 Date 7/11/2011 Form 1,, r Roviso• •, 110 " : ii MS JUL t 1 I 201 Submit Original Only N I. 7 /( I/ / 15 -33B 203 -194 " PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15 -33B 1/8/04 PER 10,926. 10,973. 8,833.77 8,843.94 15 -33B 1/8/04 PER 12,590. 12,650. 8,842.78 8,842.79 15 -33B 1/8/04 PER 12,079. 12,189. 8,846.74 8,847.91 15 -33B 1/8/04 PER 11,969. 12,049. 8,839.72 8,846.15 15 -33B 1/8/04 PER 11,901. 11,929. 8,834.7 8,836.36 15 -33B 1/8/04 PER 12,380. 12,420. 8,848.31 8,844.99 15 -33B 1/8/04 PER 11,634. 11,698. 8,832.18 8,831.7 15 -33B 1/8/04 PER 11,506. 11,580. 8,834.9 8,833.98 15 -33B 1/8/04 PER 11,378. 11,473. 8,832.7 8,833.82 15 -33B 1/8/04 PER 11,719. 11,787. 8,832.32 8,832.79 15 -33B 1/8/04 PER 11,196. 11,345. 8,838.36 8,834.57 15 -33B 6/18/07 BPS 9,978. 12,650. 8,459.7 8,842.79 411 15 -33B 7/2/07 BPP 9,978. 12,650. 8,459.7 8,842.79 15 -33B 1/20/09 APF 12,460. 12,470. 8,842.56 8,842.29 15 -33B 1/20/09 APF 12,470. 12,485. 8,842.29 8,842.16 15 -33B 1/21/09 APF 10,885. 10,905. 8,822.97 8,828.37 15 -33B 6/24/10 APF 10,830. 10,855. 8,807.34 8,814.55 15 -33B 6/24/10 BPS 11,030. 12,650. 8,846.64 8,842.79 15 -33B 6/22/11 BPS 10,817. 11,030. 8,803.61 8,846.64 15 -33B 6/23/11 APF 10,791. 10,806. 8,796.16 8,800.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . 15 -33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ,PATS _� 0 4 4 a 6/22/2011'CT -8 1 3/4" SCOPE OF WORK: Drift/depth log, set CIBP, add 15' perfs. Finish WEEKLY BOP TEST, MIRU on 15 -33B, MU & run PDS 2.2" carrier & GR/CCL memory logging /Drift assembly w/2.3" Noz. TOL 16.28'. Drift for Hal CIBP 2.281" OD. 'Thru LT no indication. Good data on log, +16' correction. Set Hal MAPS CIBP @ 10817', Csq collar (7a 10813;. RIH w/ 15' pert gun. !Continued on 6/23/11 6/23/2011 CTU #8 w/ 1.75" CT Scope: Log /drift, CIBP, add 15' perfs Finish RIH w/ pert gun and perforate 10791 - 10806' w/ SWS 2" guns at 6 spf w/ PJ2006 HMX charge. POH. RDMO to SWS yard for planned maintenance and reel swap ;Job complete 3 , FLUIDS PUMPED BBLS 197 1% XS KCL 56 50/50 METH 253 TOTAL TREE = FMC III , WELLHEAD = CNV SAFETY NOT ELL ANGLE > 70° @ 10503' * ** ACTUATOR = BAKER C 1 5-33 B CHROME 7" L R*** ORIGINAL & SIDETRACK "A" KB. ELEV = 69.6' NOT SHOWN *** BF, ELEV = i 1 KOP = 2522' Max Angle = 95° @ 12391' Datum MD = 1231f 1 2204' I— 4 -1/2" CAMCO TRDP -4A SSSV NP, ID = 3.855" Datum TVD = 8800' SS LOCKED OUT (08/01/05) 120" CONDUCTOR, 91.5 #, H -40, ID = 19.124" H 112' GAS LIFT MANDRELS 1 13 -3/8" CSG, 68 #, NT -80 CYHE, ID = 12.415" H 3603' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3023 3001 19 OTIS DOME RA 16 01/19/04 Minimum ID = 2.377" 10948 2 5165 4997 22 OTIS SO T2 20 01/19/04 3 7055 6703 37 OTIS DMY T2 0 10/05/03 3 -3/16" X 2 -7/8" XO 4 9405 8142 57 OTIS DMY T2 0 10/05/03 1 9 -5/8" CSG, 47 #, NT -80 NSCC, ID = 8.681" H 9683' 1 fl 9520' H9-5/8" X 7" TIW LTP & LNR HGR, ID = ? 1 10069' H3.70" BKR KB LTP, ID = 2.560" I 1 I 10077' 1 - 13.70 BKR DEPLOY SLV, ID = 3.00" 1 1 10096' 1 13 -1/2" HES X NIP, ID- 2.813" 1 13 1/2" LNR, 8.81 #, L -80 STL, .0081 bpf, ID = 2.880" 1—I 10127' 1 I 10127' 1-13 -112" X 3- 3/16" XO, ID = 2.786" 1 1 10138' H4-1/2" OTIS X NIP, ID = 3.813" 1 10155' H z ►v,1 7" X4 -112" BKRSABL -3 PKR I BEHIND s 10186' 1 -1/2" OTIS X NIP, ID = 3.813" 1 CT LNR III 10203' H4 -1/2" OTIS XN NIP, ID = 3.725" 1 1 17" LNR, 26 #, L -80 NSCT, .0383 bpf, ID = 6.276" 1-) 10246' 1->< 1 TOP OF WHIPSTOCK H 10350' MILLOUT WINDOW (15 -33B) 10354' - 10360' 14 -1/2" TBG, 12.617, L- 8ONSCT, .0152 bpf, ID = 3.958" 1-1 -10350 -. 17" LNR, 26 #, 13CR -80 NSCT, .0383 bpf, ID = 6.276" H -10360 1- L ✓ 1 1 10817' 3- 3/16" HES CIBP (06/22/11) 1 PERFORATION SUMMARY ∎• ∎• ∎• ∎• ∎• ∎��� REF LOG: / 10948' - 3- 3/16" X 2778" XO, ID = 2.377" ANGLE AT TOP PERF: 73° @ 10791' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE , 2" 6 10791 - 10806 0 06/23/11 V 1 11030' 1-12-7/8" HAL CIBP 2" 6 10830 - 10855 C 06/24/10 r 1 (06/24/10) 2" 6 10885 - 10905 C 01/21/09 2" 4 10926 - 10973 C 01/08/04 3- 3/16" LNR, 6.2 #, L -80 TC11, 10948' 1 ♦ 2" 4 11196 - 11345 C 01/08/04 .0076 bpf, ID = 2.805" 2" 4 11378 - 11473 C 01/08/04 2" 4 11506 - 11580 C 01/08/04 z� 2" 4 11634 - 11698 C 01/08/04 1 PBTD 1-1 12656' 1 2" 4 11719 - 11787 C 01/08/04 2" 4 11901 - 11929 C 01/08/04 2" 4 11969 - 12049 C 01/08/04 2 -7/8" LNR, 6.16 #, L -80 STL, .0055 bpf, ID = 2.377" 12699' 1 2" 4 12079 - 12189 C 01/08/04 2" 4 12380 - 12420 C 01/08/04 2" 6 12460 - 12485 C 01/20/09 2" 4 12590 - 12650 C 01/08/04 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/31/94 D-9 ORIGINAL COMPLETION 07/03/07 BSE/PJC FISH TOOL STRING (06/16/07) WELL: 15 -33B 08/13/99 N4 /3ES SIDETRACK(15 -33A) 02/05/09 RLM/SV ADPERFS (01/21/09) PERMIT No: r 2031940 01/09/04 NORDIC 1 CTD SIDETRACK (15 -33B) 06/27/10 DBM/PJC ADPERFS/ CIBP (06/24/10) API No: 50- 029 - 22448 -02 01/19/04 JBM/KAK GLV C/0 06/25/11 CJS/ PJC CIBP/ ADPERF (06/22- 23/11) SEC 22, T11N, R14E, 560' FNL & 106' FWL 05/02/04 TH/KAK CASING DEPTH CORRECTIONS 06/25/11 PJC DRAWING CORRECTIONS 06/05/07 RCT /PAG FISH @ 9161' + CORRECTION - BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development 0 Exploratory ^ 203-1940 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-22448-02-00 8. Property Designation (Lease Number) : `~, 9. Well Name and Number ADLO-028305 PBU 15-33B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12699 feet Plugs (measured) 11030' 6/24/10 feet true vertical 8841.73 feet Junk (measured) None feet Effective Depth measured 12666 feet Packer (measured) 10069 10155 true vertical 8842.47 feet (true vertical) 8512 8559 Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.5# H-40 SURFACE - 112 SURFACE - 112 1490 470 Surface 3603 13-3/8" 68# NT-80 SURFACE - 3603 SURFACE - 3543 5020 5020 Intermediate Production 9683 9-5/8" 47# L-80 33 - 9683 33 - 8292 6870 4760 Liner 829 7" 29# L-80 9520 - 10349 7698 - 8648 8160 7020 Liner 2630 3-1/2"X3-31/6"X2-7/8" 10069 - 12699 8512 - 8842 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# L-80 30 - 10354 30 - 8670 Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker KB Toa Packer 10069 8512 4-1/2" Baker SAB-3 Packer 10155 8559 12. Stimulation or cement squeeze summary: Intervals treated (measured): +~° . t ~~g~f` ~; ~ ~ ~;j. ~ (~ 1 ~ (~ ~ '~ .~ aw. s3 J u f~F~rs«{ Treatment descriptions including volumes used and final pressure: ~~BS~~ Q~ ~ ~~aa ~;~;;; ~'p j 1 ;, ~ $5 4~ ~: t ae , 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 Subsequent to operation: 632 52007 21 860 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signature Phone 564-4944 Date 7/2/2010 15-33B 203-194 PFRF OTTOCHMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-33B 1/8/04 PER 10,926. 10,973. 8,833.77 8,843.94 15-33B 1/8/04 PER 12,590. 12,650. 8,842.78 8,842.79 15-33B 1/8/04 PER 12,380. 12,420. 8,848.31 8,844.99 15-33B 1/8/04 PER 11,969. 12,049. 8,839.72 8,846.15 15-33B 1/8/04 PER 11,901. 11,929. 8,834.7 8,836.36 15-33B 1/8/04 PER 12,079. 12,189. 8,846.74 8,847.91 15-336 1/8/04 PER 11,634. 11,698. 8,832.18 8,831.7 15-33B 1/8/04 PER 11,506. 11,580. 8,834.9 8,833.98 15-336 1/8/04 PER 11,719. 11,787. 8,832.32 8,832.79 15-33B 1/8/04 PER 11,378. 11,473. 8,832.7 8,833.82 15-336 1/8/04 PER 11,196. 11,345. 8,838.36 8,834.57 15-33B 6/18/07 BPS 9,978. 12,650. 8,459.7 8,842.79 15-33B 7/2/07 BPP 9,978. 12,650. 8,459.7 8,842.79 15-33B 1/20/09 APF 12,460. 12,470. 8,842.56 8,842.29 15-33B 1/20/09 APF 12,470. 12,485. 8,842.29 8,842.16 15-33B 1/21/09 APF 10,885. 10,905. 8,822.97 8,828.37 15-33B 6/24/10 APF 10,830. 10,855. 8,807.34 8,814.55 15-33B 6/24/10 BPS 11,030. 12,650. 8,846.64 8,842.79 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~~ 15-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/22/2010~ ~ ~ CTU #8 1.75" CT Drift w/ GR/CCL, CIBP (GSO), Add Perf Move from 9-37 to DS-15. WO Well Support to add riser length above PIS. MIRU. Work on CT weight cell calibration. Standby. Continued on 6/23/10 ~~~ 6/22/2010 CTU #8 1.75" CT Drift w/ GR/CCL, CIBP (GSO), Add Perf Move from 9-37 to DS-15. WO Well Support to add riser length above PIS. MIRU. Work on CT weight cell calibration. ~ ' Standby. Continued on 6/23/10 i ~ 6/23/2010 MIRU CTU #8. Objective: Coil Flag, CIBP, Shoot 25' perfs. MU SWS GR/CCL in carrier. Kill well with 290 bbl KCL. RIH w/ logging tools Tagged TD at 12,636' ' Start up logging pass.Paint flag at 10980' finish logging to 10,000' POOH ***"* Job Continued on 6/24/10 *'""** ~~ 6/24/2010 MIRU CTU #8. Objective: Coil Flag, CIBP, Shoot 25' perfs.****'" Continued from 6/23/10 "*""* POOH B/D tools check for data. Got good data , +18.5' correction. MU/RIH Halco 2.875" CIBP. Correct @ flag. Set CIBP @ 11030' (mid element). Stack weight, confirm set. Set flag @ 10780'. POOH. MU/RIH w/ 25' of 2" gun. ~ Tag CIBP, correct depth. Shoot interval 10830'-10855'. POOH. Wellbore is FP ~ ~~ Ito 2500' w/ water/meth. Job is complete. RDMO. FLUIDS PUMPED BBLS 540 1 %KCL 99 METHM/ATER 2 Total TREE _ FMC WELCHERD = ' CNV ACTUATOR = BAKER C KB. ELEV = 69.6' BF. ELEV = KOP = 2522' Max Angle = 95 @ 12391' Datum MD = 12317' Datum TV D = 8781' SS • SAFETY N :CHROME 7" LNR 15-338 13-3/8" CSG, 68#, NT-80, ID = 12.415" 3603' Minimum ID = 2.377" @ 10967' TOP OF 2-7/8" LINER 9-5/8" CSG, 47#, NT-80, ID = 8.681" I-I 9683' (3-1/2" LNR 8.81#, L-80, .0081 bpf, ID = 2.880" I TOP OF WHIPSTOCK ~ 10350' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 74° @ 10885' Note: Refer to Production DB for historical perF data SIZE SPF INTERVAL Opn/Sgz DATE 2" 6 10885 - 10905 O 01121/09 2" 4 10926 - 10973 O 01/08/04 2" 4 11196 - 11345 O 01/08/04 2" 4 11378 - 11473 O 01/08/04 2" 4 11506 - 11580 O 01!08/04 2" 4 11634 - 11698 O 01/08/04 2" 4 11719 - 11787 O 01/08/04 2" 4 11901 - 11929 O 01/08(04 2" 4 11969 - 12049 O 01/08104 2" 4 12079 - 12189 O 01/08/04 2" 4 12380 - 1242p O 01/08/04 2" 6 12460 - 12485 O 01/20/09 2" 4 12590 - 12650 O 01/0$/04 7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" 11394' 14-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 2-718" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" 4-112" CAMCO TRDP-4A SSSV NIP, ID = 3.855" LOCKED OUT (08/01/05) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3022 3001 19 OTIS DOME RA 16 01/19/04 2 5164 4996 22 OTIS SO T2 20 01/19/04 3 7054 6702 37 OTIS DMY T2 0 10/05103 4 9404 8141 58 OTIS DMY T2 0 10/05!03 10069' - -~ BKR KB LNR TOP PKR 10077' 3.70 BKR DEPLOY SLV, ID = 3.0" 10096' 3-1 /2" HES X NIP, ID - 2.813" 10127' 3-1/2" X 3-3/16" XO, ~ = 2.786" 10138' 4-112" OTIS X NIP, ID = 3.813 10155' 7" X 4-1/2" BKR SABL-3 PKR Behind CT LNR 10185' 4-112" OTIS X NIP, iD 3.813 10202' 4-1/2" OTIS XN NIP, ID = 3.725" MILLOUT WINDOW (15-338) 10354' - 10360' 10948' I--I 3-3116" X 2-718" XO, ID = 2.377" 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" PBTD 2-718" LNR, 6.16#, L-80, .0055 bpf, ID = 2.377" DATE REV BY COMMENTS DATE REV BY COMMENTS 03/31194 ORIGINAL COMPLETION 07/03/07 BSE/PJC FISH TOOL STRING (06116/07) 08/13/99 SIDETRACK 1533A 02/05/09 RLM/SV ADPERFS (01121/09) 01109!04 JLM/KAK CTD SIDETRACK 15-338 01/19/04 JBM/KAK GLV C/O 05/02(04 TH/KAK CASING DEPTH CORRECTIONS 06/05/07 RCT/PAC FISH 9161' + CORREC710N PRUDHOE BAY UNIT WELL: 15-338 PERMIT No: "2031940 API No: 50-029-22448-02 SEC 22, T11N, R14E, 649.62' FEL & 1473.23' FNL BP Exploration (Alaska} BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, ao3-~R ~ ~~- 33$ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date' 01105/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-016 2042570 50029206960200 NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 .50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28!2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-128 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11 /7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11!12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11!11/2009 15-31 B 2050860 50029222850200 NA 1.2 NA 3.4 11111!2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17!2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10!9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS :~ t~ aJ F~ ~ ,5 %x(39 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated E; ~ +,; ;_.,_ r f7r?'Imiccin _ ~ ~ Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension~~~Or8 8 ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory 203-1940 - 3. Address: P.O. Box 196612 Stratigraphic I~' Service ~~ 6. API Number: Anchorage, AK 99519-6612 50-029-22448-02-00 7. KB Elevation (ft): 9. Well Name and Number: 69.6 KB - PBU 15-336- 8. Property Designation: 10. Field/Pool(s): ADLO-028305 - ~ "" PRUDHOE BAY Field! PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12699 - feet Plugs (measured) None true vertical 8841.73 - feet Junk (measured) None ~~ Effective Depth measured 12666 - feet l-~ true vertical 8842.47 - feet Casing Length Size MD TVD Burst Collapse Conductor 112 20" 91.5# H-40 Surface - 112 Surface - 112 1490 470 Surface 3603 13-3/8" 68# NT-80 Surface - 3603 Surface - 3543 5020 2270 Production 9683 9-5/8" 47# L-80 33 - 9683 33 - 8292 6870 4760 Liner 829 7" 29# L-80 9520 - 10349 7698 - 8648 8160 7020 Liner 2630 3-1/2X3-3/16X2-7/8 10069 - 12699 8512 - 8842 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 30 - 10354 0 0 - Packers and SSSV (type and measured depth) 3-1 /2" Baker KB Top Packer 10069 4-1/2" Baker SAB-3 Packer 10155 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 490 44758 17 1125 Subsequent to operation: 626 40738 15 1307 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 1~ Development - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~`- Gas WAG ~ GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 2/5/2009 Form 10-404 Rev4sed 04/x'0()6 ~ ~ _ ,~~ ~ ' ~¢ ti f _ ~ 7a0q /-/~ Submit Original Only ~ !~ ~ti_a 3 15-33B 203-1940 PERF ~4TT~4CHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-33B 1/8/04 PER 10,926. 10,973. 8,833.77 8,843.94 15-33B 1/8/04 PER 11,196. 11,345. 8,838.36 8,834.57 15-33B 1/8/04 PER 11,378. 11,473. 8,832.7 8,833.82 15-33B 1/8/04 PER 11,506. 11,580. 8,834.9 8,833.98 15-336 1/8/04 PER 11,634. 11,698. 8,832.18 8,831.7 15-336 1/8/04 PER 11,719. 11,787. 8,832.32 8,832.79 15-336 1/8/04 PER 11,901. 11,929. 8,834.7 8,836.36 15-336 1/8/04 PER 11,969. 12,049. 8,839.72 8,846.15 15-33B 1/8/04 PER 12,079. 12,189. 8,846.74 8,847.91 15-336 1/8/04 PER 12,380. 12,420. 8,848.31 8,844.99 15-336 1/8/04 PER 12,590. 12,650. 8,842.78 8,842.79 15-336 6/18/07 BPS 9,978. 12,650. 8,459.7 8,842.79 15-336 7/2/07 BPP 9,978. 12,650. 8,459.7 8,842.79 15-33B 1/20/09 APF 12,460. 12,470. 8,842.56 8,842.29 15-33B 1/20/09 APF 12,470. 12,485. 8,842.29 8,842.16 15-33B 1/21/09 APF 10,885. 10,905. 8,822.97 8,828.37 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 15-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY '' ACTIVITYDATE SUMMARY 1/20/2009 CTU 6 1.75" CT Scope; adperf «interact publishing» *"job continued from WSR 01-19-09** Drift w/ 2.2' carrier w/ memory GR,CCI, inside. Tag @ 12636' , paint flag @ 12585'. Log @ 30 fpm up to 9981' and POOH. CK data. Confirmed' good data. RIH w /Gun run #1 2" HSD PJ2006 Omega HMX guns 6 spf.