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200-209
STATE OF ALASKA RECEIVE LASKA OIL AND GAS CONSERVATION COMMI N RECEIVED WEL MPLETION OR RECOMPLETION REP AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned IZJ • Suspended ❑ 1®1)IJl Cask 2017 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero S •AOG OL Test 0 2. Operator Name: 6. Date Comp.,Susp.,orAband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 9/16/2017' 200-209 • 317-331 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 1/21/2001 50-029-21523-01-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/8/2001 PBU B-29A Surface: 399'FNL,1892'FEL,Sec.31,T11N,R14E,UM • 9 Ref Elevations KB 81.90 17. Field/Pool(s): Top of Productive Interval: 1910'FNL,1924'FEL,Sec.31,T11N,R14E,UM GL 42.85 • BF 42.50 • PRUDHOE BAY,PRUDHOE OIL• Total Depth: 2399'FNL,1664'FEL,Sec.31,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 8898'/8639' ADL 028310 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 663733• y- 5950245 • Zone - ASP 4 • 10503'/9034' • 89-034 TPI: x- 663740 y- 5948733 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 664012 y- 5948251 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Wndow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 8851'/8595' 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 MWD/GR/RES,GR/CCL/CNL SCANNE_�ft! • Ali 2 6 2018 23. C3 CASING,LINER AND CEMENTING RECORD CASING Wr.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20"x 30" 42' 122' 42' 122' 36" 8 cu yds Concrete 13-3/8" 72# L-80 41' 2684' 41' 2683' 17-1/2" 3255 cu ft PF E,465 cu ft PF 9-5/8" 47# L-80 39' 8802' 39' 8548' 12-1/4" 1760 cu ft Class'G' 7" 29# L-80 8541' 8851' 8297' 8595' 8-1/2" 340 cu ft Class'G' 3-1/2"x3-3-16" 9.3#/6.2 L-80 8508' 10500' 8265' 9034' 3-3/4" 188 cu ft Class'G' x2-7/8" /6.5# 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 8592' 8438'/8197' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. A.i9' '`CzY) -e W Was hydraulic fracturing used during completion? Yes 0 No 0 r Per 20 AAC 25.283(i)(2)attach electronic and printed 1 information i pfroi-1-.r, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Uk- 8898' Set Whipstock 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 W.► Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only VT- ' /i8 AOgir U / RBDMS t,."- nu - 5 2017 f/.5*() $. 28. CORE DATA • Conventional Core(s) Yes 0 No B • • Sidewall Cores Yes 0 No l 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 TVD Permafrost-Top Well Tested? Yes 0 No I Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8820' 8566' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 8820' 8566' Shublik 8849' 8593' Sadlerochit-Zone 4B 8932' 8668' Zone 4A 9315' 8782' CGL-Zone 3 9940' 8882' Baske of CGL-Zone 2 10365' 9033' Formation at total depth: Zone 2 10365' 9033' 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. Authorized Name: Lastufka,Joseph N Contact Name: Ciolkosz,Ryan R Authorized Title: I o tion anc�D a C troller Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: ✓1A` Date: 1o/+/'I Contact Phone: +1 907 564 5977 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 la. 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-Alternating-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 ND 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 5/2017 Submit ORIGINAL Only • • Daily Report of Well Operations B-29A ACTIVITYDATE SUMMARY CTU#8 1.5" CT Job Scope: Dmy Whipstock Drift(Pre CTD) MIRU CTU. Make up tools. Function test BOPs. Open well. RIH w/2.13" x 1.28' Baker CTC, 2.13"x 2.20' Shorty MHA, 2.2" x 10.65' HES Logging Carrier, 2.625" x 9.59' 3-3/16"WS drift, 2.0" x 0.27' Baker XO, 2.5"x 0.58' DJ Nozzle. OAL = 24.57', Max OD = 2.625". 8/2/2017 ***In Progress*** CTU#8 1.5" CT Job Scope: Dmy Whipstock Drift(Pre CTD) MIRU. Make up and RIH with BOT 3-3/16"WS drift. Circulate in safelube while RIH. Tag @ 8906' do /8900' up. Log up to 8000' @ 50 fpm. POOH. Circulate in 50/50 from 2500' for freeze protect. Download log data. Make (-2)' correction to be on depth with tie in log: SLB Mem. Coil Flag on 19-Oct-2012. Corrected tag depth is 8916.18, looks like drift made it to CIBP. 8/2/2017 ***Continue on WSR 08/03/17*** CTU#8 1.5" CT Job Scope: Dmy Whipstock Drift (Pre CTD) Finish reel blowdown. RDMO 8/3/2017 ***Job Complete*** T/I/O = 120/450NAC. Temp = SI. TBG & IA FL (Pre RIG). ALP = 1780 psi, AL SI @ casing valve. TBG FL @ 700' (11 bbls). IA FL @ surface. OA FL near surface. 8/28/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 00:30 T/I/O = 120/450NAC. Temp = SI. Bleed IAP & OAP to 0 psi (Pre CTD). ALP = 1780 psi, AL SI @ CV. IA FL @ surface. OA FL near surface. Bled IAP to BT from 450 psi to 0 psi in 1 hr(1.4 bbls). Monitored for 30 min. IAP unchanged. FWHPs = SSV/ONac. 8/29/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 12:00 T/I/O = SSV/20Nac. Temp = SI. WHPs (pre CTD). ALP = 1780 psi, SI @ CV. IAP increased 20 psi overnight. 8/30/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 12:45 T/I/O = SSV/20/Vac. Temp = SI. WHP's. (Pre-CTD). ALP = 1860 psi &SI (LOTO) @ IA casing valve. 8/31/2017 SV, WV(LOTO), SSV= C. MV= O. IA, OA= OTG. 21:10 T/I/O= 100/0/0. Barriers= MV(23.25 turns) x SSV(4.5" stem) Set TWC #437 @125". Removed upper 4" CIW tree and installed CDR#02 Tree . Torqued to API specs. PT'd against the TWC to 5,000 psi (PASSED) . RDMO***Job Complete*** SEE LOG FOR 9/2/2017 DETAILS. Final T/I/O= TWC/0/0. T/I/O = TWC/10Nac. Temp = SI. WHP's. (Pre-CTD). IAP increased 10 psi, OAP went on Vac overnight. WH, Flow line, scaffold, SSV removed. 9/3/2017 SV, WV= C. MV= O. IA, OA= OTG. 20:45 T/I/O = TWC/10NAC. Temp = SI. IA FL (Pre Rig). IA FL @ surface. WH, Flow line, scaffold removed. 9/11/2017 SV, WV= C. MV= O. IA, OA= OTG. 23:45 • • North America-ALASKA-BP Page 1 qt, Operation Summary Report Common Well Name:B-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/16/2017 I End Date:9/20/2017 X3-018LY-C:(1,958,490.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:CDR-2 Spud Date/Time:1/13/1986 12:00:00AM Rig Release:9/22/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000619 Active datum:KB @81.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations I (hr) I (usft) 9/12/2017 12:00 - 18:00 6.00 BWM P I PRE PRE JOB ON ALL JOB SCOPE CHANGES. -CONTINUE TO DRESS OUT EQUIPMENT FOR I 2"COIL. -REMOVE GOOSENECK FOR 2 3/8"COILAND REPLACE W/2"GOOSENECK. -CHANGE OUT INJECTOR GRIPPER BLOCKS I TO 2". 18:00 - 22:30 4.50 BWM 1 P PRE CHANGE OUT ROLLERS ON HORSES HEAD. FINISH CHANGING OUT GRIPPER BLOCKS. CHANGE OUT STRIPPER ELEMENTS AND I BRASS. PERFORM LOTTO OF REELAND INJECTOR, INSTALL HARDLINE INSIDE REEL,SECURE 1 WITH CHAINS. 22:30 - 00:00 1.50 BWM P I PRE PREP TO PULL CT OFF REELAND INTO INJECTOR. IRUN CABLE THROUGH INJECTOR BACK TO I REEL. 9/13/2017 00:00 02:00 2.00 BWM P 1PRE PREP TO INSTALL GRAPPLE. CONDUCT PJSM AND REVIEW PROCEDURE. INSTALL GRAPPLE AND PULL TEST,GOOD. 02:00 - 02:30 0.50 BWM - P PRE I CONDUCT PJSM AND REVIEW PROCEDURE FOR PULLING CT ACROSS. 02:30 - 04:30 2.00 BWM P PRE PULL 2"COIL FROM REEL AND STAB INTO INJECTOR. 04:30 - 07:45 3.25 'BWM ` P PRE MISCELLANEOUS ACTIVITIES. -SQUARING THINGS UP IN PREPARATION FOR IMPENDING PAD MOVE. 07:45 - 08:15 0.50 BWM P- PRE PRE MOVE SAFETY MEETING WITH ALL ,PARTIES INVOLVED. -IDENTIFY RISKS AND MITIGATIONS. I DISCUSS PROBLEM AREAS,(SHARP TURNS). I I-STRESS ON USING GOOD COMMUNICATION TECHNIQUES. I I -UTILIZE THE STOP THE JOB PROGRAM,IF SOMETHING IS SEEN THAT IS NOT RIGHT. -DO NOT GET IN A HURRY. 08:15 - 15:15 7.00 RIGU P PRE HOOKUP AND PULL EACH MODULE AWAY FROM THE WELL. -SECURITY HERE,TOOL BOX WITH SECURITY AND ESTABLISH A PLAN. -MOVE MODULES AROUND THE PAD AND I I ONTO THE ACCESS ROAD. -MOVE ON TO THE OXBOW AND DOWN TO THE SPINE. '-MODULES ON B PAD ACCESS©12:45. -SPOT SUB OVER WELL.STOPS IN PLACE AND ALL STOP SIGNALAGREED ON. -WELL SITE LEADER,PAD OPERATOR AND 'RIG MANAGER WITNESS MOVING OVER WELL. -SPOT MUD MODULE ACCEPT RIG AT 15:00. 15:15 - 17:30 2.25 RIGU P PRE COMPLETE RIG UP CHECKLIST. Printed 9/27/2017 9:57 06AM *ATI depths reported in Drillers Depths* •• North America-ALASKA-BP Page 2 o(¢ Operation Summary Report Common Well Name:B-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/16/2017 End Date:9/20/2017 1X3-018LY-C:(1,958,490.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:CDR-2 Spud Date/Time:1/13/1986 12:00:OOAM Rig Release:9/22/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000619 Active datum:KB @81.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 17:30 - 21:00 3.50 BOPSUR P PRE PERFORM LEAK TIGHT TEST OF SWAB AND •MASTER TO 3,500 PSI,GOOD. REMOVE TREE CAP AND INSTALL BOPS. GET RKB MEASUREMENTS. 21:00 - 23:00 2.00 BOPSUR P PRE ASSEMBLE TEST JOINT FOR TESTING 2" STACK CONFIGURATION. COMPLETE VALVE CHECKLIST SHEET,ALIGN VALVES FOR SHELL TEST. 23:00 - 00:00 1.00 BOPSUR P PRE PJSM AND REVIEW PROCEDURE FOR TESTING BOPS. REVIEW PRESSURE CROSSCHECK • VERIFICATION WITH DRILLER AND TOURPUSHER. GET SHELL TEST ON BOPS TO 4,000 PSI. FIND DOOR SEAL LEAKING. 9/14/2017 00:00 - 01:00 1.00 BOPSUR N PRE CHANGE OUT LEAKING DOOR SEAL ON BOPS. 01:00 - 10:00 9.00 BOPSUR =' P PRE REVIEW PROCEDURE AND CONDUCT PJSM FOR TESTING BOPS. SHELL TEST BOPS,GOOD. TEST ANNULAR WITH 2"AND 2-3/8"TEST JOINTS. TEST UPPER BLIND/SHEAR RAMS,UPPER 2" PIPE/SLIP RAMS,UPPER AND LOWER 2-3/8" PIPE/SLIP RAMS,LOWER BLIND/SHEAR RAMS AND LOWER 2"PIPE/SLIP RAMS. TEST ALL CHOKE AND MPD VALVES. -RAM LOCK TESTS COMPLETED. AOGCC INSPECTOR JEFF JONES WAIVES WITNESS. NOTIFICATION GIVEN ON 9/11/2017 @ 16:00 HRS WITNESS WAS WAIVED ON 9/11/2017 @ 21:30 HRS. -RIG EVAC DRILL DURING PRE TOUR WITH LUKE JURY'S CREW. 10:00 - 17:30 7.50 BOPSUR P PRE CONTINUE TESTING BOPS. ALLOTTED BOP TEST TIME STARTED AT 00:00 TO 10:00. 17:30 - 18:00 0.50 BOPSUR P PRE TEST C9,C10 FROM OPPOSITE DIRECTION. 18:00 - 20:00 2.00 RIGU P PRE PREP CT CONNECTOR. COMPLETE VALVE CHECKLIST. REVIEW PROCEDURE FOR INSTALLING CT CONNECTOR. DRESS END OF CT FOR CONNECTOR. INSTALL CT CONNECTOR,PULL TEST TO 50K IS GOOD. 20:00 - 21:30 1.50 RIGU P PRE INSTALL BHI CABLE HEAD. i INSTALL CT RISER. 21:30 - 23:00 1.50 RIGU P PRE INSPECT AND CHANGE OUT CT PACKOFFS. M/U NOZZLE AND GET ON WELL,FILL REEL FORWARD. 23:00 - 00:00 1.00 RIGU P PRE LINE UP TO TEST INNER REEL VALVE. WHILE TESTING,CONNECTION IS SEEN LEAKING IN THE REEL HARDLINE. BLEED OFF PRESSURE. 9/15/2017 00:00 - 01:00 1.00 RIGU P WEXIT I TIGHTEN UP REEL HARDLINE. Printed 9/27/2017 9:57:06AM *All depths reported in Drillers Depths' North America-ALASKA-BP Page 3ab4$ Operation Summary Report ._............. ... ... Common Well Name:B-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/16/2017 End Date:9/20/2017 X3-018LY-C:(1,958,490.00) 1 Project:Prudhoe Bay Site:PB B Pad 1 Rig Name/No.:CDR-2 • Spud Date/Time:1/13/1986 12:00:00AM Rig Release:9/22/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000619 Active datum:KB @81.90usft(above Mean Sea Level) Date From-To Hrs 1 Task 1 Code NPT I Total Depth Phase Description of Operations ._. (hr) (usft) 01:00 - 02:00 1.00 RIGU P WEXIT PRESSURE TEST INNER REEL VALVE TO 250/ 3,500 PSI,GOOD. CIRCULATE 1 REEL VOLUME FORWARD AT 3.5 BPM TO PUMP SLACK FORWARD. CHECK TORQUE ON TREE BOLTS. 02:00 - 03:30 1.50 RIGU P WEXIT INSTALL CHECK VALVES IN UQC. PRESSURE TEST UQC,CT CONNECTOR TO 4,700 PSI,GOOD. PRESSURE TEST CHECK VALVES TO 3,500 PSI,GOOD. 103:30 - 06:00 2.50 RIGU P WEXIT PJSM AND REVIEW PROCEDURE FOR 'PULLING TWC. BRING BPV LUBRICATOR AND PULLING EQUIPMENT TO RIG FLOOR. PRESSURE TEST BPV LUBRICATOR TO 3,500 PSI. PULL BPV,170 PSI ON WELL,NO INDICATION OF GAS. 06:00 - 07:00 1.00 KILLW P WEXIT PREPARE TO BULLHEAD KILL THE WELL. -PRE JOB WITH ALL PARTIES INVOLVED. -REVIEW PLAN AS OUTLINED IN WELL PROGRAM. -REVIEW PRESSURE CROSS CHECK LIST. -VERIFY MAX PRESSURE ANTICIPATED AND TRIPS SET ON RIG PUMP. -VERIFY PROPER VALVE ALIGNMENT AND FLUIDS TO BE PUMPED. 