~~ from 12470' to shot to 12485' ottom shot.15 feet of guns OOH confirmed guns fired. RIH w /gun run #2 - 2" HSD PJ2006 Omega HMX guns 6 spf. Shoot from 12460' to shot to 12470' bottom shot. POOH RIH w/ PDS logging tools. paint flag @ 11200' begin logging @ 30 fpm. "*job continued on WSR 01-21- , 09*'" _ _ _ ~__ ~.._ _ a...__.__._. _.~.. > 1/21/2009 **"* CTU 6 w/ 1.75" OD CT -Add Perfs **"* Continued from 1/20/09 WSR **"* '~~ Paint flag at 11200' -Log up to 10000 - POH -Verify good log data - +12' correction - MU/RIH w gun #3 - 20' 2" OD - 6 spf PJ Omega -Fire pert gun # 3 .and shoot interval 10885 - 10905 (ref: SLB MCNL 07-January-2004). -good surface indication gun fired - POH. At surface, confirm all shots fired. Freeze protect wellbore to 2500' with 60/40 methanol/water. RDMO. Release well to j operations. Job complete. FLUIDS PUMPED BBLS 77 2% KCL 101 60/40 METH 1 Total • ~~. -- ~; - ~. I~ff~~L ~~V T~3,4/I ~S/1'?",4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ,~ ~~,hr RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 X03-1~~/ ~~~'~'~ 1) Coil Flag (run 1) 19,Jan-09 15-338 E~ 50.029-22448-02 2) Coil Flag (run 2j 20,1an-09 15,338 EDE f ~ 2 ~ ~ ~: : t o ~~, ,t Signed : ~ . ~ Date : ~''~~ ~ ~~~~ Print Name: ~. ~~,I+ui~~ir~ ~~c~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8851 FAx: (907)245-88952 E-MAIL : pdsancharageCa~memorylog.com WEBSrrE : wwwr.memorvloc~ coal C:\Documents and Settings\OwnerlDesktop\Transuut BP.dopc • ~.._ `~ °"~, '~ ~,~. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \I.aserFiche\CvrPgs_Inserts\Micrafilm_Marker. doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 /3705"" RE: MWD Fonnation Evaluation Logs 15-33B, 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 15-33B: :) ð 3 - qL\J LAS Data & Digital Log Images: 50-029-22448-02 1 CD Rom ~ If\ ~\D1Þ Cf nfa DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031940 Well Name/No. PRUDHOE BAY UNIT 15-33B Operator BP EXPLORATION (ALASKA) INC (' 1 / ~-..-.. A-u"ù <"1 ~¡Il Ui.L "'\V.., API No. 50-029-22448-02-00 MD 12699 / TVD 8842./ Completion Date 1/9/2004 ./ Completion Status 1-01L Current Status 1-01L UIC N ~-~._--~.~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~.~- DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR 1 CCL 1 CNL Well Log Information: Logl Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH . Received Comments .Rpt t'ó'g Directional Survey Production 2 Blu ~ I i 10327 12699 1/16/2004 I 9975 12645 Case 7/21/2004 PRODUCTION PROFILE, I MEMORY GR/CCL/CNL/STP 10330 12667 Open 9/28/2004 MWD, GR, ROP 10330 12667 Open 9/28/2004 MWD, GR, ROP, DSN 12648 9598 12585 Case 9/22/2004 COMPENSATED NEUTRON LOG, MEMORY GR/CCL/CNL 9598 12585 Case 9/22/2004 COMPENSATED NEUTRON LOG, I . MEMORY GR/CCL/CNL 9975 12645 2/3/2005 memory borax/gr/ccl/cnl I ---"~ D 12648 Gamma Ray LIS Verification C Pds 12735 Neutron 25 12735 Neutron 25 Blu Lb, Leak 2 Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Permit to Drill 2031940 DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Well Name/No. PRUDHOE BAY UNIT 15-33B API No. 50-029-22448-02-00 MD 12699 TVD 8842 ADDITIONAL INFORM~. ION Well Cored? Y /~ Chips Received? Analysis Received? """rl N ~. Operator BP EXPLORATION (ALASKA) INC Completion Date 1/9/2004 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? ~ Y N . Y IN Formation Tops Comments: Compliance Reviewed By: t-o Date: 3 pJ;-m ~ -- . . i07S~ ,~3- / r ¥ 01/24/05 Schlumberger NO. 3318 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . WII J b # L D 'f D t BI r Color p' t CD t e 0 OQ escnptlon ae ue me rm s 2o'b··Jf{ G-12B 10715391 MCNL 03/21/04 1 .,..~..-....[,/~ 15-3S'B ;:'0 :,.. i q '-I 10728396 MCNL 04/03/04 1 ~, :7-iJ)-( I c... D-04B 10715393 MCNL 04/07/04 1 DS 18-13A 10715395 MCNL 04/16/04 1 =03-10.(5 K-10B 10715402 MCNL 05/16/04 1 DS 02-15A 10715404 MCNL 05/18/04 1 -;;..-12.S DS 2-33A 10670016 MCNL 05/23/04 1 i C¡5"-tX1 DS 07 -03A 10715406 MCNL 06/03/04 1 2tJ)-Rl. DS 07 -29C 10715407 MCNL 06/04/04 1 hi'ð/2. E-15B 10861913 MCNL 06/05/04 1 ?6-t- I j"Li DS 18-27C 10715410 MCNL 06/13/04 1 ß."t.ðfl E-24B 10861916 MCNL 06/20/04 1 '1'i09 DS 18-31 10715413 MCNL 07/05/04 1 ... -lID K-09C 10861920 MCNL 07/16/04 1 ~,o'11 C-17B 10715418 MCNL 08/10/04 1 f'}j.tJ14 C-39 10715421 MCNL 08/19/04 1 Prints..... only-Job not complete) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 d)ç I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Date Delivered: . . C:<ð3 - fj f RECEIVED 12ro'lfl SEP 2 8 2004 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7ili Avenue, Suite 100 Anchorage, Alaska 99501 WELL LOG TRANSMITTAL Alaska Oil & Gas Cons. Commission Anchowlle September 17, 2004 RE: MWD Formation Evaluation Logs ] 5-33B, AK-MW-2846007 1 LDWG formatted Disc with verification listing. API#: 50-029-22448-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 995 ] 8 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:# . STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: !HI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 !HI Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/9/2004 203-194 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1/1/2004 50- 029-22448-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1/5/2004 PBU 15-33B 558' SNL, 5171' WEL, SEC. 22, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2624' NSL, 3466' WEL, SEC. 16, T11N, R14E, UM 69.6' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2609' NSL, 5227' WEL, SEC. 16, T11N, R14E, UM 12666 + 8842 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676021 . y- 5960923 Zone- ASP4 ' 12699 + 8842 . Ft ADL 028305 TPI: x- 672369 y- 5964024 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 670609 . y- 5963968 . Zone- ASP4 (Nipple) 2204 MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey !HI Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: -0~zv /ð¡ 3Sr',/?7Þ SGRC Combined GR & EWR, MGR 1 CCL 1 CNL <4 ~'</ ~ 712:::> ?2. CASING, LINER AND CEMENTING RECORD CASING SETfIf',lc:r¡:¡ I=PTHMÞ .SETfI/llGI E","tt4TVP ~?jt ......... .......... SIZE . w¥. PER: FT. GRAbE Top BottOM Top I BOtTOM ) CEMENTING RECORD . PúÖ..Eb 20" 91.5# H-40 Surface 112' Surface 112' 30" 760 sx Arcticset 13-3/8" 68# L-80 35' 3603' 35' 3543' 17-1/2" 1205 sx PF 'E', 375 sx Class 'G' 9-518" 47# L-80 33' 9683' 33' 8292' 12-1/4" 51 sx Class 'G' 7" 29# L-80 9520' 10349' 7698' 8648' 8-1/2" 186 sx Class 'G' 3-1/2" x 3·3/16" x 2-7/8" 9.3# /6.2# /6.16# L-80 10069' 12699' 8512' 8842' 4-1/8" x 3-3/4" 127 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. ....... » iT JSING )ii Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10160' 10155' MD TVD MD TVD (tailpipe fell off) 10926' - 10973' 8834' - 8844' 12380' - 12420' 8848' - 8845' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11196' -11345' 8838' - 8835' 12590' - 12650' 8843' - 8843' 11378' -11473' 8833' - 8834' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11506' -11580' 8835' - 8834' 11634' - 11698' 8832' - 8832' 2000' Freeze Protected with MeOH 11719' -11787' 8832' - 8833' 11901' -11929' 8835' - 8836' 11969' - 12049' 8840' - 8846' 12079' - 12189' 8847' - 8848' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 13, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r-·-·-·_~-·"-·- rh~-" ('AWE'''''''' t ,.,Vt'!·:'L;¡ ¡U;'ii ~ None - ¡ DATE.; ¡ f'\. §::. fED 05 --L-CZ:..t.:: ¡ n RØ)MSBfL v:J~~r DIe 1 ~ f !\ , FEB 04 2004 !.::~~~¡~:~..::-.I ~"./ ,\ r I,'~ ! . ". .' ,. , in ., .. n.. .;) ,f",_ P. ! 'U>,> ~. k.·," Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~F 28. GEOLOGIC MARKERS 29. ..... ,JRMATlON TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 22TS 10450' 8684' None 21TS 10606' 8735' Zone 1 B 10748' 8783' Zone 1A I TDF 10884' 8823' FEB 0 :1 2004 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date O;).....DL/- P8U 15-338 Well Number 203-194 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Thomas McCarty, 564-4378 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal. Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1. and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 1 of 11 BP Operations Summary Report 15-33 15-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 2/24/1994 End: 1/9/2004 12/16/2003 1/9/2004 N1 Description of Operations Date From - To Hours Task Code NPT Phase .. ~.._ ._____..____n_ ...._...._u__. ____.__. ___..____np_____ _..____"_.. ._ ........__.__... 12/26/2003 11 :00 - 00:00 13.00 MOB N WAIT PRE 12/27/2003 00:00 - 08:00 8.00 MOB N WAIT PRE 08:00 - 11 :00 3.00 MOB P PRE 11:00 -12:30 1.50 MOB P PRE 12:30 - 00:00 11.50 MOB N WAIT PRE 12/28/2003 00:00 - 00:00 24.00 MOB N WAIT PRE 12/29/2003 00:00 - 19:00 19.00 MOB N WAIT PRE 19:00 - 21:00 2.00 MOB N WAIT PRE 21 :00 - 00:00 3.00 MOB N WAIT PRE 12/30/2003 00:00 - 06:30 6.50 MOB N WAIT PRE 06:30 - 08:30 2.00 MOB N WAIT PRE 08:30 - 18:30 10.00 MOB N WAIT PRE 18:30 - 18:45 18:45 - 22:30 22:30 - 23:45 23:45 - 00:00 12/31/2003 00:00 - 00:30 00:30 - 03:00 03:00 - 08:30 08:30 - 09:30 09:30 - 09:45 09:45 - 10:45 10:45 - 11 :00 11 :00 - 11 :30 11 :30 - 12:20 12:20 - 13:00 13:00 - 15:45 15:45 - 16:00 16:00 - 18:30 18:30 -19:00 0.25 RIGU P PRE 3.75 RIGU 1.25 RIGU 0.25 MOB 0.50 MOB 2.50 BOPSU PRE PRE PRE PRE PRE 5.50 BOPSU PRE 1.00 BOPSU PRE 0.25 BOPSU 1.00 BOPSU PRE PRE PRE WEXIT 0.83 STWHIP P 0.67 STWHIP P 2.75 STWHIP P 0.25 STWHIP P WEXIT WEXIT WEXIT WEXIT 2.50 STWHIP P WEXIT 0.50 STWHIP P WEXIT Wait 0 Nordic #2 to move from W-1 to DS15 Waiting on NordiC#2 rig move Pre rig move meeting with Security and CPS. Move rig to DS 15. On DS 15 access road at 11 :00. Move rig to 15-33. Spot rig in front of well. Lay spill dikes around well head. Wait on weather. Winds too high to raise derrick and wind walls. WOW Wind 24mph wI gust to 35 mph. GPB current in Phase I driving on spine road and Phase II on access roads. National weather service issued blizzard warning. Phase II weather declared on all roads at 21 :00. Wait on weather. Phase 2 conditions in GPB field wide. Blizzard warning through tonight. Winds 30 - 40 mph gusting to 60+ mph. Visibility on DS 15 is very poor. Driving is hazardous on the pad and access road. Phase 3 finally issued in GPB field wide at 11 :30 hrs Crew change out with Security & front end loader (Phase III) WOW. Phase 3. WOW Phase 3. Phase conditions lifted to Phase 2. Wait on wind to raise derrick and wind walls. Lifted to Phase 1 on main roads. Remains Phase 2 on all access roads and pads. Wait on wind. Wind down to 20 mph gust limit at 17:30. Wait 1 hour fo confirm this is not a lull, prior to raising wind walls. Safety meeting with night tour prior to raising wind walls. Hazards discussed. Snow accumulation around rig has been cleared, but needs further removal prior to raising wind walls. Call for snow removal from Peak. Call for 2 portable heaters. Pick up derrick and wind walls. Pick up injector out of stabbing box. Stab coil. Safety meeting prior to moving rig over well. Back rig over well. Nipple up BOP stack. Accept rig at 00:30. Perform initial BOP test. Test witnessed by AOGCC, Jeff Jones. Test Methane and H2S alarm. Cut 22' of coil. Install Baker CTC. Pull test to 35,000 Ibs and pressure test. Pressure test new shock hose on Pump #1 to 5,000 psi. Pressure test hard line in reel house. Pump dart, 58.5 bbls. Pressure test inner reel valve. PJSM for PU milling BHA. Unable to use beaver slide due to close proximity of adjacent well. Pick up milling tools on pipe elevator. MU milling BHA. RIH. Tight spot at 7,200'. Weight check, 31,000 Ibs. Tag cement at 10,342'. Wash down to Top of whipstock. Pinch point at 10,357.4'. Correct -7.4'. Flag pipe. Free spin 1,510 psi at 2.7 bpm. Mill window at 2.7 bpm, 1700 psi. 10352.5',2.5' into the window. 2.7/2.7/1740 psi. 240 psi motor Printed: 1/13/2004 3:20:41 PM "WI' .. Page 2 of 11 BP Operations Summary Report Legal Well Name: 15-33 Common Well Name: 15-33 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To I Hours I Task ¡ Code 12/31/2003 18:30 - 19:00 0.50 STWHIP P 12/16/2003 1/9/2004 N1 Spud Date: 2/24/1994 End: 1/9/2004 Start: Rig Release: Rig Number: NPT I Phase I Description of Operations ----------.- -"- ....--.... 19:00 - 20:00 1.00 STWHIP P 20:00 - 21 :00 1.00 STWHIP P 21 :00 - 22:00 1.00 STWHIP P 22:00 - 23:00 1.00 STWHIP P 23:00 - 00:00 1.00 STWHIP P WEXIT work. 3400 Ibs weight on bit. Pump 15 bbl sweep of 2# biozan. WEXIT 10353.0',3.0' into the window. 2.7/2.7/1835 psi. 335 psi motor work. 4100 Ibs weight on bit. WEXIT 10353.8',3.8' into the window. 2.7/2.7/1900 psi. 400 psi motor work. 5600 Ibs weight on bit. WEXIT 10354.6',4.6' into the window. 2.7/2.7/1736 psi. 236 psi motor work. 4800 Ibs weight on bit. WEXIT 10355.4',5.4' into the window. 2.7/2.7/1800 psi. 300 psi motor work. 5000 Ibs weight on bit. Pump 15 bbl sweep fo 2# biozan. Getting metal on ditch magnets. WEXIT 10356.2',6.2' into the window. 2.7/2.7/1955 psi. 455 psi motor work. 2800 Ibs weight on bit. Drilling break at 10356.2'. Begin drilling open hole. 1/1/2004 00:00 - 00:40 0.67 STWHIP P WEXIT 00:40 - 01 :40 1.00 STWHIP P WEXIT 01:40 - 02:10 0.50 STWHIP P WEXIT .. 02:10 - 03:40 1.50 STWHIP P WEXIT 03:40 - 04:00 0.33 STWHIP P WEXIT 04:00 - 04:15 0.25 DRILL P PROD1 04:15 - 04:50 0.58 DRILL P PROD1 04:50 - 05:30 0.67 DRILL P PROD1 05:30 - 07: 15 1.75 DRILL P PROD1 07:15 - 07:30 0.25 DRILL P PROD1 07:30 - 07:45 0.25 DRILL P PROD1 07:45 - 11 :45 11:45 - 12:00 12:00 - 14:45 14:45 - 15:35 PROD1 PROD1 PROD1 PROD1 4.00 DRILL P 0.25 DRILL P 2.75 DRILL P 0.83 DRILL P Note, The above depths are not referenced to whipstock pinch point. These depths are incorrect by 47.1". The correct window depths are; Top of Whipstock=1 0350.0' Top of Window=1 0354.0' RA tag=10360.0' Bottom ofWindow=10360.0'. Continue drilling rathole. Pump 30 bbls of 2# biozan sweep. 10370' corrected depth. 10' of openhole rathole. ReamlBackream window several times. Dry drift down and up with no problems. Swap to mud. While waiting on mud, make a slow trip up to the tubing tail to clean the 7", then run back to bottom. POH, swapping well to a new Flo-pro system. Tag up at surface. Stand back injector. Lay down Baker window milling BHA. Window mill recovered at 3.79" go, 3.78" no-go. String reamer recovered at 3.80" go, 3.79" no-go. Pre spud safety meeting, prior to picking up first drilling BHA. Make up BHA #2, first drilling BHA. Cut of Baker CTC, install SWS CTC. Pull test to 35 klbs, Pressure test to 4000 psi. Stab injector on BHA. RIH with BHA #2. Hycalog DS100 bi center bit, BH11.37 deg mud motor, Sperry GR-Directional. Shallow hole pulse test at 500'. Orienter check at 2200', passed ok. Continue RIH. Run through window wlo pump. Set down at top of whipstock and pop through. Tag bottom at 10,370'. Log up 8'. Drill ahead to see formation marker and RA marker. Make-4' correction. Corrected window depths are: RA marker: 10,355' Top of whipstock: 10,345' Top of Window: 10,349' Bottom of Window: 10,355' Drill ahead to 10,520' at 2.75 I 2.75 I 3,360 psi, TF 70 to 90L. Wiper trip to 10,370'. Drill from 10,520' to 10670' at 2.8 I 2.8 I 3,340 psi, TF 90 Wiper Trip to 10160', RIH Tie-in at 10375' (Corrected +2.5 ft - Printed: 1/13/2004 3:20:41 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 3 of 11 BP Operations Summary Report Start: Rig Release: Rig Number: Phase I i 15-33 15-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 i ! Task I Code I NPT I Date From - To I Hours _n.."