1 1-MAKE UP INJECTOR TO WELLAND TEST QTS @ 3500 PSI,OK. -LINE UP TO PUMP DOWN THE 4 1/2"TUBING TO THE PERFS @ 8820'. 07:00 - 09:00 i 2.00 KILLW P WEXIT KILL WELL,(BULLHEAD). ' -BULLHEAD(5)BBLS METH SPEAR. -FOLLOW WITH 220 BBLS 8.6 PPG KCL '-ICP 4 1/2 BPM @ 2500 PSI. -PUMP 220 BBLS,FCP 4.85 BPM @ 2200 PSI. -PUMP(20)BBLS HI VIS PILL. i -FOLLOW WITH 118 BBLS OF 8.8 PPG DRILLING MUD.(QUIKDRIL) , I 1-SEE PRESSURE CLIMBA BIT INDICATING I PILL @ PERFS. 1 -FCP ON MUD,4.85 BPM @ 2150 PSI. -SHUT DOWN AND OBSERVE PRESSURE BLEED DOWN. l -AFTER(15 MINUTES),PRESSURE @ 280 PSI, CONFER W/ODE AND AGREE TO BLEED TO ZERO. 09:00 09:30 0.50 KILLW P I WEXIT MONITOR WELL,LOST(5)BBLS IN 1ST(5) MINUTES. 1 I -LOST(3)BBLS IN NEXT 25 MINUTES- -LOSS RATE ESTIMATED TO BE 6-7 BPH. 09:30 - 10:30 1.00 KILLW P WEXIT I PJSM.LINE UP TO TIGER TANK AND 'DISPLACE COIL. -DISPLACE COIL TO 8.8 PPG DRILLING MUD. -LOSS RATE WHILE DOING THIS @ 4 BPH. 10:30 - 12:30 2.00 STWHIP P WEXIT BREAK OFF INJECTOR. -MAKE UP WHIPSTOCK BHAAS PER BAKER , REP,MWD AND DD. MAKE UP TO 2"COIL.MAKE UP INJECTOR TO WELL. -PT QTS @ 3500 PSI,OK.LOSS RATE @ 2.8 j BPH NOW. Printed 9/27/2017 9:57:06AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 4 e Operation Summary Report Common Well Name:8-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) 1 Start Date:9/16/2017 End Date:9/20/2017 X3-018LY-C:(1,958,490-00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:CDR-2 Spud Date/Time:1/13/1986 12:00:00AM I Rig Release:9/22/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000619 Active datum:KB @81.9ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase 1 Description of Operations (hr) (usft) 12:30 - 15:25 2.92 STWHIP P WEXIT RIH W/WHIPSTOCK ASSEMBLY. -EDC IS OPEN,1/4 BPM/1100 PSI. -RIH @ 80 FPM WITH WHIPSTOCK ORIENTED TO HIGH SIDE. -2.3 BPH LOSS RATE WHILE RIH. 15:25 - 16:15 0.83 STWHIP P WEXIT LOG GAMMA F/8835'-8875'. -SUBTRACT 6'CORRECTION. -25K DOWN WT.PICK UP AT 25 FPM PUMPING 1/4 BPM @ 1150 PSI. -PICK UP 5'AND SEE BREAKOVER.UP WT 37K. -POOH TO 8391',(CCL @ 8350'). -LOG DOWN CCL @ 16 FPM,1/4 BPM©1170 PSI. 16:15 - 17:15 1.00 STWHIP P WEXIT UP WT 37K,DOWN WT 25K. -RIH W/WHIPSTOCK. " -CCL SHOWS COLLAR TO BE @ 8901'. -TAG EARLY@ 8911'.CIBP SHOWN TO BE @ 8916'. -PICK UP,3'TO BREAKOVER. 1-TOP OF WHIPSTOCK CALCULATED TO BE @ 8901.25'. -CALL ODE AND DISCUSS W/WOS,ODE AND BOTH WSLSAS WELL AS BAKER HAND. -AGREED TO SET WITH TOP OF WHIPSTOCK. 8901.25'. -TAG ONE MORE TIME @ 8911',PICK UP TO 8907',(1'OFF OF CIBP). 17:15 - 18:00 0.75 STWHIP P 8,$98.00 ', WEXIT !CLOSE EDC AND PRESSURE UP TO 3,500 PSI TO SET WHIPSTOCK. SET 4K DOWN TO CONFIRM SET. TOP OF WHIPSTOCK IS 8,898'SET AT HS ORIENTATION. PICK UP ABOVE WHIPSTOCK AND CONDUCT j SEVERAL PICKUPS AT DIFFERENT SPEEDS TO DETERMINE THE EFFECT OF PICKUP SPEED ON COIL WEIGHT. 18:00 - 20:00 2.00 STWHIP P 8,898.00 WEXIT POOH,PUMP 1 BPM. AT 6,722'LIGHT RETURNS ARE NOTICED. i STOP HERE AND MEASURE OUT DENSITY WITH MUD BALANCE,8.7#HEAVY. OUT MM IS SHOWING 8.3#. LEL IS ZERO AT THE SHAKER. CONDUCT 10 MIN FLOW CHECK AT THE RIG FLOOR,NO FLOW. CONTINUE POOH. SOURCE OF LIGHT FLUID IS LIKELY THE ZONE FROM THE BOTTOM PERF AT 8,850'TO THE BRIDGE PLUG AT 8,911'WHICH DOESN'T GET SWEPT BY THE BULLHEAD. Printed 9/27/2017 9.57:06AM `AII depths reported in Drillers Depths* North America-ALASKA-BP Page 5 6i Operation Summary Report Common Well Name:B-29 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:9/16/2017 End Date:9/20/2017 X3-018LY-C:(1,958,490.00) Project:Prudhoe Bay Site:PB B Pad Rig Name/No.:CDR-2 Spud Date/Time:1/13/1986 12:00:OOAM Rig Release:9/22/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000619 Active datum:KB @81.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 20:00 - 21:30 1.50 STWHIP P 8,898.00 WEXIT MONITOR WELL FOR 10 MINUTES AT BHA: STATIC -CLOSE EDC,POWER DOWN -INJECTOR OFF:20:15 -WHIPSTOCK SETTING TOOL HAS FUNCTIONED NORMALLY. MAKE UP 2.74"MILLING BHA#2 -PICK UP 2-3/8"XTREME MOTOR(0.6 DEG AKO)AND 2-3/8"COILTRAK TOOLS -SURFACE TESTED COILTRACK TOOL.GOOD TEST. -PRESSURE TEST QTS TO 3,500 PSI HIGH FOR 5 MINUTES,GOOD. -INJECTOR ON:21:15 21:30 - 00:00 2.50 STWHIP P 8,898.00 WEXIT 'RIH WITH 2.74"MILLING BHA#2. RATE:0.21 BPM IN,0.58 BPM OUT.CIRC PRESSURE:1,000 PSI -MUD WEIGHT:8.78 PPG IN,8.81 PPG OUT -LOG DOWN FOR TIE-IN FROM 8,950' (FORMATION)WITH-8'CORRECTION. -DRY TAG WHIPSTOCK AT 8,899'. 9/16/2017 00:00 - 05:00 5.00 STWHIP P 8,898.00 WEXIT MILL 2.74"WINDOW IN 3-1/4"CASING PER l(1 In T BAKER REP FROM 8,898'MD TO 8,900.2'MD RATE:1.70 BPM IN,1.66 BPM OUT fJ-'!�l� -MUD WEIGHT:8.77 PPG IN,8.80 PPG OUT ✓ -DWOB:1-2.2 KLBS -CIRC PRESSURE:3,520 PSI -BLEED IA FROM 750 PSI TO 100 PSI,BLEED OA FROM 620 PSI TO 50 PSI. 05:00 - 10:45 5.75 STWHIP P 8,913.00 WEXIT CONTINUE TO MILL WINDOW AS PER PROGRAM. - 1-2K WOB,150-250 PSI MOTOR WORK. -1.7 BPM @ 3400 PSI FREE SPIN.UP WT 37K, 25K DOWN WT. -MILL WINDOW TO 8903',SEEING FORMATION IN RETURNS. -MILL RATHOLE TO 8913'.SAMPLE TAKEN @ 8905' - SHOWS SIGNIFICANT AMOUNT OF FORMATION.(SHUBLIK) 10:45 - 12:00 1.25 STWHIP P 8,913.00 WEXIT PERFORM(3)REAMING PASSES AT 1'/MIN. -PICK UP 3.5'@ 25 FPM AND OBSERVE BREAKOVER. -PUMPING 1.7 BPM @ 3400PSI.37K UP WT. -BACKREAM WINDOW UP AT HS TOOLFACE. -REAM DOWN AT HIGH SIDE TOOLFACE. -BACK REAM UP AT 15 DEG LEFT OF HS TOOLFACE. -REAM DOWN AT HS TOOLFACE. -BACKREAM UP AT 15 DEG RIGHT OF HS TOOLFACE. -DRY DRIFT TO 8913',SMOOTH WITH NO RESISTANCE. 12:00 - 14:00 2.00 STWHIP P 8,913.00 WEXIT POOH ABOVE WINDOW,OPEN EDC AND PUMP @ 2 BPM @ 3250 PSI. -PAINT EOP FLAG @ 8700'.(8795'BIT DEPTH). -POOH.FLOW CHECK AT SURFACE/10 MIN. -WELL BORE STATIC,8.8 PPG MUD IN AND OUT. -2 BPH LOSS RATE WHILE POOH.INJECTOR OFF @ 14:00 HRS. Printed 9/27/2017 9.57:06AM `AII depths reported in Drillers Depths* TREE= 4-1/16"CM/ • SAVOTES:WELL ANGLE >7Q°@ 10221'***4-1/2" VVELLFEAD= MCEVOY B-29 A CFR TBG*** ACTUATOR= BA KH OKB.ELE'V= 81.9' ) i RIEF ELB/= 81.9' BF. REV= 42.5' 2130' —14-1/2"0115'HXCY SSSV NP,ID=3.813" KOP= 4200' 20'CONDUCTOR, 110' I Max Angle= 92°@ 10450' #, GAS LFT MANDRELS [ ST MD 'IVD DEV TYPE VLV LATCH FORT DATE Datum hot)= 9939' D= 7 3017 3017 1 CARKX) DM' RK 0 07/13/17 Datum ND= 8800'SS 6 4990 4950 21 CARCO DAY RK 0 07/13/17 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 2684 1 Fr. 5 6263 6125 22 CAPA:X) DMY RK 0 05121/92 4 7103 6910 19 CAMX) DMY RK 0 06/16/01 3 7668 7449 15 CARCO DAY RK 0 08/29/00 2 8200 7966 13 CARCO DMY RK 0 05/21/92 Minimum ID = 2.387" @ 8930' 1 8305 8068 14 CARCO OW RK 0 06/16/01 3-3/16" X 2-7/8" XO 8371' H4-1/2"SWS NIP,113=3.813'j i L 8438. IHBKR LOC SEAL ASSY,ID=3.875" M 1 8440' —19-5/8"X 4-1/2"BKR'DB'PKR,ID=4.750" ] .! .%. 1.' V 8446' —I BKR SEAL BORE EXTENSPON,ID=4.750" .. ----.1 8453' —17"MLLOUT EXTENSION,ID=6.00" 1 .......\ 8460' —7"X 4-1/2"XO,ID=3.956" I 8488' H 1/2"SWS NP,0=3.813" 8509' H BKR DEPLOY SLV w/GS PROF,ID=3.00" 8 3-1/2"X 3-3/16"X 2-7/8"LNR TOP —1 8609' .1" BEHIND TOP OF 7"LIsR —1 8541' 8641' —19-5/Er x 7^BOT L7P,ID=? CT LNR MI 3-1/2"LNR.9.3#,L-80,.0087 bpf,0=2.992" — 8950' .- 1 8650' H3-1/2"X 3-3/16" X0.ID=2.786" I 1-------- I 8682' —4-1/2"SVVN NIP-MLLED TO 3.80"(12/17/00) 4-1/2"TBG, 12.6#,13CR-90,TDS, H 8594' / \ 8694' —14-1/2"VVLEG,0=3.958" BEHIND .0152 bpf,I)=3.958" 8613' --I ELMD TT-LOGGED 08/17/95 CT LNR j 8779' —7"MA RICER JOINT 9-5/8"GSG.47#,L-80 BUTT,113=8.681" H 8800' j--al I lk MLLOUT WNDOW(B-29A) 8851'-8867' 7"W-IFSTOCK(12/09/00)WI RA TAG,c, 8858' 1-1 8848' . L 8898' 1-1 3-3/16"W-UPSTOCK(09/15/17) 7"LNR,29#,L-80 BTRS,.0371 bpf,0=6.184" H 9600' 8916' —13-1/4"BKR CUP(10/07/16) I 8930' H3-3/16"X 2-7/8" XO,D=2_387" PERFORATION SUMMARY .•..1.1.1.1../4 W'( REF LOG:INTE0 MIAO/GR ON 02/03/01 .1.4.... 10330'CTMD H2-7/8"BUT CUP(8/24/14) 1..1... I ANGLE AT TOP POT: 16°@ 8820 1.4...4. I.4.4.4.4.4.4.4.1 Note:Refer to Production DB for historical perf data 10432°CTM —FISH CEP MLLED SIZE SIT INTERVAL Opn/Sqz SI-OT SQZ 3-3/16"LNR,6.2#, —1 8930' 9 PUSHED(5/27/12) 2" 6 8820-8850 0 10/07/16 L-80,.0076 bpf, 7' f*,4, 6 8934-8984 S 04/16/01 04/27/13 ID=2.80' PBTD H 10,464' 7 6 9290-9300 S 04/15/01 04/27/13 FISH:CBP MLLED —1 10439 4111* 2" 6 9418-9428 S 04/15/01 04/27/13 &FUSFED 2" 6 10280-10300 C 10/20/12 (05/04/13) 2" 6 10370-10450 C 02/11/01 _ 2-7/8"LNR,6.5#,L-80 571_,.0058 bpf,13=2.441" H 10,500' DATE REV BY COMMENTS DATE REV BY COMMITS PRUDHOE BAY UNIT 01/28/86 ORIGINAL COMPLETION 12/31/15 RCT/JMD GLV 00(12/26/15) VVELL: B-29A 05/25/92 AUC1#2 RfVO 09/28/16 JG/JM) GLV 00(09/26/16) PERMIT'S/3:'2002090 02/11/01 A USD1114 C.T.SIDE TRACK("B-2911") 10/11/16 JUJM3 SET C33P/ADPERFS(10/07/16) API No: 50-029-21523-01 03/07/14 TBD/JM) SET EVO-TREVE PLUG(2/25/14) 07/17/17 JMG/JMD GLV 00(07/13/17) Sec.31,T11N,R14E,399'FM_&1892'FR_ 04/20/14 GA'PJC RLL EVO PLUG(04/20/14) 09/17/14 CR/JM) SET CIBP/PERF CORRECTIONS BP Exploration(Alaska) SOF 0,1",‘V/7,...,„7., THE STATE Alaska Oil and Gas of AIKA Conservation Commission 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T .., :*+ Main: 907.279.1433 OF ALAS*N. Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna J. Egbejimba Engineering Team Leader—CTD & RWO BP Exploration (Alaska), Inc. SEAMEDAA P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU B-29A Permit to Drill Number: 200-209 Sundry Number: 317-331 Dear Mr. Egbejimba: 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, P4L \i Cathy '. Foerster Commissioner DATED this 2.10 day of July, 2017. RBDMS 1-k-- JUL 2 7 2017 STATE OF ALASKA 0 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ 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 0. 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: 200-209" 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0' 6. API Number: 50-029-21523-01-00 e 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 0 , PBU B-29A " R EC E IV ED 9. Property Designation(Lease Number): 10. Field/Pools: .JUL 1 9 20,17 ADL 028310' PRUDHOE BAY,PRUDHOE OIL - Pts ?124-51/ 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): vv 10503 , 9034 . 8916 8654 2433 8916.10330 10423,10439 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"x 30" 42-122 42-122 Surface 2643 13-3/8" 41-2684 41-2683 4930 2670 Intermediate 8763 9-5/8" 39-8802 39-8548 6870 4760 Liner 310 7" 8541-8851 8297-8595 8160 7020 Liner 1992 3-1/2"x 3-3/16"x 2-7/8" 8508-10500 8265-9034 See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8820-10450 8566-9034 4-1/2"12.6# 13Cr80 36-8592 Packers and SSSV Type: 4-1/2"Baker Model D Packer Packers and SSSV MD(ft)and ND(ft): 8438/8197 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0' Service 0 14.Estimated Date for Commencing Operations: July 25,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 " 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Leemhuis,Jacob be deviated from without prior written approval. Contact Email: Jacob.Leemhuis@bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 4989 Authorized Title: Engineeringy /Team Leader-CTD&RWO Authorized Signature: .7 y " � _ Date: 7 j '( 512. 0 v` r/ / COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3kZ - 33 \ Plug Integrity ❑ BOP Test n Mechanical Integrity Test 0 Location Clearance ❑ Other: P.UP-f5-± 74 35t2 0p,-5/ l/U pS f �Y) a pre" i --r 7 I'S, 3-C n G ., l GiC t�vrr� 1 �I)id 1--___°l�' Post Initial Injection MIT Req'd? Yes❑ No [ �� I7 r'w'CAA-C 2-5 - I<Z(C) - Spacing Exception Required? Yes❑ No E3 Subsequent Form Required: f 0 —4 j) / APPROVED BYTHE Approved by: etli � se41.4......_ COMMISSIONER COMMISSION Date:7.4_ /7 yrL- ?