_..._n__._ 1/1/2004 14:45 - 15:35 15:35 - 15:45 15:45 - 16:00 16:00 - 16:45 16:45 - 17:10 17:10 - 18:30 18:30 - 18:45 18:45 - 19:40 19:40-20:10 20: 10 - 20:25 20:25 - 20:45 20:45 - 22:25 22:25 - 22:45 22:45 - 00:00 1/2/2004 00:00 - 00:45 00:45 - 00:50 00:50 - 01 :25 01 :25 - 01 :30 01 :30 - 01 :40 01 :40 - 03:25 03:25 - 04:30 04:30 - 06:50 06:50 - 07:20 07:20 - 07:30 07:30 - 08:00 08:00 - 08:20 08:20 - 09:45 09:45 - 10:55 10:55 - 12:45 12:45 - 16:15 16:15 - 17:45 17:45 - 18:00 18:00-18:10 0.83 DRILL P 0.17 DRILL P PROD1 PROD1 0.25 DRILL P 0.75 DRILL P 0.42 DRILL P 1.33 DRILL P 0.25 DRILL P 0.92 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 0.50 DRILL P PROD1 0.25 DRILL P 0.33 DRILL P PROD1 PROD1 1.67 DRILL N DPRB PROD1 0.33 DRILL N DPRB PROD1 1.25 DRILL N DPRB PROD1 0.75 DRILL N 0.08 DRILL N DPRB PROD1 DPRB PROD1 0.58 DRILL P PROD1 0.08 DRILL P 0.17 DRILL P 1.75 DRILL P PROD1 PROD1 PROD1 1.08 DRILL P PROD1 2.33 DRILL P PROD1 0.50 DRILL P 0.17 DRILL P 0.50 DRILL P 0.33 DRILL N PROD1 PROD1 PROD1 DFAL PROD1 1.42 DRILL N 1.17 DRILL N DFAL PROD1 DFAL PROD1 1.83 DRILL N 3.50 DRILL P DFAL PROD1 PROD1 1.50 DRILL P 0.25 DRILL P PROD1 PROD1 0.17 DRILL P PROD1 12/16/2003 1/9/2004 N1 Spud Date: 2/24/1994 End: 1/9/2004 Description of Operations ...-". ..... .-..---.--....-.----. correction) RIH, tagged bottom at 10670' Drilling wI 60L a dn ROP = 150 fph Driling sandlshale sections Drilled to 10715' PUH and orient TF around Drilling and orient TF to fit dir plan to 10790' Wiper trip to 10,370'. Drill to 10,910' at 2.7 I 2.7 I 3,900 psi, TF 90L. Orient to 70R. 10890', Resume drilling. Free spin = 2900 psi at 2.5 bpm. Drilling at 2.5/2.6/3550 psi. Pit vol=299 bbls. IAP=234 psi, OAP=225 psi. ROP=72 fph. 10950', wiper trip to tail pipe. Clean PU off bottom at 36 klbs. Clean up thru window, and back down to TD. Orient to 60R. Resume drilling. Free spin 2950 psi at 2.6 bpm. Drilling at 2.6/2.6/3500 psi. Pit vol=296 bbls. ROP=130 fph. TF=60R. 10974', Not getting the doglegs we need to avoid the Kavik. POOH for a bigger bend motor. Tag up with BHA #2, reset motor to a larger bend. Scribe motor and MWD. RIH with BHA #3 to land well. Same DS100 bicenter bit. Same motor reset to 3.0 degrees. Continue RIH to finish build section. Slick thru window and to TD. Tag up and make -10' correction setting depth to last tag of 10974'. Orient to high side. Resume drilling build section. 2.5/2.5/3300 psi. Pit vol=300 bbls. IAP=230 psi, OAP=80. ROP=60 fph. 11008', Orient 2 clicks. Resume drilling. 11021', Well is landed at 94 deg. POOH for lateral section BHA. Tag up at surface. Replace bicenter bit with Hycalog DS49. Adjust motor bend to 1.04 deg. Check motor and orienter. DS100 bicenter bit recovered graded as 4,2,Ringed. RIH with BHA #4, to drill lateral section. DS49 bit, 1.04 deg motor, Sperry MWD-GR. Shallow hole test of pulser at 500', and of orienter at 2200', passed ok. RIH. Tie in log. Correct -20'. Tag TD at 11,022'. Orient. Drill to 11,037'. Sporadic pulses from MWD tool. Surge tool. Pull up hole to trouble shoot MWD. POOH to change MWD. Change out pulser and probes of MWD. Change orienter. Inspect bit and motor, ok. RIH. Shallow hole test MWD and orienter. RIH. Tag bottom. Correct depth 11,037', -20'. Drill to 11,200' at 2.5 12.5 I 3,550 psi 80 - 90R TF, 100 fph average ROP. Wiper trip to 10,360'. Hole in good condition. Tag bottom. Drill from 11,200' to 11,269' at 2.4 I 2.4 I 3,350 psi, 55L TF. Free spin=3,000 psi. 11269', Orient to 90L. IAP=240 psi, OAP=238 psi. Pit vol=309 bbls. Printed: 111312004 3:20:41 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 4 of 11 BP Operations Summary Report 1 5-33 1 5-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 I From - To Hours, Task Code I NPT Date 1/2/2004 18:10 - 19:00 19:00 - 20:20 1/3/2004 20:20 - 20:45 20:45 - 23:00 23:00 - 23:40 23:40 - 23:50 23:50 - 00:00 00:00 - 00:25 00:25 - 00:35 00:35 - 02:50 02:50 - 03:50 03:50 - 05:00 05:00 - 05:30 05:30 - 05:40 05:40 - 06:00 06:00 - 07:30 07:30 - 10:00 10:00 - 11 :30 11:30-13:10 13:10 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 16:40 16:40 - 17:50 17:50 - 18:15 18:15-18:50 0.83 DRILL P 1.33 DRILL P ..----.........-....¥ 0.42 DRILL P 2.25 DRILL P 0.67 DRILL P 0.17 DRILL P 0.17 DRILL P 0.42 DRILL P 0.17 DRILL P 2.25 DRILL P 1.00 DRILL P 1.17 DRILL P 0.50 DRILL P 0.17 DRILL P 0.33 DRILL P 1.50 DRILL P 2.50 DRILL N 1.50 DRILL N 1.67 DRILL N 0.33 DRILL N 2.00 DRILL N 0.50 DRILL N 0.67 DRILL N 1.17 DRILL P 0.42 DRILL P 0.58 DRILL P Start: Rig Release: Rig Number: Phase 12/16/2003 1/9/2004 N1 Spud Date: 2/24/1994 End: 1/9/2004 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations Resume drilling. TF=78L, ROP=11 0 fph. 11350', wiper trip to tubing tail. Clean pickup at 35klbs. Slight weight bobble and motor work at shale at 10590', and 10880' when RIH. Orient to 120L. Resume drilling. Free spin 3200 psi @ 2.5 bpm. 11500', Wiper trip to shoe. Clean PU off bottom at 40 klbs. Log tie in pass up from 11380'. Make -5' correction. Run back to bottom. Continue wiper trip back to bottom to resume drilling. Orient to 30R. 11495', Resume drilling. Starting swap to new mud system. Wiper trip to tubing tail. Clean PU off bottom at 36 klbs. Clean up thru window with pumps at minimum. Clean to tubing tail. Hung up running down back thru window at 10348', with pumps at minimum rate. Tried it several times at minimum rate, oriented to 45L, 20L, 0, 20R, 45R (whipstock set at 2L). Tried it with pumps down, and coil pressure bled off, several times. Tried running at it at 100 fpm with pumps down. Tried it with pumps on, set down at 10348', and motor stalled. (Note top of window at 10349'). Tried it every click all the way around with the orienter and pumps at minimum rate. Tried it all the way around a second time. Finally, when at 120L (?) we went thru the window and tagged up at 10361'. Kick on pumps, staying below the window. Try to work down thru the obstruction. Stalling when we tag it. Oriented to keep tool face at 60L which is what hole was drilled at. Looks as if we are pushing something downhole. Finally popped thru it after a major amount of working the pipe. Whew. Continue wiper trip back in the hole. Orient to 45 R. Resume drilling. Drill to 11,712'. Getting weak stalls from motor and pressure fluctuations. MWD tool turning off and on. May have flow problem in BHA or above. POOH to inspect BHA. Pull through window without problems. Pull up to 10,300'. Orient to 14L of HS. Slow pumps to .13 bpm. Run through window without problems. Continue POOH. Break motor and bit. PT BHA, OK. Change motor, bit, MWD, and MHA. Bit had broken cutters from window damage. PU used DS 49. Cut 200' of coil. Pull and PT CTC. RIH to 10,300'. Orient TF to 30L. RIH at 40 fpm. Set down on WS. PU. Orient one click. Try again at 57 fpm, 0.1 bpm. Set down and popped through. Tie in. -22' correction. Verify RA location relative to formation to ensure whipstock has not moved. RIH. Tight hole and motor work from 11,620' - 11,660'. Orient to 70 RTF. Start drilling at 11,712',2.4 I 2.4 I 2,950 I 3,370 psi, 90 - 100 fph. 11712', Orient 11800', Resume drilling. Free spin 3250 psi at 2.6 bpm. Printed: 1/13/2004 3:20:41 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/3/2004 1/4/2004 Page 5 of 11 BP Operations Summary Report 15-33 15-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To I Hours Task I Code I NPT 18:15 - 18:50 18:50 - 20:25 20:25 - 21 :00 21:00 - 21:15 21:15 - 22:50 22:50 - 22:55 22:55 - 23:00 23:00 - 00:00 00:00 - 00:40 00:40-01:10 01:10 - 01:30 01 :30 - 02:30 02:30 - 03:25 03:25 - 03:40 03:40 - 04:30 04:30 - 06:00 06:00 - 06:50 06:50 - 08:50 08:50 - 12:05 12:05 - 14:50 14:50 - 15:35 15:35 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 18:20 18:20 - 20:00 ______ ----_.___.0_0.___._- Start: Rig Release: Rig Number: Phase 12/16/2003 1/9/2004 N1 Spud Date: 2/24/1994 End: 1/9/2004 Description of Operations 0.58 DRILL P .___d .." ~.._...~_ .... ___.....____.___ . ---.---..-..- .-.-.- ."- ......---.- 1.58 DRILL P 0.58 DRILL P 0.25 DRILL P 1.58 DRILL P 0.08 DRILL P 0.08 DRILL P 1.00 DRILL P 0.67 DRILL P 0.50 DRILL P 0.33 DRILL P 1.00 DRILL P 0.92 DRILL P 0.25 DRILL P 0.83 DRILL P 1.50 DRILL P 0.83 DRILL P 2.00 DRILL P 3.25 DRILL P 2.75 DRILL P 0.75 DRILL P 0.42 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 1.00 DRILL N DPRB PROD1 0.83 DRILL N 1.67 DRILL N DPRB PROD1 DPRB PROD1 Drilling at 2.6/2.6/3900 psi. Pit vol=302 bbls, IAP=247 psi, OAP=205 psi. TF=100L, ROP=11 0 fph. 11850', Wiper trip to window. Clean PU at 35 klbs. Clean to window, and clean back in the hole. No motor work while RIH. Resume drilling. 2.5/2.5/3700 psi. Pit vol=297 bbls. 11890', Orient to 11 OL. Resume drilling. TF=126L, 2.5/2.5/3860 psi. IAP=250, OAP=330, Pit vol=296 bbls. String weight down to 5000 Ibs when drilling. Drill solids at 20:00 PM were only 0.3%. Have mud man bring Lubetex up to 4.5% (From 3.0%), and Flolube up to 1.5% (From 0). 11980', Orient to 60L. Resume drilling. 12000', pit vol=298 bbls (Adding flulube and lubetex), PU clean at 35 klbs. Wiper trip to window. Still adding Flolube and Lubetex to system. Continue wiper trip to the window. Clean back in hole until 11600', tagged out then fell thru. 12000', Resume drilling. 2.5/2.5/3200 psi. Pit vol=302 bbls. 12065', Orient to 90L. Resume drilling. 2.5/2.5/3800 psi, 90 fph. TF=90L. 12150', Wiper trip to the shoe. Log tie in pass over RA tag in whipstock. Make -8' correction. Continue back in the hole after wiper trip. Slight weight bobble and motor work at 10890' when RIH. Tagged up very hard at 11600', and had to stack full weight to pop thru. (30' shale) 12150', Resume drilling. 2.5/2.5/3625 psi. Pit vol=302 bbls. IAP=270 psi, OAP=475 psi. TF=90L, ROP=120 fph. Drill to 12,300'. Wiper trip to tubing tail at 10,155'. RIH. Set down on WS. Orient to 9L. Attempt to run through window at 57 fpm with no pump. Set down. Try lower running speeds 4 times, no luck. Set down 1000 Ibs on WS and roll pump. Got through. Set down at 10,367'. Pick up and work through. RIH. Drill from 12,300' to 12,410' at 2.4/2.4 3,650/4,170 psi. Difficult drilling to 12,410'. Stalling and stacking weight at 12,400'. May be getting close to breaking out of shale. Broke into better drilling at 12,410'. Wiper trip to window. Drill To 12,508' at 2.4/2.41 3,700/3,900 psi 100 to 150 fph. Orient to 80R. Free spin pressure up to 3,900 psi. Start new mud down hole. Drill to 12,520'. Seeing 180 degree reactive torque, had been seeing 10 to 20 degrees. May be in fault area. Circulate new mud to bit. New mud to bit. Free spin 4,200 psi at 2.4 bpm. Circulate new mud around and wiper to window to monitor pressure. Pressure coming down while pulling up hole. Got new mud all the way around. Start to RIH. Pressure gradually coming back up, 4,000 psi at 11,000'. Pull into casing. Slight bobble at window. Pull into tubing tail and check pressures. S Circulating pressure at 2.5 bpm=4100 psi. Something isn't right. The CTP is too high. This pressure should be closer to Printed: 1/13/2004 3:20:41 PM ~ Page 6 of 11 BP Operations Summary Report Legal Well Name: 15-33 Common Well Name: 15-33 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date I From - To Hours Task! Code NPT i Phase r-- -------- ----- -----.- ---. -------.--. ------------.------- -- ------------------- 18:20 - 20:00 1.67 DRILL N DPRB PROD1 1/4/2004 20:00 - 21 :30 DPRB PROD1 1.50 DRILL N 21 :30 - 23:00 1.50 DRILL N DPRB PROD1 23:00 - 00:00 1.00 DRILL N DPRB PROD1 1/5/2004 00:00 - 00:25 0.42 DRILL N DPRB PROD1 00:25 - 02:15 1.83 DRILL N DPRB PROD1 02: 15 - 02:40 0.42 DRILL N DPRB PROD1 02:40 - 04:40 2.00 DRILL N DPRB PROD1 04:40 - 05:00 0.33 DRILL N DPRB PROD1 05:00 - 05:45 0.75 DRILL N DPRB PROD1 05:45 - 06:00 0.25 DRILL P PROD1 06:00 - 10:00 4.00 DRILL P PROD1 10:00 - 12:05 2.08 DRILL P PROD1 12:05 - 12:30 0.42 DRILL N DFAL PROD1 12:30 - 15:15 2.75 DRILL P PROD1 15:15 - 16:30 1.25 DRILL N DPRB PROD1 16:30 - 18:30 2.00 DRILL N DPRB PROD1 12/16/2003 1/9/2004 N1 Spud Date: 2/24/1994 End: 1/9/2004 Description of Operations ...-..-.-------.--. 2900 psi. Investigate for a few minutes, then conclude that we need to POOH to check BHA. IAP=270 psi, OAP=430 psi. Watched pressures all the way out of the hole. It was 4000 psi all the way OOH until 3000' (7 deg inclination), then the pump pressures gradually went down to 2900 psi. This is what it should be. Continue POOH pumping at full rate. No unusual amounts of cuttings observed across the shaker on trip OOH. Tag up at surface, stand back injector. Blow down BHA with water and air. Inspect bit, motor and MHA. No obvious problems found. Change out motor, MWD probe, orienter. Re run same bit. Bit not plugged. Bit recovered at 1,1. RIH wth BHA #7. DS49 bit, 1.04 deg motor, Sperry GR-Directional. Shallow hole test of pulser at 500'. 2.5 bpm, 2800 psi. Pulser worked properly. Test of orienter at 2300', Not getting clicks. Try it a few times. No good. POOH for 2nd new orienter. Tag up, stand back injector, change out SWS MHA, orienter, Sperry equalizer sub. Repair leak in injector hydraulic hose. RIH with BHA #8. Shallow hole test at 500', 2.5/2.5/2700 psi. Pressures are good. Orienter test at 2200', only getting 10 degree clicks. No more orienters on location. RIH. Stop at window to perform reel maintenance. 10368' (CTM uncorrected), Attempt to run thru window with pumps down. Can't get thru. PU, orient to 45L, 20L, 0, 27R, 36R. Make multiple attempts at each tool face, 17 total. Can't get thru. CTP pressure starting to come up. Make trip up to tubing tail to clean out any debris. Try again, can't get thru window. Orient back around to 43L. Set down dry 5 times and did not get thru. Brought pumps up to 1.5 bpm, and popped down 5'. kept pumps on at 1.3 bpm, and drilled off thru whatever is obstructing us. (Fill or cuttings?). Finally got thru the obstruction after 15 additional minutes of drilling. Log tie in pass up from 10424'. Pump pressure is 3600 psi at 2.5 bpm. Make -24' correction. RIH to resume drilling. Ream to bottom from 12390'. Orient to 80R. Getting 100 degrees of reactive torque. Drill to 12,700' at 100 fph average ROP. Only getting 10 degree clicks from the orient, none at times. Wiper trip to window. Took weight running in hole at 11,600' and 11,900'. Tag bottom. Attemp to orient. Not getting any clicks. Tag bottom, get motor work. Dump pressure. Try to orient. Still not getting clicks. TD may be called here. Wiper trip to window. Discuss plan forward with Anchorage, TD called. Tie in to RA marker, -8' correction. RIH and tag corrected TD at 12,699'. POOH slowly and wait on low vise. sweep. Pump 20 bbls 2% KCI. Chase with 28 bbl high vise. flo pro sweep. Circulate sweeps down. Work pipe from 10,360' to 10,380' while low vise and high vise sweep exit bit. Pull through window and chase high vise sweep up hole. Packed Printed: 1/13/2004 3:20:41 PM - ..... BP Page 7 of 11 Operations Summary Report Legal Well Name: 15-33 Common Well Name: 15-33 Spud Date: 2/24/1994 Event Name: REENTER+COMPLETE Start: 12/16/2003 End: 1/9/2004 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2004 Rig Name: NORDIC 1 Rig Number: N1 I , I Date I From - To Hours I Task Code NPT Phase Description of Operations 1/5/2004 16:30 - 18:30 2.00 DRILL N DPRB PROD1 off and got hung up at 10,197' (BHA in tubing tail). Slack off and stack weight down. Work pipe free. Regain circulation. Make multiple passes in 7". Pressure spiked on 1st down pass. 18:30 - 19:00 0.50 DRILL N DPRB PROD1 Try to pull up into tubing tail. Hanging up at 10178' (TTail @ 10155'). Can't get into the tail pipe, but have not packed off yet. Continue working up and down. Geologist looked at a sample caught from this depth, and reports that it is 70% formation sand, and 30% scale, with an occational flake of metal. Pit vol=255 bbls, IAP=270 psi, OAP=403 psi. 19:00 - 19:15 0.25 DRILL N DPRB PROD1 Finally managed to pull up into the tubing after working it numerous times. Pulled 10klbs over getting into tubing. Suspect we have cuttings or some other kind of debris packing off. Pull up hole to 40 degs deviation to chase this stuff out of the hole. Mixing another high viscosity sweep to try to clean out the 7". 19:15 - 21:15 2.00 DRILL N DPRB PROD1 Pump 20 bbls of rig water followed by 30 bbls of high vis sweep built with our rig base mud with 2 additional buckets of Flovis L. Tag up at 10348', top of whipstock. Jet from window up to tubing tail with water, pulled up to 10150' clean, then repeated from window to ttail with high vis sweep. Made 3 passes across 7" with high vis, then 1 final pass at 15 fpm up to the tubing tail. Pulling into the tubing clean each time. Made final cleanout run up to 7000' (35 degs inclination). Did not get a large amount of any type of cuttings, however the sample from last low vislhigh vis sweep was checked. Found to be 95% formation sand, 2% pipe scale, 3% metal. 21:15-21:50 0.58 DRILL N DPRB PROD1 Run back in hole from 7000' to attempt to dry drift thru window. Made it down thru window slick with pumps down. Kick pumps on, tool face was 10L when pumps brought back up. RIH to 10450' to confirm. PUH. 21 :50 - 22:30 0.67 DRILL P PROD1 Log tie in pass over RA tag in whipstock. Make -8' correction. 22:30 - 00:00 1.50 DRILL P PROD1 SD pumps, pull thru the window. Pumps back on, pumping at 2.5 bpm, pulling at 15 fpm in 7". Note, 80% is 50 fpm, so we are way slower than needed to clean the hole. POH pumping at full rate all the way out of the hole. 1/6/2004 00:00 - 00:45 0.75 DRILL P PROD1 Tag up at surface. Just before tag up we got a slug of metal accross the shakers. (About 1 gallon) Looks consistent with metal from milling the window. Mostly fine, short pieces. This is probably what has been causing our problem at the window. Stand back injector. Lay down BHA #8. Bit was recovered surprisingly damaged. It was graded at 6,2,Ringed on the nose. Looked like we had been drilling zone 3 chert instead of zone 1. 00:45 - 01 :00 0.25 CLEAN P COMP Safety meeting prior to picking up cleanout BHA. 01 :00 - 01 :45 0.75 CLEAN N DPRB COMP Pickup cleanout BHA. 5 joints of liner with float eq as per proceedure. 01 :45 - 03:30 1.75 CLEAN N DPRB COMP RIH with cleanout BHA. Tied into flag at 7700' EOP, made a -15' correction. RIH pumping at 4.0 bbls/minute. Ran thru tubing tail slick, 7", and window slick. No problems or weight bobbles observed. 03:30 - 04:00 0.50 CLEAN N DPRB COMP Ran down in open hole while pumping another high viscosity Printed: 1/13/2004 3:20:41 PM Page 8 of 11 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 15-33 15-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 i I I h~~~~_~~~'~~~~~__ TaSkJ Code I NPT I Phase 03:30 - 04:00 0.50 CLEAN N DPRB COMP --------- _. . .-..----- 1/6/2004 04:00 - 05:10 1.17 CLEAN N DPRB COMP 05:10 - 05:25 0.25 CLEAN N DPRB COMP 05:25 - 05:40 0.25 CASE P COMP 05:40 - 06:15 0.58 CASE N COMP 06: 15 - 08:30 2.25 CASE N COMP 08:30 - 12:00 3.50 CASE P COMP 12:00 - 12:15 0.25 CASE P COMP 12:15-12:50 0.58 CASE P COMP 12:50 - 14:00 1.17 CASE P COMP 14:00 - 15:00 1.00 CASE P COMP 15:00 - 15:25 0.42 CASE P COMP 15:25 - 18:30 COMP 3.08 CASE P Start: Rig Release: Rig Number: I Spud Date: 2/24/1994 End: 1/9/2004 12/16/2003 1/9/2004 N1 Description of Operations ..__.._m__________.. sweep. RIH to the horizontal section of hole @ 11000'. Pull back up, continuing to pump at 4 bpm. Went up and down thru the window slick again. Pull at 20 fpm thru the 7" section, while jetting with high vis sweep at 4 bpm. POOH to run liner, pumping at 4 bpm the entire way. Got another slug of metal out of the hole just as we tagged up. Volume estimated at another gallon. Tested sample of cuttings and they seem magnatized. They will stick to anything. Makes it hard to clean out of the hole when they stick to the casing walls I guess. Tagged up at surface. Stand back injector, lay down SWS MHA. Hold PJSM prior to picking up and running liner. MU/Run2-7/8" x 3-3/16" liner as per proceedure. Floats not holding. LD 15 joints of liner. Change out float equipment. Run: 56 joints 2 7/8", 6.16#, L-80, STL liner wI cementralizers, TIW LSL sub at 10,978' 23 joints 3 3/16", 6.2#, L-80, TC 11 liner wI cementralizers, 3 joints 3 3/16", 6.2#, L-80, TC 11 liner wlo cementralizers, 1 joint 31/2",8.8#, L-80, STL 'X' nipple at 10,127' Baker Deployent sub, top at 10,076.8" RD liner running equipment. Install Baker CTC. Pull test and PT. RIH wI liner on CT. Correct to 7,700 EOP flag. PU=40K, SO=25K. Run liner into open hole. Run through window slick. Run in weights with liner: 11,150' 24.5K 11,600' 23.0K 11,700' 21.0K 11,800' 22.0K 11,900' 21.0K 12,000' 18.0K 12,100' 21.0K 12,200' 20.0K 12,300' 20.0K 12,400' 19.0K 12,500' 17.5K Tight spot at 12,518' 12,600' 17.5K Tight spot at 12,651'. Pick up and work pipe through. PU= 46K. MAde it to hard bottom. PU and retag 3 times. Liner at TD. Drop 5/8" ball. Pump ball with mud. Good indication of ball rolling. Ball on seat at 45 bbls away (60 bbls coil vol). Good indication of release at 3800 psi. PU at 36 klbs, was 47 klbs before release. Good indication of release from liner. Start pumping KCL to swap well to water. Notify cementers. Printed: 1113/2004 3:20:41 PM BP Operations Summary Report Page 9 of 11 Legal Well Name: 15-33 Common Well Name: 15-33 Spud Date: 2/24/1994 Event Name: REENTER+COMPLETE Start: 12/16/2003 End: 1/9/2004 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2004 Rig Name: NORDIC 1 Rig Number: N1 I Hours I Code I NPT I Description of Operations Date From - To Task Phase ___.n......· i .. _·w..··w··__··________ ....... ".____. __ n___w."."_ __. .____.____....._.. 1/6/2004 15:25 - 18:30 3.08 CASE P COMP Pumping initially at 2.4/2.4/2900 psi. With KCL around, pumping at 2.412.312250 psi. 18:30 - 18:45 0.25 CEMT P COMP SAFETY MEETING. Review procedure, hazards and mitigation to pump liner cement job. 18:45 - 19:10 0.42 CEMT P COMP Circulate while mix cement to weight. Cement at wt at 1910 hrs. Added 2 bbls to cement volume to make up for fluid loss. 19:10 - 19:15 0.08 CEMT P COMP Press test cement line. 19:15 - 20:15 1.00 CEMT P COMP Stage 26 bbls, 15.8 ppg, G cement with latex. 1.8 bpm, 1800 psi. Stop pump, clear lines, insert dart. Displace cement with 2# Biozan water. 2.8 I 2.5 bpm, 2400 psi, Zero out volume at 48.4 bbls. [Cement at shoe]. Slow rate at 52 bbls displacement to 1.5 bpm, Dart on liner wiper plug at 56.9 bbls. Sheared at 3500 psi, Pump 2.95 I 2.75 bpm, 3700 psi, 0.2 bpm fluid loss with cement on formation. Slow pump to 1.0 bpm at 71 bbls. Bumped plug at 73.0 bbls with 1900 psi. Total returns of 23.6 bbls. Dart held pressure. Bleed off and check floats, OK. Good cement job. 20:15-21:45 1.50 CEMT P COMP Sting out OK. 36K up wt. POH while replace CT volume only with Biozan. 21 :45 - 23:15 1.50 CEMT P COMP Layout BKR CTLRT. Recover 100%. Close swab valve. MIU jetting nozzle and jet BOP stack. 4.2 bpm, 3400 psi. Getting metal shavings over shaker. Made 5 upldown passes until clean returns. 23:15 - 23:30 0.25 EVAL P COMP SAFETY MEETING. Review procedure, hazards and mitigation for MIU Motor, mill and SWS memory CNL/GR/CCL. 23:30 - 00:00 0.50 EVAL P COMP MIU 2.30" mill, motor, xo, 2 jts 1-1/4" CSH, xo, SWS CNL/GR/CCL in carrier, circ sub, disc and XO. 1/7/2004 00:00 - 03:45 3.75 EVAL P COMP Pick up 84 jts of CSH workstring. MIU MHA. Total BHA = 2,707 ft. 03:45 - 05:00 1.25 EVAL P COMP RIH with mill, motor and Memory CNL/GR/CCL. SWS cement UCA sample at 1000 psi at 0330 hrs. 05:00 - 06:00 1.00 EVAL P COMP Log down at 60 fpm from 10,000 ft. Circulate in 20 bbls New FloPro for perforating, 150,000 CPo 0.70 bpm, 900 psi. RIH clean to 12,683 ft. Correct PBTD is 12,664 ft BKB. Tag PBTD at 12,683' CTD twice. CTD not tied-in. Normatl depth correction has been -20 ft. 06:00 - 06:45 0.75 EVAL P COMP Circ. New FloPro to bit. 0.70 bpm, 1470 psi. 06:45 - 08:30 1.75 EVAL P COMP Log up at 30 fpm, laying in perf pill at 0.2 bpm. 08:30 - 09:30 1.00 EVAL P COMP Logged up to 9700'. POH pumping .7 bpm to keep the hole full. 09:30 - 10:00 0.50 EVAL P COMP Tag up at surface, stand back injector. Hold PJSM with rig hand discussing tripping pipe. Hazards and mitigations reviewed. Plan to stop on last stand in the hole to hold PJSM prior to pulling radioactive logging tool to surface. 10:00 - 12:00 2.00 EVAL P COMP Trip CS hydril work string OOH. Stand back 16 stands, lay down the remainder. 12:00 - 12:20 0.33 EVAL P COMP Safety meeting prior to laying down radioactive source in memory logging tool. 12:20 - 12:50 0.50 EVAL P COMP Pull radioactive source, and store in transport container, lay down memory tools, 2 spacer joints, mill and motor. All recovered ok. Printed: 1/13/2004 3:20:41 PM ..... ....... BP Page 1 0 of 11 Operations Summary Report Legal Well Name: 1 5-33 Common Well Name: 1 5-33 Spud Date: 2/24/1994 Event Name: REENTER+COMPLETE Start: 12/16/2003 End: 1/9/2004 Contractor Name: NORDIC CALISTA Rig Release: 1/9/2004 Rig Name: NORDIC 1 Rig Number: N1 Date F_rom - To I Hours Task Code NPT Phase Description of Operations .-...-....-...--..---..-.. .............-.--.- 1/7/2004 12:50 - 13:30 0.67 PERF P COMP Remove memory tool to van, download memory tools. Bring perf guns into the pipe shed and prepare to run. 13:30 - 14:00 0.50 PERF P COMP Pressure test liner lap to 2000 psi. 13:32 pressure=211 0 psi 13:47 pressure=1890 psi 14:02 pressure=1775 psi Lost 335 psi, which is more than 10% pressure over 1/2 hour. Pressure test failed. After consultation with town, we will plan on running a liner top packer. Note - Cement UCA was at 2000 psi at 07:00 this morning. 14:00 - 15:45 1.75 EVAL N WAIT COMP Wait on memory logs to be printed out and for final approval of perforation intervals. 15:45 - 19:30 3.75 PERF N WAIT COMP Recieved updated perf intervals from town. Need to replace 6 guns. Waiting on new guns to be loaded, and transported to location from Deadhorse shop. 19:30 - 20:30 1.00 PERF P COMP Re-pressure test liner lap while waiting on guns. Start press = 2050 psi. Final press [30 min.]= 1860 psi. Lost 190 psi in 30 min. Marginal test. Decide to run liner top packer. 20:30 - 22:00 1.50 PERF N WAIT COMP Load SWS 2" perf guns in pipe shed and re-number guns and double check layout. 22:00 - 22: 15 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for running perf guns. 22:15 - 00:00 1.75 PERF P COMP MIU SWS 2" perf guns, 4 spf, 1/8/2004 00:00 - 02:00 2.00 PERF P COMP MIU total of 84 SWS 2" perf guns and blanks. 02:00 - 03:00 1.00 PERF P COMP MIU BKR 2-1/8" Hyd Disconnect, XO and 16 stds of CSH. MIU BKR 3-3/8" Hyd Disconnect, UplDown fishing jars, Check Valves and Swivel. Perf BHA = 2,741 ft. 03:00 - 03: 15 0.25 PERF P COMP RIH. Unable to circulate, held 500 psi with no rate. POH. 03:15 - 04:00 0.75 PERF N RREP COMP Check Coil for circ, [-60 chill factor], circ. OK, circ 8 bbls. Check Circ thru Perf BHA at surface, OK, 0.8 bpm at 150 psi. Found ice plug in rig choke line, open 2" bypass, circ OK. Steam and thaw choke line. MIU coil to BHA again. Circ. OK at 0.4 bpm at 110 psi. 04:00 - 06:00 2.00 PERF P COMP RIH with Perforating BHA. 0.40 bpm, 100 psi. Tag PBTD of 12,656' BKB at 12,681' up depth. Correct CTD to 12,656 ft. Circ. 8 bbls of new high vis FloPro perf pill. Pull to ball drop position. 42K up wt. 06:00 - 06:30 0.50 PERF P COMP Insert 5/8" AL ball. Displace with 4 bbl FloPro and KCL water at 2 bpm, 2000 psi. Ball on seat at 54.5 bbls (Coil vol=57.7). Bring pressure up to 3000 psi with guns moving. Good indication of fire on pressure. PU weight=46 klbs. POOH with perf guns, pumping at minimum rate to lay in 4 bbls of flowpro to replace displacement. After displacing flowpro, fill across the top to replace voidage. Intervals perforated with 2" 4 spf, 60 deg phase guns 10926'-10973' 11196'-11345' 11378'-11473' 11506'-11580' 11634'-11698' 11719'-11787' v t.. Printed: 1/13/2004 3:20:41 PM ~ .. Page 11 of 11 BP Operations Summary Report Legal Well Name: 15-33 Common Well Name: 15-33 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Hours Task I Code I NPT 1/8/2004 06:00 - 06:30 06:30 - 08:30 08:30 - 08:45 08:45 - 10:00 10:00 - 10:20 10:20 - 16:30 16:30 - 18:00 18:00 - 19:20 19:20 - 21 :50 21 :50 - 23:00 23:00 - 23:30 Start: Rig Release: Rig Number: I Phase I 12/16/2003 1/9/2004 N1 Spud Date: 2/24/1994 End: 1/9/2004 0.50 PERF P --f----.-.-.- .--. ...... -.-. ......-... .... ______m.._._ --.--.----.-------------. Description of Operations 2.00 PERF P 0.25 PERF P 1.25 PERF P 0.33 PERF P 6.17 PERF P 1.50 PERF P 1.33 ZONISO P 2.50 ZONISO P 1.17 ZONISO P 0.50 ZONISO P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 23:30 - 00:00 0.50 ZONISO P COMP 1/9/2004 00:00 - 01 :00 1.00 ZONISO P COMP 01 :00 - 01 :30 0.50 ZONISO P COMP 01 :30 - 02:00 0.50 ZONISO P COMP 02:00 - 02: 15 0.25 RIGD P POST 02: 15 - 04:00 1.75 RIGD P POST 04:00 - 05:00 1.00 RIGD P POST 05:00 - 06:00 1.00 RIGD P POST 11901 '-11929' 11969'-12049' 12079'-12189' 12380'= 12420' 12590' -12650' POOH Safety meeting re: laying down CS hydril work string. Lay down CS hydril work string. PJSM RE: Laying down perf guns. Lay down spent perf guns. Many blank guns. All shots fired. Clear rig floor and load out perf guns. MIU Baker 4.5" Liner top packer BHA. BHA = 81.3'. RIH with Baker 4.5" KB Packer and seal assembly. Min. ID. = 2.39" in seal assembly. Up wt at 10000' = 38K. Dwn wt = 26K. Sting into liner deployment sleeve with pump at .5 bpm, Stk 1 OK. wt at 10,100.6' [depth not tied-in]. Top of liner Deployment sleave at 10,077 ft. Sting out and pick up to ball drop spot. Insert 5/8" AL ball and displace with KCL water. 