-1Z 5--/,re l ORIGINAL RBDMSt/`'JUL272017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate .,YrS ?.}e,.'7 • To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis 0 tp CTD Engineer Date: July 17, 2017 Re: B-29A Sundry Approval Request Sundry approval is requested to plug the B-29A perforations as part of the preparation, drilling and completing the proposed B-29B coiled tubing sidetrack. History of B-29A: Well B-29A is a coil sidetrack drilled in February 2001, and it is completed in the 25P section of Z2B. Zone 4 perforations were added in April 2001, but they quickly hit marginal GOR. In over 15 years B-29A's on time was < 20%. After multiple unsuccessful gas shut-offs and squeezes, Sag perfs were added in 2016 as end of life wellwork. B-29A has no remaining value in the Ivishak and is proposed to be sidetracked to B-29B target location. Using B-29A as a donor bore will allow to access the B-29B prospect via a straightforward coil sidetrack. There are no other coil sidetrack donor bores in the area and the target does not justify drilling with rotary. Proposed plan for B-29B: Drill a through tubing sidetrack with the Nabors CDR2 Drilling rig on or around September 1, 2017. The B-29B sidetrack will be a single string exit from the existing 3-3/16" liner. A 3-3/16" Whipstock will be set above a c1BP plug. B-29B will kickoff from 3-3/16" liner drilling a vertical well through Ivishak. The well will be completed with 2-3/8" 13Cr-85 production liner, cemented and perforated post rig. This Sundry covers plugging the existing B-29A perforations via the liner cement lob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). 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. Pre-Rig Work(scheduled to begin July 20,2017) 1. C Drift Whipstock 2. V Pre-CTD tree work. Rig Work(scheduled to begin September 1, 2017) 1. MIRU and test BOPE 250 psi low and 3500 psi high (MASP 2,433 psi). 2. Set 3-3/16" monobore whipstock 3. Mill 2.80" window and 10' of rathole. 4. Drill Build: 3.25" OH, -215' (30 deg DLS planned). 5. Drill Lateral: 3.25" OH, -1940' (12 deg DLS planned). 6. Run 2-3/8" 13Cr-85 liner leaving TOL at-8465' MD. 7. _ Pump primary cement job: 16.4 bbls, 15.3 ppg Class G, TOC at-8465' MD. 8. Freeze protect well to a min 2000' TVDss. 9. Close in tree, RDMO. Post-Rig Work 1. V Tree work as necessary 2. F Liner lap test(positive pressure test) 3. S Set live GLVs, set LTP (if necessary) 4. C RPM log, circulate to diesel, perforate -40' 5. S Regulatory compliance SBHPS Jacob Leemhuis CC: Well File CTD Engineer Joe Lastufka 564-4989 • ELLFEAD= MCEVOY • B���A I .,....�� .,. ...«. .s C E TBG " GTUA.TOR= BAKER KB.ELEV= 81.9' 1 LI _.ELEV= 43.95' DP= 4200' 2130' H4-1/2"OTIS'FAO'SSSV NP,D=3.813" ax Angle= 92°@ 10450' 20"CONDUCTOR, 110' 3tum MC)= 9939" GAS LFT MANDRELS 3tum TVQ= 8800'SS D= ST MD TV Q DEV TYPE VLV LATCH FORT DATE 7 3017 3017 1 CAMCO DOME RK 16 09/26/1 13-3/8"CSG,72#,L-80 BTRS,ID= 12.347" H 2683' 6 4990 4950 21 CAMCO DOME RK 16 09/26/1 5 6263 6125 22 CAMCO CMY RIC 0 05/21/s 4 7103 6910 19 CAMCO DMY RK 0 06/16/C 3 7668 7449 15 CAMCO DAN RK 0 08/29/C 2 8200 7966 13 CAMCO DMY RK 0 05/21/s Minimum (D =2,387" @ 8930' 1 8305 8068 14 CAMCO MY RK 0 06/16/C 3-3/16" X 2-7/8" X0 8371' —4-1/2'SWS NP,D=3.813" 1 8438' HBKR LOC SEAL ASSY,D=3.875" 8440' —I9-5/8"X 4-1/2"BKR'DB'PKR,D=4,750" 8445' —{BKR SEAL BORE EXTENSION,ID=4.750" 8463' —7"MLLOUT EXTB ISION,D=6.00" \ 8460' *7"X 4-1/2'XO,ID=3.958' I 8488• --14 1/2"SWS NP,D=3.813" 3-1/2"X 3-3/16"X 2-7/8'LNR TOP —{ 8509' 1 8509' H BKR DBRLOY SLV w/GS PROF,D=3.00" BEHIND TOP OF 7"LNR N 8541' 8541' --19-5/8"x 7"BOT LIP,D=? CT LNR 3-1/2'LNR,9.3#,L-80,.0087 bpf,ID=2.992' — 8550' 8550' H3-1/2"X 3-3/16" XO,U.=2 786" I --{ 8582' —14-1/2"SWN NIP-NILLED TO 3.80"(12/17/00) 4-1/2"TBG, 12.6#,13CR-80,TDS,H 8594' / \---I 8594' 1-14-1/2"WLEG,D=3.958" BEHIND .0152 bpf,D=3.958" 8613' —j ELMD IT-LOGGED 08/17/95 1 CT LNR 1 8779' H7"MARKER JOINT 9-5/8"CSG,47#,L-80 BUTT,D=8.681" —{ 8800' 4 , 7"WI-PSTOCK(12/09/00)w/RA TAG @ 8858' --{ 8848' I MLLOUT WINDOW(8-29A) 8851'-8867' r LNR,29#,L-80 SIRS,.0371 bpf,ID=6.184" H 9500' 8916' H3-1/4"BKR CBP(10/07/16) TION SUNMAf,, /; 8930' H3-3/16"X 2-7/8" XO,ID=2.387" REFFERFORALOG: EQ MWDIGR ON 02/03/01 1.4.4."4.4. // , • `, M 1.4.../1...... 10330' CTMD',H2-7/8"BOT CBP(8/24/14; ANGLE AT TOP PERF: 16"@ 8820 I.40.4.11..4..4..It 4..4 Note:Refer to Production DB for historical pert data 10432' CTM FISFt CEP NILLEC SCE SPF MBR'VAL Opn/Sqz SHOT SOZ 3-3/16"LNR,6.2#, —1 8930' 1411k. &PUSHED 2" 6 8820-8850 0 10/07/16 L-80, 0076 bpf, //" PBTD 2" 6 8934-8984 S 04/16/01 04/27/13 DH10,454=2.80" �`'# 2" 6 9290-9300 S 04/15/01 04/27/13 FISH:CBP MILLED .— 10439' 2" 6 9418-9428 S 04/15/01 04/27/13 8FED 2" 6 10280-10300 C 10/20/12 2" 6 10370-10450 C 02/11/01 (05104/13) {2-7/8 INR 6.5#,L-80 STL, .0058 bpf,D=2.441" 1— 10,500' 1 DATE REV BY CONIVENTTS DATE REV BY C ONIV ENTS PRUDHOE BAY UNIT 01/28/86 ORIGINAL COMPLETION 12/31/15 RCT/JMD GLV C/O(12/26/15) WELL: B-29A 05/25/92 Ata#2 RWO 09/28/16 JTG/JMD GLV C/O(09/26/16) PERMIT No:12002090 02111/01 AUSD#4 C.T.SIDE TRACK("B-29A") 10/11/16 JUJMD SET CBPIADPERFS(10/07/16) API No: 50-029-21523-01 03/07/14 TBCIJM) SET EVO-TRIEVE PLUG(2125114) Sec.31,T11N,R14E,399'FNL&1892'FE. 04/20/14 CAN PJC PULL EVO PLUG(04/20/14) fl0/1711A ("01 Ill SI CCT('1QC t C MOa0"TYIMC DO Cr../.....f:..../A1....1...1 r AIL IRS= SAFETY NOTES:WELL ANGLE >70°@ ""4-1/2" V E..LHEAD= MCEVOY PROPO D B-2 9 CHROME TBG"' ACTUATOR= OKB ELEV= 819' REV 1 I I BF.ELEV= 43.95' KOP= 4200' - 2130' -14-112'OTIS'I-IXO'SSSV ,D=3.813" .- Max Angle= . .°@ _ 20"CONDUCTOR, H 110' 0 __ _-- Datum MD= _#, GAS LFT MANDRELS Datum TVD= 8800S D= "X)' ST MD TVD DEV TYPE VLV LATCH FORT DATE 'SS 7 3017 3017 1 CAMCO DOME RK 16 09126/16 13-3/8'CSG,72#,L-80 BTRS,D=12.347' 2684' I 6 4990 4950 21 CAM00 DOFuE RK 11066 6 09126/16 5 6263 6125 22 CAMCO DMY RK 0 05/21/92 4 7103 6910 19 CAMCO DMY RK 0 06/16/01 Minimum ID = '. ' 3 7668 7449 15 CAMCO DMY RK 0 08/29/00 2 8200 7966 13 CAMCO DMY RK 0 05/21/92 1 8305 8068 14 CAMCO £MY RK 0 06/16/01 TOP OF LNR - -8466' F 1 -8360' H___:.DEPLOY Sl V,U-__" 8371' --I4-1/2"SWS fes,D=3.813" -- 8438' -BKR LOC SEAL ASSY,ID=3.875" 8440' H9-5/8"X 4-1/2"6K14'06'PKR,D=4.750" l 21 8446' - END IBKR SEAL BORE EXTSION, =4.750" " - 8453' 7'MLLOUT EXTENSION,D=6.00" BEHIND \ 8460'_H7"x 4-1/2"xo,D=3.958" CT LNR- 8488' 14 1/2"SWS NP,D=3.813" 13-1/2'X 3-3/16'X 2-7/8"LNR TOP H 8609' _ L8609' - DEPLOYD i BKR DEPLOY SLV w/GS PROF, =3.00" BEHIND TOP OF r LNR --i 8641' - 8541' -19-5/8'X 7"BOT LIP,D=7 CT LNR 3-1/2"LNR 9.3#,L-80,.0087 bpf,D=2.992' -{ 8660' I 8660' - 13-1/2"X 3-3/16" XO,D=2.786" , 8682' -I4-1/2"SWN NIP-MLLED TO 3.80'(12/17/00) 4-1/2'TBG,12.6#,13C R-80,TDS, H 8594' f8694' --14-1/2"WLEG,D=3.958" BEHIND .0152 bpf,13=3.958" 8613' H EMD TT-LOGGED 08/17/95 CT LNR * 8779' -1r MARKER JONT 9-5/8'CSG,47#,L-80 BUTT,D=8.681" -1 8800' I-4 I , 7"WHIPSTOCK(12/09/00)w/RA TAG @ 8858' H 8848' I MLLOUT WINDOW(B 29A) 8851'-8867' 7"LNR 29#,L-80 BTRS,.0371 bpf,D=6.184' H -8848' is T WNOOW(R.-298) 8909' 1313/16'MONOBORE WS w/2 RA TAO: / / I-L 890F' ■ 71 3-3/16"LNR 6.2#,L-80, 0076 bpf,ID=2.80" PERFORATION SUMMARY FIEF LOG NTEO MWD'GR ON 02/03/01 ANGLE AT TOP FERE 16"@ 8820 Note- Refer to Production DB for historical perf data SIZE SFf IYTERVAL Opn/Sqz SHOT SQZ PBTp ` 2" 6 8820-8850 0 10/07/16 -.-� 1 _bpf,13= 11086' I DATE REV BY COMMENTS r DATE REV BY I COMVENTS —) PRUDHOE BAY UNIT 01/28/86 ORIGINAL COMPLETION WELL B-29 05/25/92 AUDI#2 RWO PERMIT No 02111/01 AUSD#4 C.T.SIDE TRACK("F3-29A") API No. 50-029-21523-0 f1 N t .. Sec.31,T11N,R14E,399'FAL&1892'FEL 07/11/17 JB.IJFVL} 1 , I A= :1 ', i BP Exploration(Alaska) Well Blank ••CDR2-AC BOP Schematic . Date _ _ _ _ _ _ _ Quick Test Sub to Otis 1 -1.1 ft I Top of7"Otis I A.� - - - - - - - - - - - - - - - +—CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub Top of Annular I 0.0 ft, . ► 1 ' ' n�� 7-1/16"5k Flange X 7"Otis Box C--"' '''. Hydril 7 1/16" ,7.....,,,..._.,.,_, ) Top Annular Element 0.7 ft Annular ,7 Bottom Annular 2.0 ft ► "`,..mmin Blind/Shear CL Blind/Shears I 3.3 ft ► 2"Pipe/Slips CL 2"Combi's r 4.1 ft BS ll � B6 ""„„" c7 '. BS Deployment Line �� ,1111110., _ t. . r' r 1ne 'Sk mud � 6 ,II, Y lli NI Ill Choke Line 2 3/8"Pipe/Slips CL 2-3/8"Combi's 6.6 ft 2 3/8"Pipe/Slips CL 2 3/8"Combi's 7.4 ft 81 I B2 B3 I, B4 Choke Line Kill Line .1 f r.f M►^� rri tf14 r4 ;iii MMMwl_ llr ill Blind/Shear 1 CL Blind/Shears 10.0 ft ► _ 2"Pipe/Slips Iris CL2"Combi's 10.7ft ► ., i LI • CL of Top Swab 13.3 ft �.4 4.-----Swab 2 Test Pump Hose ip. �/Swab 1 CL of Bottom Swab 14.8 ft *`1 If T1 i T2 CL Flow Tee 16.2 ft •�� _ BOP2 CL of SSV 17.5 ft 1 t Master 2 } Fusable CL of Master Valve 19.0 ft BOP1 Master 1 LDS 20.5 ft — --0..- _ II 11 11 11 Ii Gound Level C4 ; ii u n u n It it .1 11 11 l' • • 0 Thousand Cubic Feet of Gas ("MCF") per Day or 0 Gas-Oil Ratio (MCF per Barrel) 0 0 0 0 0 0 0 0 .. . co too ct N o Oe 1 -' , Pt 1 '4Pr w E 9 44St - ----- ^-,___.. _ L In (6 O�4 CO -a Q .r At u ai C --=__ -._C CO 2 44, -Da N fa CG -- - Fro2 a CO --__- • r, fro m to �, 14P/ Z0 -a M c 0.. : r'Oe ? CU U O J U >� oQ0G -- .. ' -....4., 4P3 W m - E CO 0 °Coo� g O = O O 2 E 6,0 O U 2 aE e o 0 v o U I eo�o CI - -- �"14P c U �/ to J w/ COCLC D CU 902 4 1i Pi - - > a soot 4 I ii o co z Ark' _ S. Oo ep4co n e 4P - o ea,o 4P > 1 '4 1 • ---- o o 0 0 0 0 0 0 00„e4P N- lG to Tr m N rl P Aea aad aale/N in slaa.iee Jo Aea Jad 110 fo slaaae8 0 a S 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 Responsible 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 ,4s work) the initial reviewer will cross out that erroneous entry and initial the 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, they 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, they 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, they 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 Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well ElRe-enter Susp Well ❑ Other: e/r�n `CI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 200-209 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21523-01-00 7. Property Designation(Lease Number): ADL 0028310 8. Well Name and Number: PBU B-29A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10503 feet Plugs measured 8916/10330 feet true vertical 9034 feet Junk measured See Attachment feet NOV 1 4 A 2016 Effective Depth: measured 8916 feet Packer measured 8438 feet true vertical 8654 feet Packer true vertical 8197 feetOcC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 42-122 42-122 Surface 2643 13-3/8"72#L-80 41 -2684 41 -2683 4930 2670 Intermediate 8763 9-5/8"47#L-80 39-8802 39-8548 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 8820 8850 feet feet 8934-8964 feet 8964-8984 feet 9290-9300 feet 9418-9428 feet 10280-10300 feet 10370-10450 feet True vertical depth: 8566-8594 feet feet 8669-8692 feet 8692-8705 feet 8776-8778 feet 8809-8812 feet 9020-9024 feet 9034-9034 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 36-8592 36-8346 Packers and SSSV(type,measured and 4-1/2"Baker Model D Packer 8438 8197 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7 Treatment descriptions including volumes used and final pressure: scm��E� MAR 0 8 2.01 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 298 42293 512 1300 999 Subsequent to operation: 150 8876 0 1550 190 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 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 Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,, Garry R(Wipro) Title PDC Principal Engineer Signature .r 1�7�, Phone +1 907 564 4424 Date 11/10/16 ✓✓✓/1- 1 L RW m S L �,✓ ... . -wt3 Form 10-404 Revised 5/2015 �` Z /' A Submit Original Only 747;7 S • Junk Attachment PBU B-29A SW Name MD Date Comments B-29A 10432 05/27/2012 Milled Haliburton Cmt Plug B-29A 10439 05/05/2013 Milled CIBP B-29A 10450 07/24/2001 Milled CIBP 1 ! Q, 0000 000 (6 r` (O � N OCSO O O N n up N N- V +-' O MONCD 0 COt• M O CO G. N N- CO Nt (O G. N- (0 _ O N M O to O (O O V (O o0 nr O nr (O N M nr OUlV1VIUD OM N OO O 00 O 00 O) 00 F— In t` lf) O (O N T- O CO 0 0 nr OO (O 000 000 000 OM3 000 M 4.0 G� N � NOupCOD � N N O O O 00 (O N) N- O 00 Q1 In O Q1 = N 00 00 00 O0 CO 00 V I I I • Q Q a) N � 00nrQ1CCOM (O N vv (") OuoaupLC) LO00 O0000) C CCI H a 0 co 0 0 c) 0) oJJZOOp „ ooppJm CD M N 4# 4# J N J a# lt (/) X ~ - 0) 0 0 0 C N 000 - - N - N - oO CV - CO = 00 - V N `i CD N- . Ns "e4(h V) � O (h N � v 0 CDs cQm 00Oo Ns v v °O ° (i U) N O Mv- OJ W Q C I- 0- W 15 U W O 0 LL CCCLCCCLECCLZ Z t W W W W W W ap O D F- Z Z Z Z Z , U Z J J J J . ' 10 40 z 0 0 <_ & i. e w / cu = 2 0 0 0 2 0 Q W a. & H (Ni 2 = / k C / 0 a >- _ -I Q 1- . _ /2 ~ 02N w-J _ p , p _ . * o T- 0 1- C - EL wOCJ w o tSO2 m � Vw w 2 / 22LIE 2 � � A C k X22 - 0R2 A / 0 co < 0 _1k \ co �CLCV a " 0- � 0 E �� Q * E a) 2 0 ma) o �m2Om oho _i . ma @ wee # nc22m2q Caw < b 0 S m > O d22 mak , .5220 ® < ® LL0 0 ; 0 2 � — a E = 2OD/ / 2kEE � : n ? \ 2 � C ƒ � �ZN / / k < $ $ qc)= k 2 / 0 2 � 20 z pn —E 1k77iir0I § R / 6 � / 1 & O k 2 2 w w w x « 2 % -I C3 0 O � < � , ib -- E20C) F- ID / / / k / CC@ ƒ 2x - mu_ Loo w Oa o0w a © EE n G U5 D > � \ 2 2 - 0- co EL 2 = Ru_ W Lt Ce cecoeem _i _1RR & OLo -) _, = = � nowP D < co200 < < * OZ « 53 aL 000 & 2 e@ . 