1.5 bpm, 600 psi. Slow to 0.6 bpm at 45 bbls. Ball on seat at 52.5 bbls. RIH and stack 10K at 10100.6 ft. Pick up 2 ft off tag. Set Packer with 2500 psi. Pick up to 40K. Packer is set. Set down 10K again at 10098'. Press test packer seal with 2000 psi between CT and 4.5" tubing. Chart packer seal press test. 2025 psi initial press, 2000 psi final press. Good test. Release from Baker KB Packer with 3800 psi. Pick up free with 38K. POH with Baker running tools. Circ. at 3.2 bpm, 1600 psi to clean tubing while POH. POH with Baker running tools for setting liner top packer. Circ at 3.2 bpm to clean well while POH. Freeze protect well with MEOH from 2000 ft to surface while POH. Layout Baker tools. Recover 100%. Close swab valve. SAFETY MEETING. Review procedure, hazards and mitigation for displacing coil with N2. Pressure test line. Displace coil to N2. Bleed down coil pressure. Clean rig pits, tiger tank and cuttings tank. Cut off CTC. Pull CT from injecter head and secure CT. Remove Guide arch. Set injecter head in pipe bay. Nipple down BOPE. NIU tree cap and pressure test. RELEASED RIG AT 0600 HRS, 01/09/2004. A TOTAL OF 9 DAYS AND 5.5 HOURS FROM RIG ACCEPT TO RIG RELEASE. Further Telex entries carried on the DS 5-41 morning reports. Presently WOW for Derrick down rig move due to 20-35 mph winds. Printed: 1113/2004 3:20:41 PM · 2204' ., 4-1/2" CAMeO TRDP-4A SSSV NIP, ID = 3.855" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 7" LNR, 26#, 13-CR-SO, ,0383 bpf, ID = 6.276" I I I I : I l 14-1/2" SL TD LNR, 12.6#, L-80, ,0152 bpf, ID - 3,958" H 12358' PËRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE DA TE REV BY 03131/94 08/13/99 02/08/02 06/13/03 09/17/03 1 0105103 DATE REV BY COMMENTS GAS LIFT MANDRELS ATCH RM T2 T2 T2 PORT DATE o 10/05/03 o 10/05/03 o 1 0/05/03 o 10/05/03 4-112" OTIS X NIP, 10 = 3,813" I 7" X 4-1/2" BAKER SABL-3 PKR I TOP OF 4-1/2" SL TD LNR 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" 3-3/16" X 2-7/8" XO PBTD 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" PRUDHOE BA Y UNIT WELL: ÆRMIT No: API No: SEe 22, T11N, R14E. 649.62' FEL & 1473.23' FNL BP Exploration (Alaska) . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-33 B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,327.19' MD 10,345.00' MD 12,699.00' MD . (if applicable) 8°,3-'· \ q ~\ 14-Jan-04 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) '~~Dn\~ RECEIVED "" ., 6 f")'ì'1 ! ".: !. 'Jlit.' t..... '~. Q . c.. \,; I A!~~aO¡! & Gas Cons, Commîssiol'! ,,':11chorage Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 15 15-33B Job No. AKMW0002846007, Surveyed: 5 January, 2004 Survey Report 12 January, 2004 . Your Ref: API 500292244802 Surface Coordinates: 5960923.44 N, 676021.45 E (70017' 55.8121" N, 148034' 27.8175" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 960923.44 N, 176021.45 E (Grid) Surface Coordinates relative to Structure Reference: 2091.87 N, 227.58 W (True) Kelly Bushing Elevation: 69.60ft above Mean Sea Level Kelly Bushing Elevation: 69. 60ft above Project V Reference Kelly Bushing Elevation: 69.60ft above Structure Reference sper"'r"'v-sUï1 DRILLINGm. SeRVICeS A Halliburton Company r' " DEFINITI E . . Survey Ref: svy4152 .. Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 -15-33B Your Ref: API 500292244802 Job No. AKMW0002846007, Surveyed: 5 January, 2004 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) 10327.19 65.460 312.040 8569.26 8638.86 3127.18N 3095.79 W 5963977.25 N 672853.26 E 3255.21 Tie On Point 10345.00 65.780 311.800 8576.61 8646.21 3138.02 N 3107.86 W 5963987.80 N 672840.94 E 2.176 3267.84 Window Point 10373.61 67.670 307.980 8587.92 8657.52 3154.87 N 3128.03 W 5964004.17 N 672820.38 E 13.930 3288.85 10404.32 69.600 303.940 8599.11 8668.71 3171.65N 3151.17 W 5964020.41 N 672796.85 E 13.768 3312.85 10435.75 71.810 299.890 8609.50 8679.10 3187.32 N 3176.35 W 5964035.49 N 672771.31 E 14.047 3338.81 . 10465.18 72. 160 296.170 8618.61 8688.21 3200.47 N 3201.05 W 5964048.05 N 672746.31 E 12.079 3364.16 10479.85 71.770 294.340 8623.15 8692.75 3206.42 N 3213.66 W 5964053.71 N 672733.56 E 12.156 3377.07 10512.53 71.190 289.100 8633.54 8703.14 3217.89 N 3242.44 W 5964064.49 N 672704.53 E 15.307 3406.41 10550.05 69.520 284.170 8646.16 8715.76 3228.01 N 3276.28 W 5964073.82 N 672670.46 E 13.150 3440.73 10592.85 69.520 279.230 8661.14 8730.74 3236.13 N 3315.53 W 5964081.02 N 672631.03 E 10.812 3480.35 10628.01 69.430 274.470 8673.47 8743.07 3240.06 N 3348.21 W 5964084.18 N 672598.27 E 12.681 3513.19 10661.85 69.160 268.660 8685.45 8755.05 3240.93 N 3379.83 W 5964084.31 N 672566.63 E 16.079 3544.82 10702.16 71.190 263.370 8699.13 8768.73 3238.28 N 3417.64 W 5964080.78 N 672528.89 E 13.332 3582.44 10738.48 71.890 261.790 8710.63 8780.23 3233.83 N 3451.80 W 5964075.53 N 672494.85 E 4.554 3616.32 10776.15 72.510 253.500 8722.16 8791.76 3226.16 N 3486.80 W 5964067.04 N 672460.04 E 21.016 3650.87 10807.63 73.570 248.750 8731.35 8800.95 3216.42 N 3515.28 W 5964056.64 N 672431.79 E 14.820 3678.80 10840.32 73.130 243.460 8740.72 8810.32 3203.74 N 3543.91 W 5964043.29 N 672403.47 E 15.562 3706.72 10882.19 73.920 240.290 8752.60 8822.20 3184.81 N 3579.31 W 5964023.54 N 672368.52 E 7.501 3741.08 10916.26 75.070 237.120 8761.71 8831.31 3167.76 N 3607.36 W 5964005.83 N 672340.88 E 9.580 3768.20 10947.74 76.740 239.060 8769.37 8838.97 3151.62 N 3633.27 W 5963989.10 N 672315.35 E 7.992 3793.24 10981.10 81.850 244.690 8775.57 8845.17 3136.20 N 3662.17 W 5963972.99 N 672286.83 E 22.570 3821.28 11020.29 92.600 255.620 8777.47 8847.07 3122.96 N 3698.88 W 5963958.91 N 672250.43 E 39.066 3857.26 . 11057.07 92.160 260.380 8775.95 8845.55 3115.33 N 3734.82 W 5963950.43 N 672214.69 E 12.986 3892.74 11091.07 94.180 263.720 8774.07 8843.67 3110.63 N 3768.43 W 5963944.95 N 672181.19 E 11 .467 3926.07 11124.68 94.270 268.660 8771.59 8841.19 3108.40 N 3801.87 W 5963941.94 N 672147.82 E 14.660 3959.34 11160.36 92.250 272.010 8769.56 8839.16 3108.61 N 3837.48 W 5963941.31 N 672112.21 E 10.950 3994.91 11191.12 90.570 276.590 8768.80 8838.40 3110.92N 3868.14 W 5963942.90 N 672081.51 E 15.855 4025.65 11224.84 89.250 280.990 8768.85 8838.45 3116.07N 3901.45 W 5963947.27 N 672048.08 E 13.623 4059.19 11260.21 90.220 279.410 8769.02 8838.62 3122.33 N 3936.26 W 5963952.72 N 672013.13 E 5.242 4094.28 11293.77 92.510 277.820 8768.22 8837.82 3127.36 N 3969.43 W 5963956.96 N 671979.86 E 8.306 4127.66 11343.71 94.710 273.240 8765.07 8834.67 3132.16 N 4019.02 W 5963960.60 N 671930.16 E 10.157 4177.44 11373.55 92.250 267.600 8763.26 8832.86 3132.38 N 4048.79 W 5963960.12 N 671900.40 E 20.587 4207.18 11410.23 89.430 267.250 8762.72 8832.32 3130.73 N 4085.43 W 5963957.62 N 671863.81 E 7.747 4243.68 11447.03 88.460 266.190 8763.40 8833.00 3128.63 N 4122.16 W 5963954.65 N 671827.14 E 3.904 4280.25 11473.54 87.930 260.910 8764.23 8833.83 3125.65 N 4148.48 W 5963951.06 N 671800.90 E 20.007 4306.38 12 January, 2004 - 13:24 Page 2 of 4 DrillQuest 3.03.05.005 . Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 - 15-33B Your Ref: API 500292244802 Job No. AKMW0002846007, Surveyed: 5 January, 2004 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) (O/100ft) 11510.96 88.370 260.200 8765.44 8835.04 3119.51 N 4185.37 W 5963944.06 N 671764.16 E 2.231 4342.90 11539.43 91.280 265.130 8765.53 8835.13 3115.88 N 4213.60 W 5963939.77 N 671736.02 E 20.106 4370.90 11574.14 91.890 267.780 8764.57 8834.17 3113.73 N 4248.22 W 5963936.81 N 671701.46 E 7.831 4405.36 11610.58 91.980 271.830 8763.34 8832.94 3113.61 N 4284.64 W 5963935.84 N 671665.06 E 11.111 4441.72 11637.03 91.700 275.860 8762.49 8832.09 3115.38 N 4311.01 W 5963936.99 N 671638.65 E 15.265 4468.15 . 11666.06 90.750 278.530 8761.87 8831.47 3119.02N 4339.80 W 5963939.95 N 671609.78 E 9.760 4497.09 11698.64 88.370 283.460 8762.12 8831.72 3125.23 N 4371.77 W 5963945.41 N 671577.68 E 16.802 4529.34 11729.27 88.190 288.220 8763.04 8832.64 3133.58 N 4401.21 W 5963953.07 N 671548.05 E 15.544 4559.18 11763.58 90.480 292.270 8763.44 8833.04 3145.45 N 4433.39 W 5963964.18 N 671515.60 E 13.559 4591.94 11796.1 0 90.840 296.850 8763.06 8832.66 3158.96 N 4462.96 W 5963977.00 N 671485.72 E 14.126 4622.17 11834.92 88.720 294.030 8763.21 8832.81 3175.64 N 4498.01 W 5963992.85 N 671450.29 E 9.088 4658.05 11864.42 88.550 292.620 8763.91 8833.51 3187.31 N 4525.09 W 5964003.89 N 671422.94 E 4.813 4685.70 11897.09 87.840 289.450 8764.94 8834.54 3199.03 N 4555.56 W 5964014.89 N 671392.20 E 9.939 4716.75 11930.44 85.550 286.460 8766.87 8836.47 3209.30 N 4587.23 W 5964024.41 N 671360.30 E 11.281 4748.91 11969.28 84.760 281.870 8770.15 8839.75 3218.76 N 4624.75 W 5964032.99 N 671322.58 E 11.950 4786.86 12003.78 84.580 278.700 8773.35 8842.95 3224.90 N 4658.54 W 5964038.33 N 671288.65 E 9.164 4820.93 12038.50 86.610 279.060 8776.02 8845.62 3230.24 N 4692.74 W 5964042.87 N 671254.33 E 5.937 4855.37 12069.66 89.600 279.760 8777.05 8846.65 3235.33 N 4723.46 W 5964047.24 N 671223.50 E 9.855 4886.31 12104.71 88.370 274.470 8777.67 8847.27 3239.67 N 4758.22 W 5964050.77 N 671188.65 E 15.493 4921.25 12134.76 90.660 271.650 8777.93 8847.53 3241.28 N 4788.22 W 5964051.67 N 671158.62 E 12.088 4951.30 12163.49 89.600 267.070 8777.86 8847.46 3240.95 N 4816.94 W 5964050.68 N 671129.91 E 16.363 4979.96 12194.31 88.110 263.370 8778.48 8848.08 3238.39 N 4847.64 W 5964047.39 N 671099.28 E 12.940 5010.48 . 12224.31 87.050 259.500 8779.74 8849.34 3233.92 N 4877.28 W 5964042.23 N 671069.76 E 13.364 5039.84 12254.29 88.630 257.210 8780.87 8850.47 3227.88 N 4906.62 W 5964035.50 N 671040.57 E 9.275 5068.83 12286.18 90.310 254.560 8781.17 8850.77 3220.10 N 4937.54 W 5964027.00 N 671009.84 E 9.838 5099.30 12317.33 89.780 251.210 8781.15 8850.75 3210.94 N 4967.30 W 5964017.14 N 670980.30 E 10.888 5128.54 12354.54 92.780 248.750 8780.31 8849.91 3198.20 N 5002.25 W 5964003.60 N 670945.66 E 10.425 5162.78 12390.95 95.150 253.680 8777.80 8847.40 3186.51 N 5036.62 W 5963991.10 N 670911.57 E 14.993 5196.49 12438.85 93.830 261.960 8774.04 8843.64 3176.45 N 5083.26 W 5963979.95 N 670865.18 E 17.451 5242.54 12487.81 89.600 262.670 8772.57 8842.17 3169.90N 5131.75W 5963972.27 N 670816.86 E 8.760 5290.62 12530.55 90.310 263.720 8772.61 8842.21 3164.84 N 5174.19 W 5963966.21 N 670774.55 E 2.966 5332.73 12566.76 88.990 267.780 8772.83 8842.43 3162.16 N 5210.29 W 5963962.69 N 670738.52 E 11 .790 5368.64 12595.54 89.340 270.420 8773.25 8842.85 3161.70 N 5239.06 W 5963961.56 N 670709.77 E 9.252 5397.35 12627.80 90.150 272.440 8773.39 8842.99 3162.51 N 5271.31 W 5963961.61 N 670677.51 E 6.746 5429.60 12661.45 91.280 275.880 8772.97 8842.57 3164.95 N 5304.86 W 5963963.26 N 670643.91 E 10.759 5463.23 12 January, 2004 - 13:24 Page 3 of4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 15 -15-33B Your Ref: API 500292244802 Job No. AKMW0002846007, Surveyed: 5 January, 2004 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) '12699.00 91.280 275.880 8772.13 8841.73 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 3168.80 N 5342.20 W 5963966.23 N 670606.49 E 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 273.000° (True). Magnetic Declination at Surface is 25.485° (31-Dec-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12699.0Oft., The Bottom Hole Displacement is 6211.31ft., in the Direction of 300.675° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10327.19 10345.00 12699.00 8638.86 8646.21 8841.73 3127.18 N 3138.02 N 3168.80 N 3095.79 W 3107.86 W 5342.20 W Tie On Point Window Point Projected Survey Survey tool proaram for 15-338 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9629.99 0.00 8263.74 9629.99 12699.00 8263.74 AK-1 BP _HG (15-33) 8841.73 MWD Magnetic (15-33) II. BPXA Dogleg Vertical Rate Section Comment (O/100ft) 0.000 5500.72 Projected Survey . . 12 January, 2004 - 13:24 Page 4 of4 DrillQuest 3.03.05.005 -- j . l , FRANK H. MURKOWSKI, GOVERNOR I ¡ l AI4ASIiA OIL AND GAS I CONSERVATION COMMISSION ! ¡ 333 W. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Field PBU 15-33B BP Exploration (Alaska), Inc. Permit No: 203-194 Surface Location: 558' SNL, 5171' WEL, Sec.22, TllN, R14E, UM Bottomhole Location: 2692' NSL, 70' WEL, Sec. 17, TllN, R14E, UM Dear Mr. McCarty: 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 unt il all 0 ther required permits a nd approvals ha ve been is sued. 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). Sffi~~. SarahPalffi 1 Chair BY ORDER å~HE COMMISSION DATED this day of~, 2003 D¿ce¡rziJer cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section \.J GA- H [-z. 'it 2. 00 ~ ~ . STATE OF ALASKA _ ALASKA 0 ND GAS CONSERVATION COM_SION PERMIT TO DRILL 20 MC 25.005 1a. Type of work o Drill 181 Redrill rb. Current Well Class o Exploratory 181 Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: ISI Blanket o Single Well 11. Well Name and Number: / BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU 15-33B 3. Address: 6. Proposed Depth: 12. Field 1 Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12850 TVD 8810 Prudhoe Bay Field 1 Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028305 558' SNL, 5171' WEL, SEC. 22, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: December 15, 2003 /' 2293' SNL, 3457' WEL, SEC. 16, T11 N, R14E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2692' NSL, 70'WEL, SEC. 17, T11N, R14E, UM 2560 26,400' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. Distance to Nearest Well Within Pool Surface: X-676021 y-5960923 Zone-ASP4 (Height above GL): 69.6' feet 15-45A is 378' away at 10331' MD 16. Deviated Wells: 17. Anticipated pressure (see 20 AAC 25.035) / Kickoff Depth 10350 ft Maximum Hole Angle 90 0 Max. Downhole Pressure: 3225 psig. Max. Surface Pressure: 2169 psig 18. Casing Program Specifications Setting Depth Quantity Of Cernént Size Top Bottom (c.f. or sacks) Hole CasinQ WeiQht Grade Couplinq LenQth MD TVD MD TVD (includinQ staQe data) .~ . If' x '1 ',~ 4" :)<~ "f:" x ';-7 W í~.;t 616r. L-80 TCIII STL 2750' 10100' 8458' 12850' 8810' 142 sx Class 'G' -' 19. PRESENT WELL.CQNDITION SUMMARY(To becoll'lpleted for RedrillAND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft):1 Junk (measured): 14111 8838 N/A 14080 8842 N/A ;~~Inn· » ... > 1 "'...."tH> ii>···Sizei ...... i.>i v()lum~ .MD TV!:) » Structural - Conductor 112' 20" 260 sx Arcticset 112' 112' 3603' 13-3/8" 1205 sx PF 'E', 375 sx Class 'G' 3603' 3643' Intp.r 9683' 9-5/8" 751 sx Class 'G' 9683' 8292' Production I inp.r 1473' 7" 286 sx Class 'G' 9921' - 11394' 8426' - 8839' Liner 1199' 4-1/2" Uncemented Slotted Liner 11182' - 12381' 8821' - 8843' Liner 3670' 3-3/16" x 2-7/8" 221 sx Class 'G' 10441' -14111' 8683' - 8838' Perforation Depth MD (ft): 12600' - 14080' IPerfOration Depth TVD (ft): 8850' - 8842' 4-1/2" Slotted Section: 11368' - 12358' 4-1/2" Slotted Section: 8838' - 8842' 20. Attachments ISI Filing Fee ISI BOP Sketch ISI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report ISI Drilling Fluid Program 1S120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas McCarty, 564-4378 Printed Name Thomas McCarty <" Title CT Drilling Engineer Date II II IJI,; " Prepared By Name/Number: SiQnature 7¿:;~ .