2 / 2 L c Q \ iN G � 2 w 2 > E J \ < M < LO ƒ D ° uiZ0 CC 'cy CCk / � � \ � � � kd0w � � OL � % k � � m � � nw � m_ khE 2 / c kk % % Q 22CLEtU_ § \ w � 0, CL0 � 0 / Z ƒ 2 � � \ 00 � 4i w wz -Jazz - E0 < Ib / / b � 525 - F- A w T- CD CD < « 2 2 -I F- CC . W _ C 0 2 zz zz -J , UU ) ® ® � � ap 147) \ oU-J � 00r0 � wwkEN ~ -J � w k5IfwE2i' 62 � Uw / 51ww / E / i' DE / g \ � i O ; ; m a. a m m a 2 ; i 0C a. a 03 2 m = < -J > I ! a w 1-- < o o co O d d Iq > Co CO ¥ m q a a 0 « TREE= " 41116"CNY , SAFE'I)TES:WELL ANGLE >70°@ 10221""'4-1/2" rVkEELL EAD= MCEVOY B-2 9A CtROM E TBG*** ACTUATOR- BAKER V OKB.ELEV= 8t9' I Li BF.B-EV= 43.95' KOP= 4200' 2130' —14-1/2"OTIS'HXO'SSSV NP,D=3.813' Max Angle= 92°@ 10450' 20"CONDUCTOR 110' Datum ND= 9939' #,— GAS LET MANDRELS Datum TVD= 8800'SS D= " ST ND TVD DEV TYPE V LV LATCH FORT DATE 7 3017 3017 1 CAMCO DONE RK 16 09126/16 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 2683• 6 4990 4950 21 CAMCO DONE RK 16 09/26/16 lig5 6263 6125 22 CAMCO CMY RK 0 05/21/92 4 7103 6910 19 CAMCO DMY RK 0 06/16/01 3 7668 7449 15 CAMCO MY FE 0 08/29/00 2 8200 7966 13 CAMCO DMY FE 0 05/21/92 Minimum ID =2.387" @ 8930' 1 8305 8068 14 CAMCO DMY RK 0 06/16/01 3-3/16" X 2-7/8" XO ' 837V H4-1/2'SVVS NP,D=3.813" I 843$' --{BKR LOC SEAL ASSY,D=3.875' _ 8440' H9-5/8"X 4-1/2"BKR'DB'PKR,D=4.750" 8445' —BKR SEAL BORE EXTENSION,D=4.750' 8453' -I 7"MLLOUT EXTENSION,D=6.00' 8460' H 7'X 4-1/2"XO,D=3.958" 8488' —14 1/2"SWS NP,D=3.813' 3-1/2'X 3-3/16'X 2-718'LNR TOP —{ 8509' I 6 8509' -i BKR DER..OY SLV w/GS PROF,D=3.00" BEHIND TOP OF 7"LNR — 8541' 8641' H9-5/8"X 7"BOT LW,D=? CT LNR fi 3-1/2"LNR,9.3#,L-80,.0087 bpf,D=2.992' H 8550' 8550' H3-1/2-x 3-3/16" XO,D=2.786" 8582' —14-1/2"SVVN NP-MLLE)TO 3.80'(12/17/00) 4-1/2'TBG,12.6#,13CR2 80,TDS,H 8594' I-- 8594' H4-1/2"WLEG,D=3.958' BEHIND .0152 bpf,D=3.958' 8613' H RMD TT-LOGGED 08/17/95 CT LNR 8779' —I7'MARKt32 JOINT 9-5/8"CSG,47#,L-80 BUTT,ID=8.681" H 8800' 1--411 I , 7"VVMPSTOC K(12/09/00)w/RA TAG @ 8858' —{ 8848' I MLLOUT WINDOW(B-29A) 8851'-8867' 7"LNR,29#,L-80 BTRS,.0371 bpf,D=6.184' —{ 9500' 8916' -I 3-1/4"BKR CBP(10/07/16) SUMMARY —13-3/16"X 2-7/8" XO,D=2.387" PERFORATIONREF LOG:NTEO MWD/GR ON 02103/01 1111111111111111 i/ 11111111 ANGLE AT TOP PERF: 16"@ 8820 1111111111111111 I 10330'CTMD H2-7/8'BOT CEP(8/24/14) 1.1....1.4.4.4./ Note:Refer to Production DB for historical pert data 10432'CTM —FISFt CUP MLLED SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/16"LNR,6.2#, H 8930' ` &PUSHED(5/27/12) 2" 6 8820-8850 0 10/07/16 L-80,.0076 bpf, A/ 2" 6 8934-8984 S 04/16/01 04/27/13 D=2.80" 1� PBTD --J 10,464' 2" 6 9290-9300 S 04/15/01 04/27/13 FISH:CBP MLLED H 10439' , 2" 6 9418-9428 S 04/15/01 04/27/13 &PUSHED 2" 6 10280-10300 C 10/20/12 2" 6 10370-10450 C 02/11/01 (05/04/13) 2-7/8'LNR,6.5#,L-80 STL,.0058 bpf,D=2.441' ]-1 10,500' 1 DATE REV BY COMMENTS DATE REV BY COMeITS FRUDHOE BAY UM' 01/28/86 ORIGINAL COMPLETION 12/31/15 RCT/JND GLV CIO(12/26/15) WELL: B-29A 05/25/92 AID#2 RWO 09/28/16 JTG/JM) GLV CJO(09/26/16) PERMTT No:"1002090 02/11/01 AUSD#4 C.T.SIDE TRACK("B-29A") 10/11/16 JUJND SET CBA'ADPERFS(10/07/16) API No: 50-029-21523-01 03/07/14 TBOJND SET EVO-TRIEVEPLUG(2/25/14) Sec.31,Till'R14E,399'FNL&1892'FEL 04/20/14 CM PJC RLL EVO PLUG(04/20/14) 09/17/14 CR/JMD SET CIBPYFE HF CONS BP Exploration(Alaska) ! fgL B_ ZE A • Pr6 zeo ;qc Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> etc 171ZS 8tI Sent: Sunday, December 27, 2015 2:00 PM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM;AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Boman, Wade;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Glasheen, Brian P; Regg,James B (DOA) Subject: OPERABLE: Producer B-29A (PTD #2002090) MIT-IA Passed All, Producer B-29A(PTD#2002090) passed a MIT-IA on December 26, 2015 following gas lift valve work. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed - • A SSSV is not needed Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid-. expansion. ThankY ou, Kevin Parks -71 ,'Ref ,._. BP Alaska-Well Integrity Coordinator G Organiz iion SCANNED SEP .15 2016 Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinatorCcabp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, December 06, 2015 2:08 PM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS,, 38(PCC OSM; AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Super• endent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East W- s Opt Engr; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Boman, Wade; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordin- •r; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spenc- , ayers, Jessica; Dickerman, Eric; Pettus, Whitney; Glasheen, Brian P; 'Regg, James B (DOA) 'im.re•• • al.:'a.•ov)' Subject: UPDATE December 06, 2015: UNDER EVALUATIO • •roducer B-29A (PTD #2002090) Inner Annulus Repressuzation All, 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, December 06, 2015 2:08 PM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Boman, Wade; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Glasheen, Brian P; Regg, James B (DOA) Subject: UPDATE December 06, 2015: UNDER EVALUATION: Producer B-29A (PTD #2002090) Inner Annulus Repressuzation Attachments: Producer B-29A (PTD # 2002090) TIO Plot.docx All, Producer B-29A(PTD#2002090) was reported to have sustained inner annulus casing pressure over MOASP on December 02, 2015. Pressures were reported to be TBG/IA/OA=SSV/2200/20 psi. The well will remain Under Evaluation until diagnostics have been completed. Plan Forward: 1. Operations: Bleed inner annulus to 1000 psi—DONE 12/03/15 2. Slickline: Dummy gas lift valves 3. Fullbore: Perform MIT-IA 4. Well Integrity Engineer:Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. Thank you, SCANNED MAY 1 2016 Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator YY'`' Organ,,Weat n WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, December 05, 2015 7:36 PM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod 1 • • Controllers; AK, OPS PCC Ops Lead; Boman, Wade Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Glasheen, Brian P Subject: UNDER EVALUATION: Producer B-29A (PTD #2002090) Inner Annulus Repressuzation All, Producer B-29A(PTD#2002090) passed three TIFLs this year, mostly recently on October 03, 2015, but continues to show signs of inner annulus repressurization. The well has been reclassified as Under Evaluation for further diagnostics. As MOASP was not exceeded, no notification to the AOGCC was necessary. Plan Forward: 1. Slickline: Dummy gas lift valves 2. Fullbore: Perform MIT-IA 3. Well Integrity Engineer:Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 2 • • Producer B-29A(PTD#2002090) TIO Plot December 06, 2015 w.,A 29 3OW —0—MO —IF 14 4 004 1—OOOA Oft SCO( .. .. 'sans tons,, 107015 1047»5 110315 1110715 1017/15 1N4,15 1201/15 Imag~roject Well History File Cover~l~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. CAN Color items: Grayscale items: Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation Ax ~o:/~0 BEVERLY ROBIN VINCENT SHERY~--~'~WINDY OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other III IIIllllllll II III ----TOTALPAGES 9~' Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER iN SCANNING PREPARATION" YES _.~ NO Stage 2 IF NO IN STAGE 'Ii, PAGE(S) DISCREPA~RE FOUND: _.~. __.~..~YES ,.,, ~ NO RESCANNEDBY[ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: Is/ Quality Checked 12/10/02Rev3N OTScanned.wpd STATE OF ALASKA ECEIVED ik KA OIL AND GAS CONSERVATION COMitION MAY 2 9 201 3 REPORT OF SUNDRY WELL OPERATIONS ++�ee � q 1. Operations Abandon 11 Repair Well U Plug Perforations U Perforate U Othe Q rl '4�S ueeze• Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc . Development el Exploratory ❑ 200 -209 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21523 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028310 PBU B -29A • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL • 11. Present Well Condition Summary: Total Depth measured 10503 feet . Plugs measured None feet true vertical 9033.57 feet Junk measured See Attachment feet Effective Depth measured 10439 feet Packer measured 8440 feet true vertical 9034.56 feet true vertical 8199 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 38 - 118 38 - 118 0 0 Surface 2647 13 -3/8" 72# L -80 36 - 2683 36 - 2682.9 4930 2670 Intermediate None None None None None None Production 8765 9 -5/8" 47# L -80 35 - 8800 35 - 8546.46 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 8934 - 8964 feet 8964 - 8984 feet 9290 - 9300 feet 9418 - 9428 feet 10280 - 10300 feet 10370 - 10450 feet True Vertical depth 8669.24 - 8691.93 feet 8691.93 - 8705.36 feet 8775.96 - 8778.07 feet 8809.07 - 8811.88 feet 9019.68 - 9024.2 feet 9033.5 - 9034.23 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker D Packer 8440 8199 Packer None None None SSSV 12. Stimulation or cement squeeze summary: 2013 Intervals treated (measured): SCANNED JUN 0 4 10280' - 10300', 10370' - 10450' Treatment descriptions including volumes used and final pressure: 602BBL 2% KCL W /SAFE LUBE, 423BBL 2% KCL SLICK, 227BBL ORGANOSEAL, 98BBL POWERVIS 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 279 37910 174 0 1163 Subsequent to operation: 391 17193 218 0 245 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ' Service p Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil U • Gas ❑ WDSPL[J GSTOR ❑ WINJ ❑ WAG ❑ 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: N/A Contact Nita Summerhays Email Nita.Summerha BP.com Printed Name Nita Summerh., s Title Petrotechnical Data Technician y F V Signa`u 'ity,071j'4 145M ' „��� / •: Phone 564 4035 Date 5/28/2013 tir ' ( X RBDMS MAY 2 9 2013 Form 10 -404 Revised 10/2012 - 0 3 d 1 13 Submit Original Only • • • • Daily Report of Well Operations ADL0028310 ** *WELL S/I ON ARRIVAL***(cement squeeze) DRIFT TUBING WITH 2.25" CENTRALIZER & SAMPLE BAILER. SLOWED TO A STOP DUE TO DEVIATION @ 9078' SLM. BAILER RETURNED TO SURFACE EMPTY. PULLED RK -OGLV FROM STA 6 @ 4990' MD & RK -LGLV FROM STA 7 @ 3017' MD. SET RK -DGLV IN STA 7. 