~ /./ /"j - Phone 564-4378 Terrie Hubble, 564-4628 --/ / Commission Use Only Permit To Drill I API Number: I ~ermit APproval{ :':i I:~ 'I~I ~ee cover letter for Number: .20..3 - /'19 50-029-22448-02-00 Date: kr other requirements Conditions of Approval: Samples Required DYes gNo Mud Log Requiréð I I DYes MNo Hydrogen Sulfide Measures ~Yes DNo Directional Survey Required ~Yes []No Other:Te. S 1- "BoPE Fe ~~OO P~/' Original Signed By Date lJ lì. AI:? Sarah palin BY ORDER OF Approved Bv: COMMISSIONER THE COMMISSION Form 10-401 Revised 3/2003 ORiGiNAL S~bm~ In Duplicate Logging · MWD Gamma Ray wi Directional · See attached directional plan. Max. planned hole angle is 90° · Magnetic and inclination surveys will be taken every 30 ft. No gyro wi · The nearest wel s 15-45A Ctr-Ctr distance is 378' at 10331 · The nearest ne is approx. 26,400' be in the pool Prudhoe Bay property run In the open hole section Memory CNL wi be , be run run inside the liner. 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. / Parent Well Casings OH size Burst (psi) Collapse (psi) 13%" 68#, L-80, Seal Lock - surface to 3568' 17% 5020 2270 9%" 47#, NT -80 - Int surface 3568 - 9635 12Y-. 6870 4760 7" 26#, 13Cr-8Q- Production Liner 9635-11394 8% 7240 5410 3-3/16", L80 TCII- Production Liner 10441-12488 4Ys 8520 11170 2-7/8", L80 STL- Production Liner 12488-14111 3% 10570 11170 Planned Sidetrack Casinç¡s 3-3/16" 6.2#, L-80, TCII- Prod LNR 10100-11100 4Ys 8520 7660 21'," 6.5#, L-80, STL - Prod LNR 11100-12850 3% 10570 11170 Casing Program: / The production liner will be solid 33/16TCII x 2W' STL from a TDìS:2850' (-8810'ss) to 10,100'MD (8,458'ss) within the 4W' tubing. The liner will be cemented wit -29 bls, 15.8ppg class g cement with a planned TOC at 10,250'(8535'TVDss) within the 4W' tubing. Tetrack is planned for 800' of perforations in Zone 1. Disposal · All drilling and completion fluids and all other Class · All Class I wastes will go to Pad 3 for disposal Mud Program · Phase 1: Seawaterl 2% KC · Phase 2,3: Mill with seawater 1 %Ib biozan. dri wastes wi with Solids Free Flo-Pro (8.6 - 8.7 ppg) go to Grind & Inject or Pad 3. I Phase 3 Operations: Drill and Complete sidetrack: Dec 15th, 03 . Drill the build & lateral sections of the sidetrack as per the attached directional plan. The max hole anglo/' will be _90°. Solid 33/16 x 2Ys" liner will complete the sidetrack, which will be cemented and selectively perforated. The cement top will purposely be left shallow to provide options for a future sidetrack opportunity. A liner top packer will be run, if the cement lap does not pass a pressure test to 2500psi Phase 2 Operations: Nordic 1 · Mill 3.8" window, most permitting. Prep Work: Planned for kely done by Nordic 1 CTD Nov 25th, 03. rig but may be done with service coi time Phase 1 Operations: Non rig Prep Work: · Drift the production tubing & liner. · Set 2-7/8" Cast Iron Bridge Plug (CIBP) in 3-3/16" liner at approx. · nstall whipstock at approx. 10,350'md (8577'TVDss) e BP 15-33B CTD Sidetrack 10600'md (8669'TVDss) e e e Hazards / · H2S was measured at 10ppm on 8/16/2001 on 15-33 · Two pr09nosed faults will be cut by the wellpath. The risk of a lost circulation event is considered moderate. Reservoir Pressure · Res. press. is estimated to be 3225psi at 8800'ss (7.1 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2169 psi. / TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = FMC CrN BAKER C 69.6' ? 2522' 97 @ 14039' 13923' 8800' SS 13-3/8" CSG, 68#, NT-80, ID = 12.415" I 3568' Minimum ID = 2.380" @ 12488' 3-3/16" X 2-7/8" CROSSOVER 9-5/8" CSG, 47#, NT-80, ID = 8.681" H I TOP OF 7" LNR H e 15-33A . 9635' 9635' 1 TOPOF3-3/16"LNR 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I TOP OF 4-1/2" LNR 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I TOP OF 4-1/2" SL TO LNR 17" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276" 14-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, 10= 3.958" H 1 TOP OF 4-1/2" LNR I l 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID=3.958" I 12381' SA : HORIZONTAL WELL - 70° @ 10557' AND 90° @ 11417' - SIDETRACK KICKOFF DEPTH - 12381' -CHROME7" LNR 2204' -l 4-1/2" CAMCO TRDP-4A SSSV NIP, ID = 3.855" ST MD lVD 1 3022 3001 2 5164 4996 3 7054 6702 4 9404 8141 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 19 OTIS DMY RM 22 OTIS DMY 12 37 OTIS DMY T2 58 OTIS DMY 12 PORT DA TE o 10/05/03 o 1 0/05/03 o 10/05/03 o 10/05/03 10138' 10155' 4-1/2" OTIS X NIP, ID=3.813" 1 7" X 4-1/2" BAKERSABL-3 PKR I 4-1/2" OTIS X NIP, ID=3.813" 1 4-1/2" OTIS XN NO GO NIP, ID = 3.725" 3" DEPLOYMENT SLV I 10185' 10202' 10441' 10547' 4-1/2" WLEG (BEHINDCT LNR) 10556' ELMD TT LOGGED 10/01/94 1 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" PERFORA TION SUMMARY REF LOG: ? ANGLE AT TOP PERF: 88 @ 12600' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12600 - 12700 0 08/13/99 2" 4 12830 - 13020 0 08/13/99 2" 4 13150 - 14080 0 08/13/99 DATE 03/31/94 08/13/99 02/08/02 06/13/03 09/17/03 10/05/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK RNlTP CORRECTIONS CMO/TLP KB ELEVATION CORRECTION CNJ/TLP MINIMUM 10 INFO CORRECTION JCM/TLP GL V C/O 1 12488' H 3-3/16" X 2-7/8" XO I 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" I PBTD 1 DATE COMMENTS REV BY PRUDHOE BA Y UNrr WELL: 15-33A PERMrr No: 1990600 API No: 50-029-22448-01 SEC 22, T11 N, R14E, 649.62' FEL & 1473.23' FNL BP Exploration (Alaska) FMC CWII BAKER C 69.6' ? 2522' 97 @ 14039' 13923' 8800' SS TREE'::; WELLHEAD ::; . ACTUATOR::; KB. ELEV ::; SF. ELEV ::; KOP::; Max Angle ::; Datum MO ::; DatumTVD::; 2204' - 4-1/2" CAMCO TRDR-4A SSSV NIP, 10::; 3.855" 3568' GAS LIFT MANDRELS PE VLV LATCH OTIS DMY RM OTIS OMY T2 OTIS DMY T2 OTIS OMY T2 PORT DA o 10/05/03 o 10105/03 o 10/05/03 o 10/05/03 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID::; 3.958" 10155' 10155' -1/2" LNR, 12.6#, L-80, 7" LNR, 26#, 13-CR-80, .0383 bpf, ID::; 6.276" ¡ I ¡ ¡ ¡ j TOP OF 4-1/2" SL TD LNR I 14-1/2" SL TD LNR, 12.6#, L-80, .0152 bpf, ID::; 3.958" H 12358' PERFORA TION SUMMARY REF LOG: ? ANGLEATTOPPERF: 88 @ 12600' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 12600 - 12700 2" 4 12830 - 13020 2" 4 13150 - 14080 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID::; 2.80" 3-3/16" X 2-7/8" XO PBTD 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID::; 2.441" DATE 03/31/94 08/13/99 02/08/02 06/13/03 09/17/03 10/05/03 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK RNlTP CORRECTIONS CMO/TLP KB ELEVATION CORRECTION CNJ/TLP MINIMUM ID INFO CORRECTION JCM/TLP GL V C/O DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-33A PERMIT No: 1990600 API No: 50-029-22448-01 SEC 22, T11N, R14E, 649.62' FEL & 1473.23' FNL BP EKp!oratil:m (Ala$ka) BP Amoco P....nt W.llpath~ Tie on MO: WELLPATH DETAILS Plan12 15-33B 500282244802 '''33 10327.19 Rig: Ref.a.tumr V.seedon ..... 273.00' 47133 al24J1994 ~OO ~~~ .... ~t; ::::I~D REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Well Centre: 15-33. True North Vertical (TVD Reference: System: Mean Sea Levef Section (VS Reference: Slot· 33 (Q.DON,a.DOE) Measured Depth Reference: 47: 33 2124/1994 00:00 69.60 Calculation Method: Minimum Curvature ~.. T._ ti IiS.4CI 312.04 .'''.n 312T.'8 -3095.'19 .... 0.00 3285.2t H.87 311.73 8!178.811 3t...1M! I 2.'. 325.37 3271.38 87.43 310.71' 8!1H.5. 3153.16 .... :nO.DO n85.8. T".4. 30LIIIt .599.11& 317&.75 20.00 330.00 3318.5' 8a.H 288.42 8S31... 32'..... 20.00 250.00 :utlZ.77 88.23 21S4.... :~=::f 3228.17 20.00 2115.00 §i~~~ 87.11C1 :U3.32 3202." 20.00 :~j! 88.H 221.82 :~~:~: 3146.12 20.00 88.50 253.87 ,...... 20.00 '..11 Z8.... ä§~ 3067.17 12.00 ª~ ¡!~ 261M 3095.15 12.00 210.00 ä~~¡ 312173 ~!~ã 1MI.00 3151.61 270.00 l:~~~; :ffi~j: 90.00 270.00 An,,",,"CNI 8569.28 1032.7.19 TIP 857110.66 10350.00 KOP 8586.59 10370.00 3 8599.66 10410.00 4 8631.«;8 5 8668.87 . 8706.81 7 8743.761 8 8780.361 . 8788.02 11308.44 10 8792.8511558.44 11 8797.23 1180&.44 12 8800.93 12058.44 13 15 8808.92 12558.44 15 18 8&09.68 12850.00 TD TVD +NI-S +EI·W Shape 0.00 3283.72.-3486.85 Potfgon OJJO 3434.89-4900.79 I'ot;gor! :a~:æ =:~ :æ:~ = j5-J3BP0tv00n2.1 ¡ffli~~f~ 7700 7800m 7900 .... C 8000 $ Ò8100 Q ;!:.8200 -:: .c: i. 8300} QI . CI 6400 ¡¡ U 8500 :e QI 8600 > ~ 8700 .. ... 8800. + 8900 ';;'J3p':-:m'31 11~33~T21i 1:,,:\",.i~<):JPI!ì.! T l,M .¡ / Plan: Plan #2 (15-331Plan#2 15-338) Created By: Bnj Potnis Date: 11/11/2003 LEGEND C-2a ¡CoZD} C-2D C-20A) C-2D G-ZOB) 15·33 (15-33) 15·33 ¡15-33A) 15·33 15-33PB1) 15·33 15-33PB2) Planln 15-338 Plan #.2 Azimuths to True North Magnetic North: 25.54' Stre~;t~~;~~f~~~ Dip Angle: 80.8?' Date: 11/11/2003 Model: bggm2003 Contar.t information: Direct (907) 267w6613 Baker Hugha$ I~~TË~~; r9~~Oi3~§P62beq·(:orn 1:I:1!1"!"i:'\' .;.~ ~}I: 4200 e ....4000··. C ~ 3800m' Q Q 3600 N ... +,,3400 ~ 3200 o ~ 3000 -. i"2800 .. S 2600 U) "5.:::';:\ L.¡I..:] 1,1 :\::1: '-,"11 : ";.I'!\;": ,u;g¡;I, I~: :::: ¡:: I;¡ " ~ .\ "-'"'1'.,,",.,', é ---..---.----.-.---. ----- 1~'· In I')" " I' . t -- ~. . ,.> -------~. '" ~ ' . .,.¡ + . ' ' , "'" ·",I"I.':.!I,,:):!:! ._._.-.._.~--_..,-._._.__._.._.._.. I,' /" C': --'-. m ":01' e West(-)/East(+) [200ft/in] 1';: . :e i';i .~ "; -:'¡:J, ;;; 4100 4200 4300 4400 4500 4600 Vertical Section at 273.00· [100ft/in] 11.t1-1./2003 2:40 PM e e BP-GDB Baker lJughes INTEQ Planning Report Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 15 15-33 Plan#2 15-33B Date: 11/11/2003 Time: 14:42:10 Page: Co-ordinateC'IE) Referenee: Well: 15-33, True North Vertical (TVD) Referenee: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,273.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ..---..-.. .----.------... -.-..---.- Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213 W True 1.34 deg Well: 15-33 Slot Name: 33 15-33 Well Position: +N/-S 2092.72 ft Northing: 5960924.06 ft Latitude: 70 17 55.818 N +E/-W -226.40 ft Easting : 676021.58 ft Longitude: 148 34 27.813 W Position Uncertainty: 0.00 ft Wellpath: Plan#215-33B 500292244802 Current Datum: 47 : 33 2/24/1994 00:00 Magnetic Data: 11/11/2003 Field Strength: 57582 nT Vertical Section: Depth From (TVD) ft 38.60 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 15-33 10327.19 ft Mean Sea Level 25.54 deg 80.87 deg Direction deg 273.00 Height 69.60 ft Targets :\1ap Map <-- Latitude -> <-- Longitude -> TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dir. ft ft ft ft ft ..--.--..... ----.........--..... ____..__.__.._n. m__..__..... ..-------... 15-33B Polygon2.1 0.00 3283.72 -3486.85 5964125.00 672459.00 70 1828.105 N 148 36 9.504 W -Polygon 1 0.00 3283.72 -3486.85 5964125.00 672459.00 70 1828.105 N 148 36 9.504 W -Polygon 2 0.00 3222.75 -3702.35 5964059.00 672245.00 70 18 27.505 N 148 36 15.788 W -Polygon 3 0.00 3277.67 -4253.25 5964101.00 671693.00 70 18 28.042 N 148 36 31.855 W -Polygon 4 0.00 3374.82 -5240.31 5964175.00 670704.00 70 18 28.991 N 148 37 0.644 W -Polygon 5 0.00 3325.63 -5958.71 5964109.00 669987.00 70 18 28.502 N 148 3721.595 W -Polygon 6 0.00 3122.21 -6071.51 5963903.00 669879.00 70 18 26.501 N 148 37 24.880 W -Polygon 7 0.00 3000.35 -5439.15 5963796.00 670514.00 70 18 25.307 N 148 37 6.435 W -Polygon 8 0.00 2924.77 -4006.43 5963754.00 671948.00 70 18 24.573 N 148 3624.652 W -Polygon 9 0.00 2909.23 -3684.69 5963746.00 672270.00 70 18 24.421 N 148 36 15.269 W -Polygon 10 0.00 3121.95 -3242.55 5963969.00 672707.00 70 18 26.515 N 148 36 2.378 W 15-33B Fault 1 0.00 3434.89 -4900.79 5964242.99 671042.00 70 18 29.584 N 148 36 50.743 W -Polygon 1 0.00 3434.89 -4900.79 5964242.99 671042.00 70 18 29.584 N 148 36 50.743 W -Polygon 2 0.00 3001.30 -4582.84 5963816.99 671370.00 70 18 25.322 N 148 36 41.463 W 15-33B Fault 2 0.00 3401.13 -5850.90 5964186.99 670093.00 70 18 29.246 N 148 37 18.452 W -Polygon 1 0.00 3401.13 -5850.90 5964186.99 670093.00 70 18 29.246 N 148 37 18.452 W -Polygon 2 0.00 3005.19 -5432.03 5963800.99 670521.00 70 18 25.355 N 148 37 6.228 W 15-33B T2.1 8780.00 3066.93 -3626.97 5963905.00 672324.00 70 18 25.973 N 148 36 13.588 W 15-33B T2.2 8810.00 3269.93 -5459.84 5964064.99 670487.00 70 18 27.958 N 148 37 7.044 W Annotation ---.--------.-- MD ft -- ---.-------- .--.... 10327.19 10350.00 10370.00 TVD ft 8569.26 8578.66 8586.59 ...._____.__un_. ..........--.---.--. TIP KOP 3 e e BP-GDB Baker Hughes INTEQ Planning Report .. ....--. ...- Company: BP Amoco Date: 11/11/2003 Time: 14:42:10 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-33, True North Site: PB DS 15 Vertical (TVD) Reference: System: Mean Sea Level . Well: 15-33 Section (VS) Reference: Well (0.00N,0.00E,273.00Azi) i Wellpath: Plan#2 15-33B Survey Calculation Method: Minimum Curvature Db: Oracle .1 1_....- .n .n. . --..---..----------.-- _...___u_u_. ......-.---.--.--.... n_.______.___. .. Annotation ._-". .. _n..._....____....._ ..----- ..--.--. MD TVD ft ft ...--. -... -------- -.- . -----. .....---- 10410.00 8599.66 4 10510.00 8631.68 5 10610.00 8668.87 6 10710.00 8706.61 7 10810.00 8743.76 8 10993.44 8780.36 9 11308.44 8788.02 10 11558.44 8792.95 11 11808.44 8797.23 12 12058.44 8800.93 13 12308.44 8804.14 14 12558.44 8806.92 15 12850.00 8809.68 TD Plan: Plan #2 Date Composed: 11/11/2003 Identical to Lamar's Plan #2 Version: 5 Principal: Yes Tied-to: From: Definitive Path Plan Section Information -------- MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg ...----....-....-.... --------...-.... -..---.----....-..-... ..----.--.....-. 10327.19 65.46 312.04 8569.26 3127.18 -3095.79 0.00 0.00 0.00 0.00 10350.00 65.87 311.73 8578.66 3141.06 -3111.27 2.18 1.80 -1.36 325.37 10370.00 67.43 310.76 8586.59 3153.16 -3125.07 9.00 7.81 -4.87 330.00 10410.00 74.41 306.61 8599.66 3176.75 -3154.57 20.00 17.45 -10.36 330.00 10510.00 68.58 286.42 8631.68 3219.06 -3238.74 20.00 -5.83 -20.20 250.00 10610.00 68.23 264.89 8668.87 3228.17 -3330.57 20.00 -0.35 -21.52 265.00 10710.00 67.90 243.32 8706.61 3202.97 -3419.11 20.00 -0.33 -21.58 265.00 10810.00 68.96 221.82 8743.76 3146.82 -3492.36 20.00 1.06 -21.49 269.00 10993.44 88.50 253.67 8780.36 3054.06 -3642.60 20.00 10.65 17.36 62.00 11308.44 88.81 291.48 8788.02 3067.97 -3951.51 12.00 0.10 12.00 90.00 11558.44 88.97 261.48 8792.95 3095.85 -4197.04 12.00 0.06 -12.00 270.00 11808.44 89.11 291.48 8797.23 3123.73 -4442.58 12.00 0.06 12.00 90.00 12058.44 89.23 261.48 8800.93 3151.61 -4688.13 12.00 0.05 -12.00 270.00 12308.44 89.33 291.48 8804.14 3179.49 -4933.68 12.00 0.04 12.00 90.00 12558.44 89.42 261.48 8806.92 3207.37 -5179.24 12.00 0.04 -12.00 270.00 12850.00 89.53 296.47 8809.68 3252.13 -5462.77 12.00 0.04 12.00 90.00 Survey ...--------..- .. MD lncl Azim Sys TVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 OOft deg .-..----------.... -------------. - -.-....--.. ..-------.- .- n..... ....._ ......- ......-... .. _n_______._ . -----.---.- 10327.19 65.46 312.04 8569.26 3127.18 -3095.79 5963977.67 672853.59 3255.21 0.00 0.00 TIP 10350.00 65.87 311.73 8578.66 3141.06 -3111.27 5963991.18 672837.79 3271.39 2.18325.37 KOP 10370.00 67.43 310.76 8586.59 3153.16 -3125.07 5964002.95 672823.71 3285.81 9.00330.00 3 10375.00 68.30 310.22 8588.47 3156.17 -3128.60 5964005.88 672820.12 3289.49 20.00 330.00 MWD 10400.00 72.66 307.62 8596.83 3170.96 -3146.93 5964020.23 672801.44 3308.57 20.00 330.20 MWD 10410.00 74.41 306.61 8599.66 3176.75 -3154.57 5964025.84 672793.66 3316.51 20.00 331.07 4 10425.00 73.40 303.67 8603.82 3185.04 -3166.36 5964033.86 672781.69 3328.71 20.00 250.00 MWD 10450.00 71.82 298.70 8611.29 3197.40 -3186.76 5964045.73 672761.01 3349.73 20.00 250.82 MWD 10475.00 70.37 293.64 8619.40 3207.83 -3207.97 5964055.66 672739.56 3371.46 20.00 252.30 MWD 10500.00 69.06 288.50 8628.07 3216.26 -3229.84 5964063.57 672717.50 3393.74 20.00 253.94 MWD 10510.00 68.58 286.42 8631 .68 3219.06 -3238.74 5964066.16 672708.54 3402.77 20.00 255.73 5 10525.00 68.35 283.20 8637.19 3222.62 -3252.22 5964069.41 672694.97 3416.43 20.00 265.00 MWD 10550.00 68.10 277.82 8646.47 3226.86 -3275.04 5964073.11 672672.07 3439.43 20.00 266.18 MWD 10575.00 68.03 272.43 8655.82 3228.93 -3298.13 5964074.64 672648.94 3462.60 20.00 268.18 MWD 10600.00 68.14 267.04 8665.15 3228.82 -3321.31 5964073.99 672625.77 3485.74 20.00 270.19 MWD 10610.00 68.23 264.89 8668.87 3228.17 -3330.57 5964073.12 672616.53 3494.95 20.00 272.20 6 10625.00 68.00 261.67 8674.46 3226.54 -3344.39 5964071.17 672602.75 3508.67 20.00 265.00 MWD 10650.00 67.75 256.28 8683.89 3222.11 -3367.11 5964066.21 672580.14 3531.13 20.00 266.20 MWD e It B BP-GDB Baker Hughes INTEQ Planning Report "~'~^'~~µ'~~ lNTEQ -..- .-. - . ..__n__ ....... . .-.- .. ___.__n.___ ___ -....- . .... __.. ...____n._.. .-...-- n __ _ .._._------, Company: BP Amoco Date: 11/11/2003 Time: 14:42:10 Page: 3 I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-33, True North I Site: PB DS 15 Vertical (TVD) Reference: System: Mean Sea Level I Well: 15-33 Section (VS) Reference: Well (0.00N,0.00E,273.00Azi) Wellpath: Plan#2 15-33B Survey Calculation Method: Minimum Curvature Db: Oracle .--........-. -.---...----..-- .. .._____________n_n_____.___n_n________... Survey MD Incl Azim Sys TVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg ....--. -.----.--------.---..---- ---..---- _n ................-...-. nm _____._____.___.__._ -....- .---... -.... ...... .-.--.--- 10675.00 67.69 250.87 8693.37 3215.58 -3389.29 5964059.16 672558.12 3552.93 20.00 268.23 MWD 10700.00 67.80 245.47 8702.84 3206.98 -3410.76 5964050.06 672536.86 3573.92 20.00 270.28 MWD 10710.00 67.90 243.32 8706.61 3202.97 -3419.11 5964045.86 672528.60 3582.05 20.00 272.33 7 10725.00 67.88 240.08 8712.26 3196.39 -3431.34 5964038.99 672516.53 3593.93 20.00 269.00 MWD 10750.00 67.99 234.68 8721.66 3183.90 -3450.85 5964026.05 672497.32 3612.75 20.00 270.22 MWD 10775.00 68.27 229.30 8730.98 3169.62 -3469.12 5964011.35 672479.39 3630.25 20.00 272.25 MWD 10800.00 68.73 223.95 8740.15 3153.66 -3486.02 5963994.99 672462.87 3646.29 20.00 274.25 MWD 10810.00 68.96 221.82 8743.76 3146.82 -3492.36 5963988.01 672456.69 3652.27 20.00 276.22 8 10825.00 70.39 224.63 8748.97 3136.58 -3502.00 5963977.54 672447.30 3661.35 20.00 62.00 MWD 10850.00 72.87 229.21 8756.86 3120.38 -3519.32 5963960.95 672430.36 3677.81 20.00 61.02 MWD 10875.00 75.44 233.66 8763.68 3105.40 -3538.13 5963945.53 672411.91 3695.80 20.00 59.58 MWD 10900.00 78.11 238.01 8769.41 3091.74 -3558.26 5963931.41 672392.11 3715.19 20.00 58.36 MWD 10925.00 80.83 242.28 8773.98 3079.52 -3579.57 5963918.69 672371.09 3735.83 20.00 57.37 MWD 10950.00 83.61 246.47 8777.36 3068.81 -3601.90 5963907.46 672349.02 3757.57 20.00 56.59 MWD 10975.00 86.42 250.63 8779.54 3059.71 -3625.07 5963897.82 672326.07 3780.24 20.00 56.02 MWD 10993.44 88.50 253.67 8780.36 3054.06 -3642.60 5963891.76 672308.68 3797.45 20.00 55.66 9 11000.00 88.50 254.46 8780.53 3052.26 -3648.91 5963889.82 672302.41 3803.65 12.00 90.00 MWD 11025.00 88.50 257.46 8781.18 3046.20 -3673.15 5963883.19 672278.32 3827.54 12.00 89.98 MWD 11050.00 88.51 260.46 8781.83 3041.41 -3697.68 5963877.83 672253.92 3851.78 12.00 89.90 MWD 11075.00 88.52 263.46 8782.48 3037.92 -3722.42 5963873.76 672229.26 3876.31 12.00 89.82 MWD 11100.00 88.54 266.46 8783.12 3035.72 -3747.31 5963870.98 672204.43 3901.05 12.00 89.74 MWD 11125.00 88.56 269.46 8783.76 3034.84 -3772.29 5963869.51 672179.49 3925.95 12.00 89.67 MWD 11150.00 88.58 272.46 8784.38 3035.26 -3797.27 5963869.34 672154.50 3950.92 12.00 89.59 MWD 11175.00 88.61 275.47 8784.99 3036.99 -3822.20 5963870.49 672129.54 3975.91 12.00 89.52 MWD 11200.00 88.64 278.47 8785.60 3040.02 -3847.01 5963872.94 672104.67 4000.84 12.00 89.44 MWD 11225.00 88.67 281.47 8786.18 3044.34 -3871.62 5963876.68 672079.96 4025.64 12.00 89.37 MWD 11250.00 88.71 284.47 8786.75 3049.95 -3895.97 5963881.72 672055.49 4050.26 12.00 89.30 MWD 11275.00 88.75 287.47 8787.31 3056.82 -3920.00 5963888.03 672031.31 4074.61 12.00 89.23 MWD 11300.00 88.80 290.47 8787.84 3064.95 -3943.63 5963895.60 672007.49 4098.64 12.00 89.17 MWD 11308.44 88.81 291.48 8788.02 3067.97 -3951.51 5963898.43 671999.54 4106.66 12.00 89.10 10 11325.00 88.82 289.49 8788.36 3073.76 -3967.02 5963903.86 671983.90 4122.45 12.00 270.00 MWD 11350.00 88.82 286.49 8788.87 3081.48 -3990.79 5963911.02 671959.96 4146.59 12.00 270.04 MWD 11375.00 88.83 283.49 8789.39 3087.95 -4014.93 5963916.92 671935.68 4171.04 12.00 270.10 MWD 11400.00 88.84 280.49 8789.90 3093.14 -4039.38 5963921.54 671911.12 4195.73 12.00 270.16 MWD 11425.00 88.85 277.49 8790.40 3097.05 -4064.06 5963924.86 671886.35 4220.58 12.00 270.23 MWD 11450.00 88.87 274.49 8790.90 3099.65 -4088.92 5963926.89 671861.44 4245.54 12.00 270.29 MWD 11475.00 88.89 271.49 8791.39 3100.96 -4113.88 5963927.61 671836.46 4270.53 12.00 270.35 MWD 11500.00 88.91 268.49 8791.87 3100.95 -4138.87 5963927.02 671811.48 4295.49 12.00 270.41 MWD 11525.00 88.93 265.49 8792.34 3099.64 -4163.83 5963925.12 671786.56 4320.35 12.00 270.46 MWD 11550.00 88.96 262.49 8792.80 3097.02 -4188.68 5963921.92 671761.77 4345.03 12.00 270.52 MWD 11558.44 88.97 261.48 8792.95 3095.85 -4197.04 5963920.55 671753.45 4353.31 12.00 270.57 11 11575.00 88.97 263.46 8793.25 3093.68 -4213.45 5963917.99 671737.09 4369.59 12.00 90.00 MWD 11600.00 88.98 266.46 8793.70 3091.48 -4238.35 5963915.22 671712.25 4394.34 12.00 89.96 MWD 11625.00 88.98 269.46 8794.14 3090.59 -4263.33 5963913.75 671687.30 4419.23 12.00 89.91 MWD 11650.00 88.99 272.46 8794.58 3091.01 -4288.32 5963913.58 671662.31 4444.21 12.00 89.86 MWD 11675.00 89.00 275.47 8795.02 3092.74 -4313.25 5963914.72 671637.35 4469.20 12.00 89.80 MWD 11700.00 89.02 278.47 8795.45 3095.77 -4338.06 5963917.17 671612.48 4494.14 12.00 89.75 MWD 11725.00 89.04 281.47 8795.88 3100.10 -4362.68 5963920.92 671587.77 4518.94 12.00 89.70 MWD 11750.00 89.06 284.47 8796.29 3105.71 -4387.03 5963925.96 671563.29 4543.56 12.00 89.65 MWD 11775.00 89.08 287.47 8796.70 3112.58 -4411.06 5963932.27 671539.10 4567.92 12.00 89.60 MWD 11800.00 89.10 290.47 8797.10 3120.71 -4434.70 5963939.83 671515.29 4591.95 12.00 89.55 MWD 11808.44 89.11 291.48 8797.23 3123.73 -4442.58 5963942.67 671507.34 4599.97 12.00 89.50 12 e BP-GDB e Baker Hughes INTEQ Planning Report ~~-~-,~-- IN'TEQ Company: BP Amoco Date: 11/11/2003 Time: 14:42:10 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-33, True North Site: PB DS 15 Vertical (TVD) Reference: System: Mean Sea Level Well: 15-33 Section (VS) Reference: Well (0.00N,0.00E,273.00Azi) Wellpath: Plan#2 15-33B Survey Calculation Method: Minimum Curvature Db: Oracle .-------------.---.----..-.---.. Survey 1--- ------ . ... .... n__....._...__ ------- ---.. u____.....__..____._ ________.. , MD Incl Azim Sys TVD N/S E/W MapN MapE VS DLS TFO Tool I ft deg deg ft ft ft ft ft ft deg/1 000 deg -----....-..... 11825.00 89.11 289.49 8797.49 3129.52 -4458.09 5963948.10 671491.70 4615.77 12.00 270.00 MWD 11850.00 89.11 286.49 8797.87 3137.24 -4481.86 5963955.26 671467.75 4639.91 12.00 270.03 MWD 11875.00 89.12 283.49 8798.26 3143.71 -4506.01 5963961.16 671443.47 4664.36 12.00 270.08 MWD 11900.00 89.13 280.49 8798.64 3148.90 -4530.45 5963965.77 671418.90 4689.05 12.00 270.12 MWD 11925.00 89.14 277 .49 8799.02 3152.81 -4555.14 5963969.10 671394.13 4713.90 12.00 270.17 MWD 11950.00 89.15 274.49 8799.39 3155.41 -4580.00 5963971.13 671369.22 4738.86 12.00 270.21 MWD 11975.00 89.16 271.49 8799.76 3156.72 -4604.96 5963971.85 671344.24 4763.86 12.00 270.26 MWD 12000.00 89.18 268.49 8800.12 3156.71 -4629.95 5963971.26 671319.25 4788.82 12.00 270.30 MWD 12025.00 89.20 265.49 8800.48 3155.40 -4654.91 5963969.36 671294.33 4813.68 12.00 270.35 MWD 12050.00 89.22 262.49 8800.82 3152.78 -4679.77 5963966.16 671269.55 4838.36 12.00 270.39 MWD 12058.44 89.23 261.48 8800.93 3151.61 -4688.13 5963964.79 671261.22 4846.64 12.00 270.43 13 12075.00 89.23 263.46 8801.16 3149.44 -4704.54 5963962.23 671244.86 4862.92 12.00 90.00 MWD 12100.00 89.23 266.46 8801.49 3147.24 -4729.44 5963959.46 671220.02 4887.67 12.00 89.97 MWD 12125.00 89.24 269.46 8801.82 3146.36 -4754.42 5963957.99 671195.07 4912.57 12.00 89.93 MWD 12150.00 89.24 272.47 8802.16 3146.78 -4779.41 5963957.82 671170.08 4937.55 12.00 89.89 MWD 12175.00 89.25 275.47 8802.48 3148.50 -4804.35 5963958.96 671145.11 4962.54 12.00 89.85 MWD 12200.00 89.26 278.47 8802.81 3151.54 -4829.16 5963961.41 671120.24 4987.48 12.00 89.81 MWD 12225.00 89.28 281.47 8803.13 3155.86 -4853.78 5963965.16 671095.53 5012.29 12.00 89.78 MWD 12250.00 89.29 284.47 8803.44 3161.47 -4878.13 5963970.20 671071.05 5036.91 12.00 89.74 MWD 12275.00 89.31 287.47 8803.74 3168.35 -4902.17 5963976.51 671046.86 5061.27 12.00 89.70 MWD 12300.00 89.33 290.47 8804.04 3176.47 -4925.80 5963984.07 671023.04 5085.30 12.00 89.66 MWD 12308.44 89.33 291.48 8804.14 3179.49 -4933.68 5963986.91 671015.10 5093.32 12.00 89.63 14 12325.00 89.33 289.49 8804.33 3185.28 -4949.19 5963992.34 670999.45 5109.12 12.00 270.00 MWD 12350.00 89.34 286.49 8804.62 3193.00 -4972.97 5963999.50 670975.51 5133.26 12.00 270.02 MWD 12375.00 89.34 283.49 8804.91 3199.47 -4997.11 5964005.40 670951.22 5157.71 12.00 270.06 MWD 12400.00 89.35 280.49 8805.20 3204.66 -5021.56 5964010.02 670926.66 5182.40 12.00 270.09 MWD 12425.00 89.35 277 .49 8805.48 3208.57 -5046.25 5964013.34 670901.88 5207.26 12.00 270.13 MWD 12450.00 89.36 274.49 8805.76 3211.18 -5071.11 5964015.37 670876.97 5232.22 12.00 270.16 MWD 12475.00 89.37 271.49 8806.04 3212.48 -5096.07 5964016.09 670851.99 5257.22 12.00 270.19 MWD 12500.00 89.39 268.49 8806.31 3212.48 -5121.07 5964015.50 670827.00 5282.18 12.00 270.23 MWD 12525.00 89.40 265.49 8806.57 3211.17 -5146.03 5964013.60 670802.08 5307.04 12.00 270.26 MWD 12550.00 89.42 262.49 8806.83 3208.55 -5170.89 5964010.40 670777.29 5331.72 12.00 270.29 MWD 12558.44 89.42 261.48 8806.92 3207.37 -5179.24 5964009.03 670768.97 5340.01 12.00 270.32 15 12575.00 89.42 263.46 8807.09 3205.20 -5195.66 5964006.48 670752.60 5356.29 12.00 90.00 MWD 12600.00 89.42 266.46 8807.34 3203.01 -5220.56 5964003.70 670727.77 5381.04 12.00 89.98 MWD 12625.00 89.43 269.47 8807.59 3202.12 -5245.54 5964002.23 670702.81 5405.94 12.00 89.95 MWD 12650.00 89.43 272.47 8807.84 3202.54 -5270.53 5964002.06 670677.82 5430.92 12.00 89.92 MWD 12675.00 89.44 275.47 8808.08 3204.27 -5295.47 5964003.21 670652.85 5455.91 12.00 89.89 MWD 12700.00 89.45 278.47 8808.32 3207.30 -5320.28 5964005.66 670627.98 5480.85 12.00 89.86 MWD 12725.00 89.46 281.47 8808.56 3211.63 -5344.90 5964009.40 670603.27 5505.66 12.00 89.83 MWD 12750.00 89.47 284.47 8808.80 3217.24 -5369.26 5964014.44 670578.78 5530.28 12.00 89.80 MWD 12775.00 89.48 287.47 8809.03 3224.11 -5393.29 5964020.75 670554.60 5554.63 12.00 89.77 MWD 12800.00 89.50 290.47 8809.25 3232.23 -5416.93 5964028.32 670530.78 5578.67 12.00 89.75 MWD 12825.00 89.51 293.47 8809.47 3241.58 -5440.11 5964037.12 670507.39 5602.31 12.00 89.72 MWD 12850.00 89.53 296.47 8809.68 3252.13 -5462.77 5964047.14 670484.49 5625.49 12.00 89.69 TD Page 1 u ,.---.... . ~ ¡ Base Flange I , Ì"_:~'<" ~ "\ ... >.~~¿ Z;i-~.~· .~.~.~.~< I = I SSV ~ Master Valve ª=,r:§'Qoo:~¡ ..:.:_::'.1 i . ¡ I , U, ~ I ~ · Tree Size ./' I · , ! ....:~:.~-- t" ,. .~'... '. - :-\. ./" ) .... - . ./. - -. "I -. .. ~ ~ Swab Valve :U1!!(::m100:p~\::(RXt~H:::W ~Iì~1;~i:g~~~~~ffl~1::::: E::::3 :J L.::=-=-- 1I1111n .-.....- rOo - _ i : I L~~!!~:;:..!~::...-.~:.-:~.._..j ! IÌ:1:~~:~r:8~mr.m\:~B~(~; ! --- L-.._.~ -1=-----=rh:Z::j:Ö:jti;:§ººº::Mi.i.::R*M~: ~_.._._. - )) 3:",'~~~" ,h, I I ¡ [J __ ..... . ¡1::-¡·ïü·;·'Cï\iãG! I ~ . II ¿.,:; .......,., ~_.. .. ---, / ~ -~~-"'.-'." I ...................,. TC; I . I i~.=~y-j7 Utí 5000 pSI RX-';6 __..C___J..... . ~ _-·.0-0- -..-. """";""'" I . .:.: ~"'" 1 ;'~.Kin~ine' Wt. " '-2" 1I)··:..~··4:··:·:·:·. U ~..... ....:.:.: · .. . ... · ................ I ~ I ~ I ~ I ~ llHmSOOO .. Well Rig Floor e !!W$:t;~m BOP-Tree e p055164 DATE INVOICE I CREDIT MEMO 10/6/2003 INV# PR100103D THE ATTACHED CHECK IS IN ÞAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY: DESCRIPTION PERMIT TO DRILL EE GROSS \$·33ß DATE 10/6/2003 CHECK NO. 055164 VENDOR DISCOUNT NET TOTAL ~ B.p'~.I· ,::::::1 I::::) :!;;::~ ~:~' TO THE ORDER OF: ALA,§KA 9ilL & GAS CONSERVATION 333 W 7TH AVENUE SUITE 100 ANCHORAGE,AK 99501-3539 NATIONAL CITY BANK Ashland, Ohio DATE October 6, 2003 II- 0 5 5 ~ b .... II- I: 0.... ~ 20 :. 8 g 5 I: 0 ~ 2 ? 