4/20/2013 ** *CONTINUED ON 04/21/2013 WSR * ** T /I /O =ssv /1500/0 Temp=SI Assist S -line MIT IA 2000 psi (Gas Shutoff) RU Start pressure 4/20/2013 Testm ** *Job Cont to 4 -21 -13 WSR * ** ***CONTINUED FROM 04/20/2013 WSR ** *(cement squeeze) LRS LOADED IA WITH 320 BBL OF CRUDE. SET RIK -DLGV IN ST #6 © 4990' MD. LRS LOADED TUBING WITH 130 BBL OF CRUDE. LRS MIT IA TO 2000 PSI. PASS. PULLED EMPTY SLIP STOP CATCHER FROM 5116' SLM. 4/21/2013 ** *WELL LEFT SHUT IN. PAD OP WALK THROUGH UPON DEPARTURE * ** CTU 3, 1.75" Coil. Job Scope: GSO with Organoseal / Sqzcrete. MIRU CTU. SSV did not PT. Order grease crew. Grease and heat SSV and wing 4/25/2013 valves. Good test on swab and SSV. N/U BOPE. «< Job in Progress »> Continued from WSR of 04/25/13. CTU 3, 1.75" coil, Job scope: GSO with Organoseal and Sqzcrete. N/U BOPE. M/U lube. M/U WFD CTC and pull test. PT MHA. M/U PDS GR /CCL in carrier with 2.27" JSN & RIH. Tag down on CIBP at 10403'. Log up at 50fpm from 8200- 10403'. Flagged pipe red /blue at 9425'. POOH. PDS log +55' corr. MU WFD 2 -7/8" CBP & RIH. Set CBP at 9475', POOH. Test bairiers. Lay out running tools. M/U cementing nozzle BHA. PT lube. Fluid pack well with 220 bbl 2% KCL. Injectivity tests at 1,2,3 and 4 bpm. Stage 250 bbl Organoseal treatment down 4.5" tubing. 4/26/2013 ** *Job continued on 4/27/13 WSR * ** CTU 3, 1.75" coil. Job Scope: GSO with Organoseal and sqzcrete. Bullhead 227 bbl Organoseal down 4.5" tubing at 3.7 ppm / 1060 whp. Displace with 10 bbl water, 5 bbl meth, 95 bbl diesel. Close swab and circ coil to diesel. RIH with coil with P -sub closed. Tag CBP at 9455' and correct to 9475'. Pick up to 8470'. Squeezed 37 bbls of SqueezeCrete into formation, WHP stabilized at 1270psi for 1 hr. Contaminate cement down to plug, jetted through 1 stringer at 9210'. Lay in PowerVis from plug to 8360', POOH chasing returns at 80 %. FP well w/ 30bbls of 60/40 methanol. Hold 500psi on WHP. Lay out BHA. Cut 125' coil. PT tree cap. Swap BOP's for monthly change out. 4/27/2013 «< Continued on WSR of 04/28/13 »>. Continued from WSR of 04/2//13 CTU 3, 1.75" coil, Job Scope: GSO with Organoseal and SqzCrete 4/28/2013 Complete monthly change out of BOPE. RDMO. «< Job Complete »> T /I /O - 190/1340/0 Temp.- SI MIT T PASSED to 1500 psi. (Post cement squeeze) Tubing passed MIT on fourth attempt (see mit data0 pumped 2.1 bbls meth blled down pressure rig down (swaqb closed wing closed ssv closed master open annulus valves 4/30/2013 oipen to gauges) FWHP= 55/1387/0 CTU 3, 1.75" coil, Job Scope: Mill CBP at 9475 and push to bottom. MIRU CTU. Good no flow test on swab and SSV. N/U BOPE. Change out packoffs. PJSM. M/U WFD Motor and mill assy, PT Lube and function tested BOP's, RIH pumping the min rate, dry tag the plug @ 9460', started milling the plug 5/3/2013 * * * ** Continued on WSR of 05/04/13 * * * ** • • S Daily Report of Well Operations ADL0028310 * * ** *Continued from WSR of 05/03/2013 * * * ** CTU 3, 1.75" coil. Job Scope: Mill CBP at 9475' and push to bottom. Continued milling WF CBP plug @ 9460', milled the plug and pushed it to the PBTD 10439' CTM, gel sweep the hole and POOH. freeze protected the Coil, well to 2500' and surface lines with 60/40 meth. barrier test. Close swab and SSV. PJSM. Lay out WFD milling BHA. Perform weekly BOPE pressure function testing. No failures. Rig down and secure well. Move CTU to E -36. 5/4/2013 «< Job Complete »> FLUIDS PUMPED BBLS 126 DIESEL 450 CRUDE 349 60/40 METH 602 2% KCL W /SAFE LUBE 423 2% KCL SLICK 227 ORGANOSEAL 98 POWERVIS 2275 TOTAL Casing / Tubing Attachment ADL0028310 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" Conductor 38 - 118 38 - 118 LINER 6 3 -1/2" 9.3# N -80 8508 - 8514 8264.85 - 8270.66 10160 10530 LINER 37 3- 3/16" 6.2# L -80 8514 - 8551 8270.66 - 8306.44 LINER 310 7" 29# L -80 8541 - 8851 8296.77 - 8595.38 8160 7020 LINER 1947 2 -7/8" 6.5# L -80 8551 - 10498 8306.44 - 9033.59 10570 11160 PRODUCTION 8765 9 -5/8" 47# L -80 35 - 8800 35 - 8546.46 6870 4760 SURFACE 2647 13 -3/8" 72# L -80 36 - 2683 : 36 - 2682.9 4930 2670 • TUBING 8406 4 -1/2" 12.6# L -80 34 - 8440 34 - 8199 8430 7500 TUBING 154 4 -1/2" 12.6# 13Cr80 8440 - 8594 8199 - 8348 8430 7500 • TREE= , 4 1/16" CM/ .11 NO WELL ANGLE > 70' 10221 "'"4 -1 D= MCE/OY B-29A CH ACTUATOR= BAKB2 NTIAL KB. B.E 81.9' I KOP= I BF. .EV = 43.95' '= 4 20( I 2130' 1H4 -1/2" OTIB'w(a SSSV NP, D= 3.813', Max Angie = 92° @ 20" OOPD 110' ' Datun MD = 9939' GAS LFT MAPDRB -S Datum ND= 8800' SS ST AA) ND DEV TYPE VLV LATCH PORT DATE 7 3017 3017 1 CAMCO 001E RK 16 05/07/13 6 4990 4950 21 CAMCO DOME RK 16 05/07/13 13-3/8" CSG, 72#, L-80 BTRS, D= 12.347' H 2883' 5 6263 6125 22 CAMCO DMY RK 0 05/21/92 4 7103 6910 19 CAMCO DMY RK 0 06/16/01 3 7668 7449 15 CAMCO OW RK 0 08/29/00 2 8200 7966 13 CAMCO DAY RK 0 05/21/92 1 8305 8068 14 CAMCO DIN RK 0 06/16/01 8371" H4 -1/2" SINS NP, D = 3.813' I Minimum ID = 2.387" @ 8930' 3 -3/16" X 2-7/8" XD —I 8438' BKR LOC SEAL ASSY, D= 3.875" I �1 = = 8440' N9 - 5/8" X 4-1/2' BKR'DB' PKR, D = 4.750" I —1 8446' H BKR SEAL BORE O(TB'SIUN, 13= 4.750" I I 8453' H7' FALLOUT B(TB4SION, 13= 6.00", \ I 8460' H7' x 4-1/2" XO, D = 3.958" I 8488• H4 1/2" SINS NP, D = 3.813' I I3 -1/2" X 3 -3/16" X 2 -7/8' LNR TOP IH 8609' I 1 8609' BKR Leli DEFLOY SLV w /GS PROF, D = 3.00' ITOP OF 7' LPMt H 8641' I m I 8641' H9 -5i8" X 7" BOT LTP, D = ? I 1 3-1/2' LM 9.3#, L-80, .0087 bpf, D = 2.992" H 8550' I --, 8550' H 3-1/2' X 3 -3/16' XO, D= 2.786" I i ll I I 8682' H4 -1/2" SWN NP- MILLED TO 3.80" (12/17/00) ( 4-1/2' MG, 12.6#, 13CR -80, TDB, H 8594 I-- \ - 8694' H4 -112' W.EG, D = 3.958" 0152 bpf, D= 3.958" I 8613' Haman-LOGGED 08117/95 I 40---I 8779' Hr MARKER JO 1 I 1 9-5/8" CSG, 47 #, L-80 BUTT, D = 8.681" H 8800 I • ■ 17" WhPSTOCK (12109/00) H 8848• MtLLOUT WINDOW (1129A) 8851' - 8867' IRA TAG (12/09/00) H 8868' FBRFORATION SUMMARY R8= LOG: MJTEC) I9M YGR ON 02/03/01 1 3.3/16" X 2 -7/8" XO, D = 2.387° ANGLE AT TOP AYR 76° ( 10280' ► 4 • 4 • 4 • 4 • 4 • 4 • 4 • 4 4 ( 8930' H 1 Note: Refer to Production DB for historical pert data I I4 4 4 .. 4 . 4 1 10432 FSft 013P MLLED SIZE SW INTERVAL Opn/Sqz SHOT SQZ 14444444/ i & RJSF ) 2" 6 8934 - 8984 S 04/16/01 07/03/01 3- 3/16" LNR, 6.2#, —I 8930' I (05/27/12) 2" 6 9290 - 9300 S 04/15/01 05/22/12 L -80, .0076 bpf, PBTD 2" 6 9418 - 9428 S 04/15/01 0522/12 D = 2.80" 7 H 10,4 I 2" 6 10280 - 10300 S 10/20/12 RSR CBp MILLED —1 10439' 2" 6 10370- 10450 S 02/11/01 04/27/13 & R1S11D (05/04/13) 7' LNtR 29 #, L -80 BTRS, .0371 bpf, D = 6.184' H 5500' I I2 -7/8' LNR, 6.5#, L-80 STL, .0058 bpf, D = 2.441" H 10,500' I DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY INT 01/28186 ORIGINAL COMPLETION 05/17 /13 C;IWJMD GLV C/O (05/07/13) WELL: B-29A 05/25/92 AUDI #2 R WO PERMIT No: "`1002090 02/11/01 AUSD#4 C.T. SIDE TRACK ('829A") AR No: 50- 029 - 21523 -01 05/30/12 if /JI/O CMT SQZ, WILL CEP(05/22- 27/12) Sec. 31, T11N, R14E, 399' FM- & 1892' FB_ 05/30/12 WISS/JMU GLV CIO (05/28/12) 05/17/13 MAMBA) CMT SQZ, ILL CEP (05/04/13) BP 6cptoration (Alaska) I RECEIVED 1 STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COMMI ION NOV 2 0 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well Plug Perforations U Perforate U Other A� Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weir] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ISI Exploratory El 200 -209 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 21523 -01 -00 7. Property Designation (Lease Number): „ 8. Well Name and Number: ADL0028310 PBU B -29A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10503 feet Plugs measured None feet true vertical 9033.57 feet Junk measured See Attachment feet Effective Depth measured 10464 feet Packer measured 8440 feet true vertical 9033.87 feet true vertical 8199 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 38 - 118 38 - 118 0 0 Surface 2647 13 -3/8" 72# L -80 36 - 2683 36 - 2682.9 4930 2670 Intermediate None None None None None None Production 8765 9 -5/8" 47# L -80 35 - 8800 35 - 8546.46 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 8934 - 8964 feet 8964 - 8984 feet 9290 - 9300 feet 9418 - 9428 feet 10280 - 10300 feet 10370 - 10450 feet True Vertical depth 8669.24 - 8691.93 feet 8691.93 - 8705.36 feet 8775.96 - 8778.07 feet 8809.07 - 8811.88 feet 9019.68 - 9024.2 feet 9033.5 - 9034.23 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker D Packer 8440 8199 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED FEB 2 8 2013 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: 321 49538 45 0 981 Subsequent to operation: 0 0 0 0 0 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 - El Gas ❑ WDSPIU GSTOR ❑ WINJ ❑ WAG ❑ 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: N/A Contact Garry Catron Email Gar BP.COm Printed Name Garry Catron Title PDC PE Signature ida4 Phone 564 -4424 Date 11/15/2012 / VLi RBL MS NOV 21 2012 -= ;&/1--\ ii / 2 r. /1 z IA'fb Form 10 -404 Revised 10/2012 Submit Original Only • • B -29A 200 -209 -0 Junk Attachment SW Name MD Date Description B -29A 10432 5/28/2012 Milled Haliburton Cmt Plug B -29A 10450 7/24/2001 Milled CIBP • Casing / Tubing Attachment ADL0028310 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" Conductor 38 - 118 38 - 118 LINER 6 3 -1/2" 9.3# N -80 8508 - 8514 8264.85 - 8270.66 10160 10530 LINER 37 3- 3/16" 6.2# L -80 8514 - 8551 8270.66 - 8306.44 LINER 310 7" 29# L -80 8541 - 8851 8296.77 - 8595.38 8160 7020 LINER 1947 2 -7/8" 6.5# L -80 8551 - 10498 8306.44 - 9033.59 10570 11160 PRODUCTION 8765 9 -5/8" 47# L -80 35 - 8800 35 - 8546.46 6870 4760 SURFACE 2647 13 -3/8" 72# L -80 36 - 2683 36 - 2682.9 4930 2670 • TUBING 8406 4 -1/2" 12.6# L -80 34 - 8440 34 - 8199 8430 7500 TUBING 154 4 -1/2" 12.6# 13Cr80 8440 - 8594 8199 - 8348 8430 7500 • Daily Report of Well Operations ADL0028310 *��"����^�������'�u CRU�#0 ct. Job Ob]entive:PPROF/CondngentC|8P/Adperf <<<ContinueVV8Rfrom 10/19/2012 10/18/12 >x' RIH w/o|b PPROF w / Ghost logging tools. CRU #9 w/1 .75" Ct. Job Objective: PPROF/Contingent CIBP/Adperf ^<^ Continue VVSRfrom 10/18/12 >» RIH w/o|b PPROF w/ Ghost logging tools. Log up/dn passes ©4Ofpm while producing —40mmsofpd. Choke well in and allow to stabilize. Log up/down passes @ 60/80 fpm and down pass ©40fpm Take stop counts at flag (1O3S1').1U35O'.1O1OO'.S36O'.02OU'.885O'.853O'. and 8470' Load and kill well. Establish injectivity rate: 1 .6bpm @ 41 psi, 1 .9bpm @ 75psi. Complete 10/19/3012 up/down pass @4Ofpm and standby for additional fluids to re-start PITS. ��� CTU #0w/1.75''ot. Job ObienUva:PPR[)F/Contingant(}|8P/Adpe� ��< Continue VVSRhnm ��� 1O/18/12»>> RIH vv/s|bPPROFvv/ Ghost logging tools. Log up/dn passes @4Ofpmwhile producing —40mmeofpd. Choke well in and allow to stabilize. Log up/down passes @ 60/80 fpm and down pass @4Ofpm. Take stop counts et flag (1U391').1O35O'.1O1UU'.835O'.Q2UO'.885U'.853D'. and 8470' Load and kill well. Establish injectivity rate: 1 .6bpm 41poi.1.Qbpm@75psi.Complete up/down pass @ 40fpm and standby for additional fluids to re-start PITS. Log down & up passes @ 10/19/2012 60 fpm & 80 fpm © 1.9 bpm. CTU #9 w/1 75^ oL Job Objective: PPROF/Contingent CIBP/Adperf «< Continue WSR from 10/18/12>>> Log warm back passes @6O fpm after 1 hr and 3 hrs after pump was down. Painted a flag © 10180' POOH. Freeze protected flowline. Data verified good and uploaded to InterAct. Logs indicate all flow coming from 3 sets of squeezed perfs and no flow coming from perfs at 10370'-10450' Decision to shoot adperfs. MU 20' perf BHA and RIH. Perf Guns: 2''PJ Omega 2UOS 10/20/2012 HMX, 6spf, 60 deg phasing. CTU #9 w/1 .75" ct. Job Objective: PPROF/Contingent CIBP/Adperf x^< Continue VVSRfrom 1U/1S/12^» Log warm back passes @OO fpm after 1 hr and 3 hrs after pump was down. Painted ��� 10/20/2012 o�ag��1O18U'POOH. ���� CTU #SwY1.75^ct. Job (]bjeotva:PPROF/CondngentC|BPA�dpe� Continue WSR `�' 10/19/12 >^> Log warm back passes © 60 fpm after 1 hr and 3 hrs after pump was down. Painted a flag © 10180' POOH. Freeze protected flowline. Data verified good and uploaded to InterAct. Logs indicate all flow coming from 3 sets of squeezed perfs and no flow coming from perfs at 10370'-10450' Decision to shoot adperfs. MU 20' perf BHA and RIH. Perf Guns: 2" PJ Omega 2006 HMX, 6spf, 8O deg phasing. Top shot 102QO'bD�om shot 1D3OO' confirmed guns - fired.RDMO 10/20/2012 « Job complete >>» ° 114±.