8 g b 1111 56-389 """4i2 No.P 055164 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *******$100.00******* NOTVALlDAFTER 120 DAYS . ' '. , ~-.,~w:, i'";;;(';:':;~::;~::~~~;t"~':~ H e e e e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/P ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~ Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. Pll..OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION .. compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/10/02 C\jody\templates Wa;;LL PERMIT CH.ECKLIS:r Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD#:2031940 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Administration 1 PeuIJit fee attache~ Ye$ 2 Lease number appropriate _ Ye$ 3 _U_nique well n_ame_afld Ol!mb_er _ _Ye$ _ _ _ 4 WeUJocated in a defiJ]edppo _Y_e$ 5 Well Jocated proper _distance from driJling uJ]itb_ouJ]d_ar:y _ Ye$ 6 WellJocated proper _distaflce_ from otber wens Ye$ 7Sutficientacreage_ayailable indJilJiog l!njt Ye$ 8 Kdeviated, js weJlbore platiJ]cJu_ded Ye$ 90-perator only affected party _ _Ye$ 10 _O-per_ator bas_appropriate_b.ond inJorce _ Yes _ _ _ _ 11 PeUTIit cafl be iS$l!eçl witbQut co_n$erva_tion order Ye$ 12 Permitcafl be iS$l!eçl witbQut administratÌ\leapprovaJ Ye$ 13 Can permit be approved before 15-day wait Yes 14 WelUQcated within area alld_strataauthorized byJnjectioo Order # (puUOfl in comments) (For_ NA 15 _AJI wens_wit/lil1Jl4-"Jite_area_of reyiew jdeot[fied (For servjcewe[l onlYL _NA _ _ _ _ 16 Pre-produ~ed ifljeçtor; ~uratiQnof pre-pro~uçtioJ] le$s thall3 montbs_ (For_service well onJy)NA 17 ACMP ¡=indjng of Con_sisteflCY_ h_a$ bee_n jssued_ forJbi$ projectNA 18Condu_ctor strillgprQvided NA 19 _Sw:face_casing_PJotects alLknown_ USDWsNA 20 _CMT v_ol adequ_ateJo circulate 011 conductor 8. surtcsg NA 21CMT vol adequ_ate to tie-inJQng _striflg lo_sul:f csg_ NA 22 _CMT will coYer_aJl koownpro_duçtiye bQrizons Ye$ 23C_a$ing designs adeQuate for C,T, B&permafr_ost Yes 24 A~equaleJallkage_oJ re_serve pit Ye$ CTDU. 25 Jfare-~rilt basa 10A-03 fQr abançlOllme_nl beeo apPJoved Yes' 26 A~equalewe[lbore separatio_n-PJopose~C _ _ Ye$ _ _ 127 Jfdivecter Jequired, dQes it meet reguJations_ NA Siçletrack. Date 28DJilJiog fJuid_ program $chematic& e(tuip Ji$taçlequate _ Yes Max MW_8J ppg. 11/24/2003 29 _BOPE$,_d_o _they meet reguJation Ye$ 30 _BOPEpres$ rating appropriate; test lo_(pu_t psig in_comment$L Ye$ 31 Choke manifold cQmpJies w/API RF'-53 (May 64)_ _Ye$ 32 Work wiJl pccur wilhputoperatiol1_sbl!tdown_ Ye$ 33 Is presence Qf H2S gas prob.able _ Ye$ 34 Mecba_nicaLcpodjt[OflOf well$ within AOR yerified (fpr_s_ervice wen ollly) NA Appr Date - Engineering Appr . Geology 35 36 Appr Date 37 RPC 38 39 Geologic Commissioner: 1}~ Well Name: PRUDHOE BAY UNIT 15-33B DEV I 1-01L GeoArea 890 Unit 11650 Program DEV On/Off Shore On - - - - - - - Test to_35QO_ psi. MSF' 2169 P$i._ 10 ppm. - - Permit can be iS$l!eçl wlo hyçlrogen sulfiçle measures _D_ata_pJeseoted on_ pote_ntial pve_rpressure _Zone» Seismic_al1alysjs_ of sbaJlow gas_zones_ Seabedconditioo $l!rvey Jif off-shore) _ Conta_clnamelp/lOlleforweekly progressreport$ [e¡cploratpry _OfllYl No NA NA NA _NA - - - Date: Engineering Commissioner: Date r2j 2-( :7 Public Commissioner ~~ Date Well bore seg Annular Disposal D D - - - 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drflting Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Sep 17 10:07:01 2004 Reel Header Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name....... ........ .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments....... ......... .STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA e p,IJ 3 -Ie:¡ cf ! 2 c:, tf<¡ RECEIVED (1rO ., n ""0 · :'-\""" / r' 'II í I' -",,; ..~..~~ ...... ,) :.... \i. !+ Alaska Oil & Gas Cons, Cammis.'S!Of; .,Cmchorage Scientific Technical Services Scientific Technical Services 15-33B 500292244802 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 17-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002846007 S. LATZ KOLSTAD/SARB MWD RUN 2 MW0002846007 S. LATZ KOLSTAD/SARB JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002846007 S. LATZ KOLSTAD/SARB MWD RUN 5 MW0002846007 S. LATZ KOLSTAD/SARB # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 11N 14E 559 106 69.60 # WELL CASING RECORD OPEN HOLE CASING DRILLERS MWD RUN 3 MW0002846007 S. LATZ KOLSTAD/SARB MWD RUN 6 MW0002846007 S. LATZ KOLSTAD/SARB 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: BIT sfIþ (IN) SIZE (IN) DEPTH (FT) 4.125 7.000 10345.0 e 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. 15-33B WAS DRILLED FROM A WHIPSTOCK POSITIONED IN THE 15-33 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 10345'MD. 4. MWD RUNS 1 - 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 1/7/2004. THESE LOG DATA WERE PROVIDED TO SSDS BY K. COONEY (SIS/BP) ON 9/15/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 6 REPRESENT WELL 15-33B WITH API#: 50-029-22448-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12699'MD/8772'TVDSS. SROP SGRC $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY COMBINED. File Header Service name..... ....... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....04/09/17 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10330.5 10368.0 STOP DEPTH 12667.0 12694.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10330.5 10339.5 10344.0 GR 10331.0 10340.0 10342.0 10350.0 10352.0 10354.0 10356.0 10358.5 10377.0 10386.5 10400.5 10405.5 10417.5 10426.0 10433.0 10447.0 10451.0 10459.5 10473.5 10475.5 10491.0 10500.5 10503.0 10519.0 10523.0 10531.0 10540.0 10546.0 10552.0 10580.0 10583.5 10593.0 10600.0 10615.0 10626.5 10642.5 10647.0 10660.5 10668.0 10671.5 10676.5 10687.5 10703.0 10718.5 10725.0 10730.0 10734.0 10737.0 10741.0 10745.0 10752.0 10759.0 10780.5 10803.0 10817.0 10838.0 10857.0 10867.0 10871.0 10882.5 10905.5 10916.0 10924.0 10926.0 10930.5 10945.0 10965.0 10969.0 10981.0 10997 . 0 11007.0 10349._ 10350.5 10353.0 10355.0 10357.0 10375.5 10387.5 10400.0 10406.0 10416.0 10424.5 10431.5 10444.5 10448.5 10456.5 10471.5 10474.5 10490.5 10501.0 10503.5 10518.5 10523.5 10530.0 10539.0 10547.5 10553.0 10581.0 10584.5 10594.5 10601.5 10617.0 10630.5 10646.0 10650.5 10663.0 10671.5 10674.0 10677.0 10688.0 10705.0 10718.5 10728.0 10732.5 10736.5 10739.0 10745.5 10750.5 10755.0 10760.5 10782.5 10806.5 10819.5 10840.5 10859.0 10869.0 10872.0 10881.0 10904.5 10915.0 10922.5 10924.5 10927.5 10943.0 10965.0 10968.0 10980.5 10995.5 11005.0 e 11009.5 11017.0 11019.5 11036.0 11046.0 11075.0 11085.5 11089.0 11099.5 11104.5 11106.0 11128.0 11132.0 11134.5 11137.5 11154.5 11166.0 11183.5 11193.0 11199.0 11251.0 11261.0 11285.0 11292.5 11301.0 11318.5 11343.0 11362.5 11373.0 11386.5 11396.0 11409.0 11415.0 11423.0 11425.5 11458.5 11497.0 11502.0 11510.0 11514.0 11522.0 11525.0 11529.5 11551.0 11571.0 11587.0 11590.5 11621.0 11623.0 11625.0 11632.5 11681.5 11689.5 11697.5 11705.5 11709.0 11717.0 11726.0 11733.0 11742.0 11747.5 11754.0 11785.0 11812.0 11850.0 11879.5 11886.0 11888.0 11009.. 11015.0 11018.5 11031.5 11042.5 11073.0 11081.5 11084.5 11098.5 11103.5 11105.0 11125.0 11129.5 11133.5 11136.0 11155.5 11166.0 11182.5 11193.0 11197.5 11248.5 11261.5 11283.0 11292.0 11300.0 11322.0 11343.5 11364.5 11376.0 11389.5 11399.0 11409.5 11417.0 11425.5 11428.5 11463.0 11500.0 11503.0 11512.5 11515.0 11525.0 11526.5 11531.5 11555.0 11573.5 11588.5 11593.0 11622.0 11625.0 11628.0 11635.0 11683.5 11691.5 11698.5 11708.5 11711.5 11719.0 11727.0 11734.5 11742.5 11747.5 11754.0 11784.5 11810.0 11854.0 11884.0 11890.5 11894.5 e 11891.5 11898.~ e 11910.0 1191 7.0 11914.0 11920.5 1191 7.0 11923.0 11921. 5 11927.5 11926.5 11931. 0 11929.5 11936.5 11937.0 11944.5 11940.5 11948.0 11945.0 11952.0 11948.5 11955.0 11959.0 11962.5 11965.0 11973.5 11966.5 11975.0 11974.5 11985.0 11979.5 11990.0 11981. 5 11991.5 12003.0 12011.5 12011.0 12020.5 12017.0 12026.0 12020.5 12029.5 12034.5 12043.0 12039.0 12048.0 12042.5 12051. 5 12044.0 12052.5 12067.0 12077.0 12069.0 12080.0 12092.0 12098.0 12095.0 12100.5 12098.5 12105.0 12113.0 12120.0 12125.0 12133.5 12129.0 12136.5 12132.0 12139.5 12158.5 12170.0 12175.0 12184.0 12179.0 12187.5 12190.5 12198.0 12204.5 12207.5 12214.5 12216.0 12233.0 12237.5 12258.0 12264.5 12290.0 12295.5 12303.0 12309.5 12325.0 12332.0 12367.0 12371.0 12375.5 12381.0 12380.5 12385.0 12387.5 12392.0 12401.5 12408.0 12412.0 1241 7.5 12418.5 12426.0 12422.0 12429.5 12445.5 12450.5 12504.5 12513 . 0 12511.5 12519.0 12519.5 12527.5 12524.0 12533.5 12531.0 12537.0 12535.0 12540.0 12539.0 12543.5 12547.0 12552.0 12556.5 12562.0 12563.0 12566.0 12568.0 12572.5 12694.5 12699.0 $ # MERGED DATA SOURCE e e PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 10331.0 10974.0 MWD 2 10974.0 11021.0 MWD 3 11021. 0 11036.5 MWD 4 11036.5 11 712 . 0 MWD 5 11 712 . 0 12520.0 MWD 6 12520.0 12699.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..... ....... ......0 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 DEPT ROP MWD GR MWD Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10330.5 12694.5 11512.5 4729 10330.5 12694.5 ROP MWD FT/H 0.11 1284.36 106.368 4654 10368 12694.5 GR MWD API 17.91 404.95 71.1463 4674 10330.5 12667 First Reading For Entire File... ...... .10330.5 Last Reading For Entire File.......... .12694.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation... ....04/09/17 Maximum Physical Record. .65535 File Type..... ... ....... .LO Next File Name....... ....STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ e It header data for each bit run in separate files. 1 .5000 START DEPTH 10331.0 10366.5 STOP DEPTH 10947.0 10974.0 # 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. . . . . . . . . . . . . . . . . . . . . . . 01-JAN-04 Insite 4.3 Memory 10974.0 10366.0 10974.0 65.7 76.7 TOOL NUMBER 78012 4.125 10356.0 Flo Pro 8.70 65.0 8.5 22000 6.8 .000 .000 .000 .000 .0 141. 0 .0 .0 Datum Specification BIOC~ub-tYPe...o e Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10331 10974 10652.5 1287 10331 10974 ROP MWD010 FT/H 0.23 195.8 96.6421 1216 10366.5 10974 GR MWD010 API 17.91 404.95 61.2696 1233 10331 10947 First Reading For Entire File......... .10331 Last Reading For Entire File.......... .10974 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation.. .... .04/09/17 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name.... ........ .STSLIB.003 Service Sub Level Name... Version Number...... .,. ..1.0.0 Date of Generation...... .04/09/17 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 GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10947.5 10974.5 STOP DEPTH 10994.5 11021.0 # 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: 02-JAN-04 Insite 4.3 Memory 11021.0 10974.0 11021. 0 81. 9 MAXIMUM ANGLE: e # 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. ....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 DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 81. 9 e TOOL NUMBER 78012 4.125 10356.0 Flo Pro 8.70 65.0 8.5 22000 7.0 .000 .000 .000 .000 .0 145.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10947.5 11021 10984.3 148 10947.5 11021 ROP MWD020 FT/H 1. 51 88.85 70.815 94 10974.5 11021 GR MWD020 API 34.09 150.44 72.2321 95 10947.5 10994.5 First Reading For Entire File......... .10947.5 Last Reading For Entire File.......... .11021 File Trailer Service name........ .... .STSLIB.003 Service Sub Level Name... version Number......... .~0.0 Date of Generation...... .04/09/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name...... .... .STSLIB.004 Physical EOF File Header Service name........ .... .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/09/17 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: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 e header data for each bit run in separate files. 3 .5000 START DEPTH 10995.0 11021.5 STOP DEPTH 11010.5 11036.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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: 02-JAN-04 Insite 4.3 Memory 11037.0 11021.0 11037.0 81. 9 81. 9 TOOL NUMBER 72829 3.750 10356.0 Flo Pro 8.70 65.0 8.5 22000 6.8 .000 .000 .000 .000 .0 145.0 .0 .0 # e e NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction........ ....... ..Down Optical log depth units... ....... .Feet Data Reference Point. ....... ..... .Undefined Frame Spacing.................... .60 .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 MWD030 MWD030 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10995 11036.5 11015.8 84 10995 11036.5 ROP MWD030 FT/H 26.43 200.14 140.874 31 11021. 5 11036.5 GR MWD030 API 56.17 89.47 66.8884 32 10995 11010.5 First Reading For Entire File..... .....10995 Last Reading For Entire File.......... .11036.5 File Trailer Service name... ......... .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .., ..04/09/17 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.. .....04/09/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD header da.for 4 .5000 each bit run in separate f~S. Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 1l01l. 0 1l037.0 STOP DEPTH 11687.5 11712.0 # 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... ......... ......0 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 03-JAN-04 Insite 4.3 Memory 11712.0 1l037.0 II 712 . 0 87.9 94.7 TOOL NUMBER 78012 3.750 10356.0 Flo Pro 8.80 65.0 8.5 23000 5.8 .000 .000 .000 .000 .0 155.0 .0 .0 e e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11011 11712 11361.5 1403 11011 11 712 ROP MWD040 FT/H 0.11 928.7 109.417 1351 11037 11712 GR MWD040 API 27.53 191. 25 75.4956 1354 11011 11687.5 First Reading For Entire File......... .11011 Last Reading For Entire File......... ..11712 File Trailer Service name... ......... .STSLIB.005 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation.. .....04/09/17 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name. ........... .STSLIB.006 Service Sub Level Name... Version Number. .... ..... .1.0.0 Date of Generation..... ..04/09/17 Maximum Physical Record. .65535 File Type... ............ .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 11688.0 11 712 .5 STOP DEPTH 12492.0 12520.0 # 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: 04-JAN-04 Insite 4.3 Memory 12520.0 11 712 .0 12520.0 84.6 95.2 # - 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....... ...... .....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 DEPT ROP MWD050 GR MWD050 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code e TOOL NUMBER 72829 3.750 10356.0 Flo Prro 8.70 65.0 8.5 24000 6.2 .000 .000 .000 .000 .0 159.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11688 12520 12104 1665 11688 12520 ROP MWD050 FT/H 0.79 1284.36 110.287 1616 11 712 . 5 12520 GR MWD050 API 23.63 191.59 80.8473 1609 11688 12492 First Reading For Entire File..... .... .11688 Last Reading For Entire File....... ... .12520 File Trailer Service name........ .... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ...~/09/17 Maximum Physical Record..65535 File Type............ ....LO Next File Name....... ....STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/17 Maximum Physical Record. .65535 File Type. ...... ........ .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 e header data for each bit run in separate files. 6 .5000 START DEPTH 12492.5 12520.5 STOP DEPTH 12671.5 12699.0 # 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: # 05-JAN-04 Insite 4.3 Memory 12700.0 12520.0 12699.0 89.0 91. 3 TOOL NUMBER 78012 3.750 10356.0 Flo Pro 8.50 65.0 8.5 23000 5.8 .000 .000 .000 .000 .0 166.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION e e (IN) : # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ............... ..0 Data Specification Block Type.. ...0 Logging Direction.............. ...Down Optical log depth units........ ...Feet Data Reference Point............. .Undefined Frame Spacing. ................. ...60 .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 MWD060 MWD060 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12492.5 12699 12595.8 414 12492.5 12699 ROP MWD060 FT/H 9.18 856.42 111.009 358 12520.5 12699 GR MWD060 API 22.3 90.51 43.5774 359 12492.5 12671.5 First Reading For Entire File......... .12492.5 Last Reading For Entire File.. ........ .12699 File Trailer Service name......... ... .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... ...... .STSLIB.008 Physical EOF Tape Trailer Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/17 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. . . . . . . . . . . . . . . . . . . . .04/09/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation NUmber.....~ 4IÞ Next Reel Name...... .... . UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