= 41116" CWY III SA TES: WELL ANGLE > 70° @ 10221"'"4 -1/2" WEI.LIEAD= MCEVOY R _ gq CHROME TBG AC . BAKB4 V . KB ELB/ = 81.9' BF. ELEV = 43.95' ' ' - KOP= 4200' I 2130' - I4 -1/2" OTIS'HXO' SSSV NP, 0= 3.813" - Max - Angle n ND C 0 DatuMD= 9939 I = 92° m 10450' 20" COrD I 110' GAS LFT MAPDFELS OdtumTVD= 8800 SS ST FAD 1VD DEV TYPE VLV LATCH PORT DATE 7 3017 3017 1 CAMCO DOME RK 16 05/28/12 5!2 6 4990 4950 21 CAMCO SO FE 20 08112 13 3/8' CSG, 72#, L-80 BTRS, D = 12.347" H 268$' 5 6263 6125 22 CAMCO DMY FE 0 05/21/92 IN 4 7103 6910 19 CAMCO OW FE 0 06/16/01 3 7668 7449 15 CAMCO DMY FE 0 08/29/00 2 8200 7966 13 CAMCO DMY FE 0 05/21/92 1 8305 8068 14 CAIVCO DMY FE 0 06/16/01 _ _ 8371' H4-1/2" SWS NP, D = 3.813" I Minimum ID = 2.387" @ 8930' 3 X 2-7/8" XO I 8438' -I BKR LOC SEAL ASSY, D = 3.875" I M. C 8440' -19 -518" X 41/2" BKR'DB' PKR, D = 4.750" I 0 V I $ 445' - I BKR SEAL BORE EXTENSION, D = 4.750" '—I 8453' H7" MLLOUT EXTENSION, D = 6.00" I `--- 8460' I-17" X 4-1/2" XO, D = 3.958' I I 8488' -I4 112" SWS NP, D = 3.813" I 13-1/2" X 3- 3/16" X 2 -7/8' LNR TOP --1 8509' 1 ' I 8509' _ -- I BKR LNR DEPLOY SLV w /GS PROF, 0= 3.00" I ITOP OP 7' LM H 8541' I m r.. E I 8541' H9-5/8" X 7" BOT LTP, 0= ? 3-1/2' LNR, 9.3#, L -80, .0087 bpf, D = 2.992" H 8550' I I 8550' IH3 -1/2" X 3 -3116" XO, D= 2.786" I } I( 8582' Ha -1/2" SWN NP- MLLED TO 3.80' (12117/00) 4 -112" TBG, 12.6#, 13CR 80, '70S, -I 8594' [ 8594' --I4 -112' WLEG, D = 3.958" .0152 bpf, D = 3.958" L 8613' H ELMD TT - LOGGED 08/17/95 I • I 8779' H7" MARKER JOM I 9 -5/8" CSG, 47 #, L -80 BUTT, D = 8.681" H 8800' • ' I7" VVHPSTOCK (12/09/00) --I 8848' MLLOUT WINDOW (B -29A) 8851' - 8867' RA TAG (12/09/00) H 8858' PERFORATION SUMMARY", REF LOG: NFEO PRMYGR ON 02/03/01 41„ 1 8930' H3-3/16" X 2-7/8' XO, D = 2.387" I ANGLE AT TOP PERT: 76° @ 10280' 1*•*•*•*4*4*•*4, 1 Note: Refer to Production C43 for historical perf data 1 • �•�j�•�•�•�j�4 1 10432' CTM FISH CEP MLLED SIZE SPF INTERVAL Opn/Sqz SHOT ST17 1.84j44�4444j441 & PUSHED 6 8934 - 8984 S 07/03/01 1 4 4 * •■••••1•••• (05/27/12) 11.414.41 r 6 9290 - 9300 S 0522112 1!4!4!4!4!4!4!4!1 ` PBTD -I 10,464' I - -1428 _______S ,, - \,, -_, 05/22/12 X3 /1 fi" LNR, 6.2#, --I 8930' - 1 - 0i70 - - , . \ 610280 -10300 0 10/20/12 2" 6 10d50 O D211110T - L -80, .0076 bpf, D = 2.80" 17" LNR 29 #, L -so BTRS, .0371 bpf, D = 6.184" H 9500' I 2-7/8" LNR, 6.5#, L -80 STL, .0058 bpf, D = 2.441" H 10,500' ] DATE REV BY COMvENTS DATE REV BY COMMENTS I PRIDHOE BAY UNIT 01/28/86 ORIGINAL COMPLETION 05/31/08 DRS/PJC SFTY NOTE! MN DCORRECTION WELL B-29A 05125/92 AUDI #2 RVVO 05/30 /12 FF /JM) CMr SOZ, WALL CBP (05/22- 27/12: P iT Kb: '2002090 02/11/01 AUSD #4 C.T. SIDE TRACK ("B -29A") 05/30/12 M5S/JMD GLV C/O (05/28/12) AR Pb: 50- 029 - 21523 -01 04/29/01 O-YTP CORRECTIONS 06/18/12 JM) PERF BOX CORRECTIONS Sec. 31, T11N, R14E, 399' FTL & 1892' FEL 07/13/01 JLJ/KAK PULL PKRISQZ PEWS 11/12/12 JJL/JMD ADPERF (10/20/12) 05/31 /08 ORS/PJC SFTY NOTE/ MN D CORRECTION BP Exploration (Alaska) STATE OF ALASKA ALA* OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well Li Plug Perforations U Perforate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension El Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other El Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory El 200 -209 -0 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21523 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: r ADL0028310 PBU B -29A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,. See Attachment PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10503 feet Plugs measured None feet true vertical 9033.57 feet Junk measured See Attachment feet Effective Depth measured 10432 feet Packer measured 8440 feet true vertical 9034.73 feet true vertical 8199 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 38 - 118 36.1 - 118 0 0 Surface 2647 13 -3/8" 72# L -80 36 - 2683 2601 - 2682.9 4930 2670 Intermediate None None None None None None Production 8765 9 -5/8" 47# L -80 35 - 8800 8464.56 - 8546.46 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet whikKEDJUN 2 7 2012 RECEitirc True Vertical depth feet P See Attachment A' Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment J�'v 2012 GGll�= Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker D Packer 8440 8199 40 k0C None None None SSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8930' - 10,400'; 8930' - 10,400'; 8934' - 9480' Treatment descriptions including volumes used and final pressure: 51 bbls 12% HCL Acid; 50 bbls 9.1 Mud Acid; 20.8 bbls OrganoSeal Cement, 18.6 bbls behind casing, Final Pressure = 1510 psig. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 357 29877 24 700 1269 Subsequent to operation: 316 21309 60 500 1065 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 7 GSTOR ❑ WINJ ❑ WAG ❑ 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: 311 -362 Contact G.„ 4 y C c c% (O r Prepared by Garry Catron 564 -4424 Printed Name GGt C Q. - 1 (p er Title O�� Vl4 0 e t 11 ��// Signature b� Phone (N yeti -1i Date 6/21/2012 Form 10 -404 Revised 11 DMSJ no Ott IL 6 0t 1_ Submit Original Only • • B -29A 200 -209 -0 Logs Run Attachment Date Log Run 2/24/2012 Caliper (To be submitted) 2/25/2012 PPROF /MCNL /PITS (To be submitted) 2/25/2012 GR /CCL /MCNL (To be submitted) • • B -29A 200 -209 -0 Junk Attachment SW Name MD Date Description B -29A 10432 JUNK 5/28/12 Milled Haliburton Cmt Plug B -29A 10450 JUNK 7/24/01 Milled CIBP • • B -29A 200 -209 -0 Casing / Tubing Attachement Casing Size MD TVD Burst Collapse CONDUCTOR 20" Conductor 38 - 118 38 - 118 LINER 7" 29# L -80 8541 - 8851 8296.77 - 8595.38 8160 7020 LINER 2 -7/8" 6.5# L -80 8551 - 10498 8306.44 - 9033.59 10570 11160 LINER 3 -1/2" 9.3# N -80 _ 8508 - 8514 8264.85 - 8270.66 10160 10530 LINER 3- 3/16" 6.2# L -80 8514 - 8551 8270.66 - 8306.44 PRODUCTION 9 -5/8" 47# L -80 35 - 8800 35 - 8546.46 6870 4760 SURFACE 13 -3/8" 72# L -80 36 - 2683 36 - 2682.9 4930 2670 TUBING 4 -1/2" 12.6# L -80 34 - 8440 34 - 8199 8430 7500 TUBING 4 -1/2" 12.6# 13Cr80 8440 - 8594 8199 - 8348 8430 7500 • • B -29A 200 -209 -0 Perforation Attachment Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base B -29A 4/16/01 PER 8934 8964 8669.24 8691.93 B -29A 4/16/01 PER 8964 8984 8610.03 8623.46 B -29A 7/4/01 SQZ 8964 9000 8610.03 8633.03 B -29A 6/24/01 BPS 9000 9010 8633.03 8638.44 B -29A 7/24/01 BPP 9000 9010 8633.03 8638.44 B -29A 5/27/12 BPP 9000 9010 8633.03 8638.44 B -29A 4/15/01 PER 9290 9300 8694.06 8696.17 B -29A 4/15/01 PER 9418 9428 8727.17 8729.98 B -29A 2/11/01 PER 10370 10450 8951.6 8952.33 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF . ' TREE = 4-1/16" CM/ • SAFElOTES: WELL ANGLE > 70° ,;', 10221' — 4-1/2" WELLHEAD = MCEVOY AdtbATok;. - BAKER B-29A CHROME TBG 0:6: ELb/ . 81 9' . . BF ELEV = 43.95' . .. „„ KOP = 4200' 2130' --I 4-1/2" 011S `HX0 SSSV NIP, ID .-- 3 813" M3X Angle = 92° iil 10450' Ca um MID = 9939' 120' COND I 110' GAS LIFT MANDRELS bWur;,tVb= ' tiado ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3017 3017 1 CAMCO DOME RK 16 05/28/12 6 4990 4950 21 CAMCO SO RK 20 05/28/12 1 13-3/8" CSG, 72#. L-80 BTRS, 0 = 12.347' H 2683 I Ilir 5 6263 6125 22 CAMCO ow RK 0 05/21/92 4 7103 6910 19 CAMCO DMY RK 0 06/16/01 3 7668 7449 15 CA PO DMY RK 0 08/29/00 2 8200 7966 13 CAMCO DMY RK 0 05/21/92 1 8305 8068 14 CAMCO DMY RK 0 06/16/01 8371' I— 4-1/7' SWS NIP, 0 = 3 813" Minimum ID = 2.387" @ 8930' 3-3/16" X 2-7/8" X0 . .. 1 8438' — BKR LOC SEA L ASSY, 0 = 3 875" I 8440' —19-5/8" X 4-1/2" BKR 'DB' PKR, ID = 4750 ■ •:' : 1 8445' — BKR SEAL BORE EATENSION, ID = 4,750" 1 I 8453' —1 T' MIL LOUT EXTENSON, ID = 6 00" 1 8460' 1-17" X 4-1/2" X0. ID = 3.958" 1 8488' H4 1/2" SWS NIP, ID = 3 813" 3-112" X 3-3/16" X 2-718" LNR TOP — 8509' 1 8509' --I BKR LNR DEROY SLV w /GS PROF. ID = 3.00" 1 TOP OF 7" LNR 1— 8541' I III f--I 8541' — 9-5/8" X 7" BOT LTF', ID = ? 1 1 3-1/2" LNR, 9.3#, L-80 0087 bpf, 0 = 2 992" 1--1 8650' I [ 8550' I---1i2" X 3-3/16" X0. 0 = 2 786"1 } 8582' 1— 4-112" SWN NIP - MILLED TO 3.80" (12/17/00) 1 4-1/2" TBG, 12.6*. 13CR-80, TDS. H 8594' 1 —1 8594' — 4-1/7' WLEG, ID = 3958' .0152 bpf, ID = 3 958" 1 8813' —I ELMD TT - LOGGED 08/17,95 • I 8779' — 7" MARKER JOINT 1 1 9-5/8" CSG, 47#, L-80 BUTT ID = 8.681" 1— 8800' I A Ilk 7" WHPSTOCK (12/09/00) 1— 8848' MILLOUT IMNDOW (I3-29A) 8851' - 8867' . RA TAG (12/09/00) 1-1 8858' PF_RFORATION SUMMARY REF LOG: INTEQ NAND/GR ON 02/03/01 8930' 3-3/16" X 2-7/8" XO, ID= 2.387" •••••••• ANGLE AT TOP FERF 86° ..t.• 10370' 1*******1 I • • • • • # • • • • • • * * * I ■tite: Refer to Production DB for histor 10432' GTM -2 FISH: CIBP PILLED ical perf dat ******** FU 144444441 SIZE SF INTERVAL , Opn/Sqz DATE (05/27/12) 144444441 2" 6 8934 - 8984 S 07/03/01 44,44044 144.44441 2' 6 9290 - 9300 S 05/22/12 ******** PBTD 10,464' 2' 6 9418 - 9428 S 05/22/12 2" 6 10370 - 10450 0 02/11/01 3-3/16" LNR, 6.2/S, — 8930' L-80, .0076 bpf, I 7" LNR, 29#. L-80 BTRS, 0371 bpf, ID = 6 184" H 9500 ID = 2 80" ' F7/8" LNR, 6 5#, L-80 STL. .0058 bpf , 0 = 2.441" Tf 10,500n DATE REV BY COPAMENTS DATE REV BY COMIVENTS PRLO-IOE BAY UNIT 01128186 ORIGINAL COMPLETION 10/16/06 JRPTTLH GLV C/0 WELL 8-29A 05125/92 AUDI 92 Faivo 05/31/08 ' DRS/PJC SFTY NOTE/ MN ID CORRECTION PERMIT Nia. 200-209 02111/01 AWE) 94 C.T. SIDE TRACK ("B-29A") 05/30/12 HF/JMD CMT SQZ, MLL CIBP (05/22-27112) API No 50-029-21523-01 04/29101 CH/TP CORRECTIONS 05/30/12 MSS/JNIJ GLV C/0 (05/28/12) Sec. 31, T11N, R14E 07/13/01 JLJ/KAK P1JLL PKR/SQZ PERFS 06/18/12 JIM PERF BOX CORRECTIONS 08/03/01 DM/TP REMOVE CIBP BP Exploration (Alaska) • SItAll[E SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Laurie Derrick Petroleum Engineer BP Exploration (Alaska), Inc. Q‘,©0 - P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B -29A Sundry Number: 311 -362 Dear Mr. Derrick: 7 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, oh, . or • issio - er DATED this day of November, 2011. Encl. • ' 4FCF!VD E OF ALASKA ALASKA OIL AND GCS CONSERVATION COMMISSION \ _,21 de APPLICATION FOR SUNDRY APPROVALS ' NOV 1 0 2. 0 1// // 20 AAC 25.280 4� 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Ai j AOF M F ' !Qn Suspend ❑ Plug Perforations ❑ PerforateD Pull Tubing p GM A� nsion ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ stimulateD Alter Casing ❑ Other: SQUEEZE Ei ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Ei _ Exploratory ❑ 200 -2090 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21523 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU B -29A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028310 PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10503 - 9033.57 • 10464 9033.87 NONE 10450 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 38 118 38 118 Surface 2647' 13 -3/8" 72# L -80 36 2683 36 2683 4930 2270 Production 8765' 9 -5/8" 47# L -80 35 8800 35 8546 6870 4760 Liner 310' 7" 29# L -80 8541 8851 8298 8595 8160 7020 Liner 1990' 3- 1/2 "X3- 3/16 "X2 -7/8" 8508 10498 8265 9034 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 34 8440 - - 4 -1/2" 12.6# 13Cr80 8440 8594 Packers and SSSV Tvoe: 4 -1/2" Baker D Packer Packers and SSSV MD and TVD (ft): 8440 8199 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 151 , Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/28/2011 Oil 0 - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Laurie Derrick Printed Name Laurie Derrick Title PE Signature Phone Date s..... , 564 -5952 11/14/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY jt� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1 + 5'�'P Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: Ar 0 � AP PROVED BY Approved by: •MMISSIONER THE COMMISSION Date: /��l? RBDMS NOY 1 /i 7.,, O R I G I N A L a/�0 Form 10 -403 Revised 1/2010 Submit in Duplicate B -29A 200 -209 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base B -29A 2/11/01 PER 10,370. 10,450. 9,033.5 9,034.23 B -29A 4/15/01 PER 9,290. 9,300. 8,775.96 8,778.07 B -29A 4/15/01 PER 9,418. 9,428. 8,809.07 8,811.88 B -29A 4/16/01 PER 8,934. 8,964. 8,669.24 8,691.93 B -29A 4/16/01 PER 8,964. 8,984. 8,691.93 8,705.36 B -29A 6/24/01 BPS 9,000. 9,010. 8,714.93 8,720.34 B -29A 7/4/01 SQZ 8,964. 9,000. 8,691.93 8,714.93 B -29A 7/24/01 BPP 9,000. 9,010. 8,714.93 8,720.34 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 • B -29A CT GSO with OrganoSEAL and SqueezeCRETE To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead Date: September 26, 2011 Code: APBBPDWL29 -N From: Laurie Derrick/Lea Duong IOR: 200 B Pad Engineer /Petroleum Engineer Est. Cost: $550,000 Subject: B -29A GSO with OrganoSEAL and SqueezeCRETE Reviewed by (D &C Personnel): Matt Brown, Josiah Igwe on 11/11/11 B -29A is a high gas, high pressure well. It is advisable to use caution on this intervention. Please perform the following procedure: 1. F MIT -IA to 2000 -psi. 2. S D &T (as deep as possible). Obtain SBHP. 3. C D &T liner to TD. Liner Caliper, PPROF /GHOST. MCNL with spinner/ temp warmback passes, PITS. 4. CP Acidize. Memory GR /CCL. Set composite bridge plug. Gel and cement squeeze. 5. FP WOC 5 Days. Pressure test tubing at 1000 psi, establish LLR if fails to hold pressure. 6. SP Install generic GL design (pending passing MIT -IA). 7. FP Pump 20 bbls 60/40 methanol down IA taking returns down flowline for hydrate prevention 8. OP Underbalance well with gas lift, taking returns down flowline 9. OP Inflow test squeeze 10. CP Mill and push composite bridge plug to bottom. 11. TP ASRC flowback (to monitor gel returns) Current Status: Shut -in Operable, 2800 -psi SITP, GLVs dummied Last Test: 01/15/2010 399 BOPD; 4 BWPD; 28.4 MMSCFD; 70,973 GOR; WC 1% Max Deviation: 92° @ 10,450' Minimum ID: 2.387" @ 8,930 MD (3 3/16" x 2 7/8" XO) Last Downhole Op: 10/08/08 S: SBHP survey. Drifted to deviation at 9051' slm with 2.25" cent Last TD Tag 07/24/01 CIBP pushed down with Coil, RIH with w/ 2.25" Junk Mill to 10,450' — Hard Bottom. Latest H Value: 11/14/2000 10 ppm Last SBHPs 10/08/08 3,264 psi @ 210 °F — 188 SI Days Program Objectives: Page 1 of 14 B -29A CT GSO with and SqueezeCRETE • The objective of this procedure is to shut off the —70' of zone 4 gas producing perforations in the heel of the well, while preserving the set of 25P perforations toward the toe of the well. The well has 3- 3/16" x 2 -7/8" L -80 liner. There is currently a CIBP pushed to 10,450' on 7/24/01. Well History: Well B -29A was sidetracked with coil in February 2001 and completed in the 25P. Initial production was —600 bopd but declined rapidly and within 2 months was —100 bopd. An SCMT was run and verified good quality cement bond across the entire CTD liner from TD up into the Shublik. After verifying the liner cement, Z4 perfs were added in April 2001. They brought in 800 bopd and 40 mmscfd and the well hit MGOR. A Baker KB Liner - Top-Pkr was run but did not shut off much gas if any and may actually have been set too high, according to the AWGRS job report. A PPROF was run after the KB PKR was run. It showed 80% flow from the top interval (8964 -8984' md, 46P) most likely all gas. The next 2 intervals (43P, 42P) were producing and may be competitive. There was no sign that the lowest interval was flowing, but the well was choked back to >3350 psi flowing pressure at that depth. There is no indication of flow from the liner lap or liner top. The KB PKR was pulled. A CIBP was set at 9000' and a GSO cement sqz on the upper interval was done July 2001. The 1 sqz did not build pressure and a second batch was pumped. Cement was drilled out and the CIBP was pushed to hard bottom of 10,450'. There was no change in rate and B -29 was left SI for high GOR. The regional GOC in the area is -8737' ss based on the RST logged on 4/28/10 in well B -21. This pick puts the gas contact at the bottom of the 42P in well B -29A, which explains the high gas rate from the Z4 perfs. The Z4 perfs were planned as part of the coiled tubing sidetrack and were an attempt to test oil lenses in Z4, with the knowledge that the GOC had expanded below the interval. When the well was sidetracked in 2001, the OWC was picked at -8842' SS based on the open hole resistivity curves. B -29A was drilled to access the 25P wedge zone in the GDWFI area. At the time when the well was sidetracked, mapping of the northern extent of the GDWFI water influx had indicated that the WF front was over running the 25N shale and bypassed oil was stranded in the 25P. B -29A was drilled to access this oil and confirmed that there is stranded oil in the 25P. However, the well also found a OWC in the bottom of Z3 at -8842' ss. There is large uncertainty around the current POWC and it is one of the greatest risks in this program. Based on production data from offset well B -21, it is assumed that the OWC is in Z3. There is no way to determine whether the 25P wedge has been swept in the past 10 years, but there are potential adperfs in the 31P and lower 41P if we discover that the 25P has watered out. The analog well B -21 is producing from upper 31P and 41P at a rate of 7500 bfpd, 23 mmscfd, 82% WC. Anticipated AAIOR is 200 bopd. Any questions and /or comments, please call Lea Duong at 564 -4840 (w) or 720 - 951 -7238 (c) or Dan Robertson at 564 -5546 (w) or 529 -5818. CC: Well File North Slope Page 2 of 14 • . B -29A CT GSO with OrganoSEAL and SqueezeCRETE B -29A Procedure Coil Procedure: OrganoSEAL: / This procedure includes the use of OrganoSEAL R gel to achieve matrix penetration to a radius of 2'. The gel will be followed immediately with SqueezeCRETE to provide a cement cap at the perforation tunnels to help hold the gel in place. A composite plug is used to isolate the bottom set of perfs during gel and cement placement. SqueezeCrete: Schlumberger's SqueezeCRETE is a microfine cement with more rounded and smaller particle sizes than typical class G cement. SqueezeCRETE has low fluid Toss values, high resistance to dehydration and high stability to free fluid and sedimentation. The objective with using SqueezeCRETE is to attempt to displace cement into the rock matrix as opposed to just filling pert tunnels or building nodes in the liner as is common with class G cement. SqueezeCRETE particles are on the order of 7 microns, while class G typically has 40 -50 micron particles. The pore throat size distribution chart below indicates predominantly 20 micron pore throats for the Ivishak reservoir. The pore throat size to particle size ratio is approximately 3, so some pore throat bridging may occur even with the finer cement, i.e. it is anticipated surface pressure will increase with cement across the perforations, but there is a chance it could be pumped into the matrix. Ideally at least some matrix penetration will be achieved. MACROPORES MICROPORES — 0.008 Figure 78. Example — 0.007 To of trimodal pore -size — 0.008 distribution often 2 seen in Prudhoe Bay CHERT — 0.005 I sandstone. Primary — 0.004 constituents of rock are intergranular KAOLDflTE — 0.003 F pores, microporous rpii chert and Kaolinite. — 0.002 The sample has an ERGRANULAR — 0.001 M average level of PORES permeability and 0 porosity. 100 10 1 0.1 0.01 PORE THROAT DIAMETER MICRONS] Primary constituents of rock Procedure /Risk Discussion • The last coil operation was to push a CIBP down to 10.450' MD. Do not anticipate any problems milling composite bridge plug post cementing. • Reservoir pressure was measured at 3264 psi, 210° F at 8800' tvdss on 10/08/2008 and it is anticipated that 86 bbl of diesel in the ct x tubing annulus will be required to obtain 0 psi WHP; WHP should increase as soon as the treatment begins. This will place diesel to 6900' TVD. Do not displace diesel any deeper Page 3 of 14 • B -29A CT GSO with OrganoSEAL and SqueezeCRETE than this as it may contaminate the gel or cement. Annular capacity of the 1.75" ct x 3.958" ID tubing is 0.0122 bbls/ft. • Ensure that a small ball drop cementing nozzle is available for use prior to job. • Post cementing cleanout: pump rate is likely to be limited to —1.0 bpm through the motor. This should result in an annular velocity of 50 fpm in the 1.75" ct x 4.5" tubing annulus. Pump biozan /flopro sweeps as needed for hole cleaning. Monitor for symptoms of cuttings buildup like pulling increased weight and pull uphole and circulate in the 4.5" tubing as needed to aid in hole cleaning. There should be minimal cement cuttings to remove from the well if all goes as planned. Monitor returns rate to confirm squeeze is holding. Open circulating sub when done milling and circulate bottoms up at max rate prior to /while POOH. • OrganoSEAL R volume is based on 2.0' of radial penetration over 70' of perforations and holes at 20% porosity. A project authorization form is also required for ordering the material. • Total volume inside the 3 -1/2" x 3- 3/16" x 2 -7/8" liner from the liner top to the composite bridge plug (Dependent from PPPROF & Caliper. Last PPROF showed cooling around 10,150' MD). If the plug is set at 10,150' and the liner volume is approximately 10 bbls. If a leak is not present and the plug is set at 9,480' and the liner volume is 6 bbis. Plan to pump 20 bbls of squeezecrete in either case. Fullbore Pre - Squeeze: 1. Confirm DGLVs are installed. 2. Shoot FL and RU pump trucks & fluid as necessary. Load and PT IA to 2000 psi. If it fails, establish LLR. RU to bleed gas off annulus down flowline as needed to ensure IA is loaded to near surface. Rated burst pressure of the 4 -1/2" tubing is 8,430 psi. The maximum tubing pressure throughout this job is 3000 -psi. The length of the seal assembly limits tubing movement to a derated pressure of 6,000 psi, so the 3000 psi maximum provides a 50% safety factor. Slickline Pre - Squeeze: 3. RU SL. D &T as deep as possible for composite plug. OD for plug is 2.18 ". Static pressure survey. Coil Pre - Squeeze Liner drift, PPROF /GHOST, Caliper, and MCNL: 7 4. Contact Pad Operator, WPOE, and PCC to ensure that well is online for at least two days and stable prior to logging operations. Please ensure well is lined up to pad test separator during logging. Desired FTP is 2000 -psi. a. B -29A currently has dummy gas lift valves installed. The SITP on 9/26/2011 was 2800 -psi. This represents a gas gradient in the tubing and it is expected that the well will be able to flow naturally without GL KO. 5. Obtain B -29A oil sample and deliver to Schlumberger Well Services lab for pre -job emulsion /sludge testing at least 5 days prior to acid stim. 6. RU 1.75" service ct. Drift to 10,450' and with a 2.25" nozzle. Run liner caliper from 10450 -8250' md. b. Production data indicates that the interval 10,370' to 10,450' MD may have formed scale in 2001. However, a CIBP was milled with a 2.25" junk mill and pushed to 10,450' and on 7/24/01. The liner was clean at that time and there is no indication that the well has formed additional scale since it has had limited production time since 2001. c. Milling Contingency: If restrictions are encountered during the drift, POOH and PU a 2.25" motor and mill and clean out down to the CIBP at 10,450' MD. Do not mill on the CIBP. Do not spend excessive amounts of time milling at any depth. Run a bladed type mill, either flat bottom, concave, or round nosed; do not run a diamond type mill to avoid sidetracking or further damaging liner. The objective of the liner cleanout is to ensure it is possible to get a composite plug into the liner. Leave well on production while milling to aid in lifting cuttings. After liner is cleaned out to PBTD (CIBP), POOH. After milling is complete, dry drift with mill motor for composite plug. Page 4 of 14 • B -29A CT GSO with OrganoSEAL and SqueezeCRETE PPROF /GHOST 7. PU SLB PPROF logging string — GR /CCUSPINNER/TEMP /PRESS/ X -Y caliper with GHOST tool. RIH with logging tool string to 8,490' MD. If absolutely necessary, SI well or pump a minimum amount of 1% KCI to knock the WHP down so coil can RIH. If KCI is used to knock WHP down, attempt to get well flowing again as soon as possible. 8. It is desired to log at the maximum feasible gas rate without destroying the spinner or logging tools. This is thought to be on the order of 20 -25 MMSCFD. Prior well test data indicates this gas rate at a FWHP around 2000 psi. When well appears to be stable, perform up and down passes at 40, 60, 80 fpm as indicated in the table below. Please note the well testing conditions during logging on the log header. 9. Perform stop counts at the following depths (30- 50' below and above all perf intervals and known leaks): /.%J /s ; G / ; ; ; A "' i% 1ii; FCV /.a.+ ve r r .�/li .� % ; / 1 /i a //. / 1fi / j /� i . e r /; ti: 3 9 # i v , � � ' 2 .. / � � �. a i/ iiir //i... ��i.'�E`, /,:� %i/ i / / /ioi/�.� �ii/.r /.r '4i% /�a/ / e,i/'iorl /r / Flowin • Pass Down /Up 4 8,490 — 10,450 Well Flowing Flowin• Pass Down /U • 60 8,490 — 10,450 Well Flowin• Flowin• Pass Down /Up 80 8,490 — 10,450 Well Flowin• 8,490' 8,600' 8,900' 9,200' 9,350' Stop Counts Stops - 9,500' 10,000' Well Flowing 10,200' 10,300' 10,450' (as close to TD as possible) 10. POOH, keep well flowing while ensuring data is good. If data is good, proceed to MCNL logging. 11. Depth shift log to correlate with tie -in log Schlumberger MCNL Log dated February 10 2001. Log Presentation for PPROF 1. Job Comments - operating steps in sequence, choke changes, production changes noted at test separator, volumes pumped, logging passes made, and basic field interpretation. 2. In the header for each pass, include a summary of the production conditions (choke, pressure, gas, oil and water rates) for that pass. 3. Flowing STP up pass overlay - spinner and temperature data from 40, 60 and 80 fpm dynamic up passes with constant choke. 4. Flowing STP up /down pass overlay. 5. Stop Counts. Page 5 of 14 B -29A CT GSO with OrganoSEAL and SqueezeCRETE MCNL /PITS The MCNL will be used to determine an updated GOC and the PITs survey will be used to assess the quality of the liner cement as well as to plan the final Squeeze -crete curing times. 1. Make up coil tubing with MCNL, spinner, pressure, temp tools. 2. SI well and knock WHP down to RIH. SITP on B -29A is — 2800 -psi. 3. While RIH, fluid pack well with 100 °F fluid. Pump 1.5x wellbore volume down the backside ( -200 bbls to CIBP at —10,450 MD w /out coil in the well). Once well is fluid packed, lower rate to maintain a positive WHP, this should correspond to — 1bpm, adjust pump rate accordingly. a. Note: It is important to use 90 -110° F fluids to aid in designing squeeze -crete job curing times. Report fluid temps while pumping for accurate inputs into the final squeeze cement design. 4. RIH to 8,490' MD and log two MCNL/ spinner, temp passes across interval from 8,490' MD to 10,450' MD at 60 fpm. Confirm BKB TD Depth by Tagging TD. 5. Prepare to log PITS. 6. Log 1 PITS pass from 8,490' MD to TD after SD pumping. PUH to 8,490'MD and park tool. 7. Log down warmback passes at 1, 3 and 5 hours after SD pumping from 8,490'MD to TD. Objective of this is to confirm which intervals most of the injected fluid went into and confirm rate of warm up for gel and cement squeeze job design. 8. Freeze protect well to 2000' as needed if it cannot be put on production immediately. 9. POOH, RD tools after ensuring data are good. / ///,� / / /,� / J a a Ji g 'i//'�f��iJ;�/%i'���iFf �s'r/H`��f"Jl f /% 'JJ,'f �rf� % � J D . � ? .�ee.✓irydi,�J.i'i%�Jr% %/r% �� i ��-3�J/�i�ss�.Ji � / �.ia: �foss J�i.Jy�J�rAr�n/! 1.,12 r��%i:. Z,*,; J f % �/f % � f f �� J �i !�%% J �fJ % Qj *?; rJ .r % %Ji // //� JJo ! %// l .% a 11;a: ` ii f % / /// J% a MCNL Pass (x2) Up 60 fpm 8,490' - Flag Ensure wellbore is fluid •acked Tie in Run UP 60 fpm 8,490' - Flag Last 10 pass. Paint flag at 10,150' MD Pre - Squeeze (Following steps are contingent on logging results in prior steps. Contact Lea Duong at 907 - 564 -4840 work or 720 - 951 -7238 cell): CTU Gas Shut Off 12. Confirm composite bridge plug setting depth with authors prior to starting job. 13. RU 1.75" CT, tanks, associated cement squeeze equipment. Filter all fluids possible to 3 microns. 14. Apply 1500 psi to the inner annulus and monitor/ maintain 1000 -1500 psi throughout job. 15. Fluid pack well by bullhead 1.5 tubing volumes 3% NH4CL at —100° F. Perform step rate test at .5, 1, 2, 3, 4 bpm toward end of liquid packing. Do not exceed 0.62 psi gradient during liquid packing, acidizing or gel placement. 16. RIH with memory GR /CCL and nozzle /drift for composite bridge plug (2.18" OD). RIH and tag cast iron bridge plug at 10,450' MD. Flag pipe as needed for composite bridge plug setting. If possible continue with acidizing with current BHA, if not POOH and lay down logging tools and PU jetting nozzle. 17. When OOH Correlate log to Schlumberger MCNL dated February 10 2001. Page 6 of 14 • • B -29A CT GSO with OrganoSEAL and SqueezeCRETE 18. Pump the following down the CT while reciprocating over the interval 8,934'- 10,450' MD. Objective is to acidize all liner leaks and perforations to ensure they are able to take gel /cement, and that the perfs that will later be produced are also scale free. Pump below frac gradient of 0.62 psi /ft. /Acid Program a. Establish injectivity with 3% NH4CL as needed b. 48 bbl 12% HCL c. 48 bbl 9:1 mud acid d. 300 bbls 3% NH4CI spacer water (to overdisplace acid well back into the formation, pump at least 50 bbls of this down the ct while reciprocating across the perfs 10,370'- 10,450' MD, the remainder can be pumped down the ct x tbg annulus) Check acid additive packages for BHST of 210 °F and 8 -hour protection time for L -80 liner & 13 -Cr tubing. Acceptable acid concentrations +/ -1% for HCI and +/ -0.25% for HF. Fluids should be 90- 110 °F, if possible. 9:1 Mud Acid A264 ACI 6 gal /Mgai A201 Inhibitor Aid 40 gal /Mgai A153 Intensifier 5 Ib /Mgai F103 Flowback Aid 2 gai /Mgai L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgai U067 Mutual Solvent 50 gal /Mgai 12% HCI A264 ACI 6 gal /Mgai A201 Inhibitor Aid 40 gal /Mgai A153 Intensifier 5 Ib /Mgai F103 Flowback Aid 2 gal /Mgai L058 Iron Control 20 gal /Mgai W054 Antiemulsifier 5 gal /Mgai U067 Mutual Solvent 0 gal /Mgai 19. POOH C-`" *20. MU composite plug and run Baker composite bridge plug for 2 -7/8 ", 6.16 # / ft L -80 liner. RIH, tie into flag, correct depth, and set at either 9480' MD or 10150' and pending PPROF results. 21. Perform step rate test at .5, 1, 2 bpm pumping down the backside for comparison with prior injectivity test. Do not exceed 0.62 psi gradient during liquid packing, acidizing or gel placement. 22. POOH. 23. PU ball drop type cementing nozzle. RIH to composite plug. Pump at least 50 bbls of KCI or NH4CL down the ct with the nozzle just above the composite bridge plug to cool the deepest set of perfs. Pump 86 bbls of diesel down backside which will balance the reservoir pressure and result in WHP of 0 -psi. This will place the diesel /water interface at 7100' and or 6,900' TVD. This is based on the last SBHPS 3,264 psi @ 8800'. Do not pump more diesel than this as it may contaminate the gel or cement. Page 7 of 14 B -29A CT GSO with OrganoSEAL and SqueezeCRETE 24. Mix 125 bbls OrganoSEAL -R. Batch mix 20 pumpable bbl SqueezeCRETE to meet the following specifications. OrganoSEAL-R: Volume to pump: 125 bbls Gel thickening time: 5 -6 hrs minimum using BP Temp ramp below Viscosity during pumping: 20 -30 cp Ultimate viscosity: ringing gel Recipe: Fresh water 6% by weight J491 Gelling Agent 0.3% by weight J525 Crosslinker 0.3% by weight J524Crosslinker (adjust as needed based on pre job testing) Note: OrganoSEAL -R can be disposed of as Class 1 Non - Hazardous material. Contact Penny Goodstein, HSE, at 564 -5069 with any questions. SqueezeCRETE: Volume to Pump: 20 bbl total (Have additional 20 bbls on -hand, if a re- squeeze is needed.) Cement Type: SqueezeCRETE Thickening Time: 17 hours using BP ramp below 500 psi compressive strength: 17 hours Ultimate compressive strength: 3700 psi Fluid loss: <15 m1 /30 min, ideally 5 m1/30 min Density: 14 ppg Pv: -50 cp Ty: >51bf /100 ft2 Filter cake: <5 mm Zero free water Recipe: D163 Squeezecrete cement D206 Antifoam D145a Dispersant D173 FLAC (adjust as needed based on pre job testing) Page 8 of 14 B -29A CT GSO with OrganoSEAL and SqueezeCRETE • BP Cement/Gel Testing Schedule (BP ramp): May Adjust Temp Schedule based on pre -job PITS Survey. 120 minute Batch time: 90 degF and 0 -500 psi 30 minute ramp to 135 deg F and 4000 psi 30 minute ramp to 160 deg F and 5600 psi 60 minute dwell at this temp and pressure 30 minute ramp down to 3500 psi and start a 1.5 deg F per minute increase to BHST. Hold until end of test. 25. Catch samples of OrganoSEAL gel and SqueezeCRETE cement for QC testing. Place samples in bath on site at 200° F. Also, transport samples to SWS NS lab for to monitor gel and UCA testing on cement. Line up cementers to the coil. 26. Pump the following down the coil: a) 10 bbl spacer fresh water b) 125 bbls OrganoSEAL R c) 5 bbls spacer fresh water d) 20 bbl SqueezeCRETE cement e) 10 bbl spacer fresh water f) 1 -1/2# biozan 27. Monitor WHP while pumping. Reciprocate across the perforations and possible liner leak 8,934' - 10,150' MD while pumping the gel out the nozzle. 28. The WCTOC if plug is set at 9480' and is 7,290' md. The WCTOC if the plug is set at 10150' and is 7,690' md. Reciprocate above the WCTOC while pumping the cement. Diesel depth is around 7,100' MD. o This is to avoid dragging the cement uphole with the plunger effect of the 1.75" ct in the small liner. The cement will be essentially bullheaded to the perfs. Choke should be closed. o After the last of the cement exits the nozzle and while the water spacer is at the nozzle, pull uphole an additional -300' to ensure the nozzle is well above the top of cement. o After cement is in place in the wellbore it is critical to ensure the wellbore is not underbaianced until after the cement and gel have set up. This is to avoid flowing any cement or gel back into the liner. If WHP increases with cement at perfs: 29. Pressure up to 3000 psi pressure at the perfs in 500 psi increments. Hold each increment for 5 -10 minutes. Hold 3000 psi for 30-45 minutes. 30. Open choke and bleed back to 500 psi. Swap to 1'/2# biozan and drop ball. Chase ball to nozzle then RIH at 1:1 jetting at max CT pressure and clean out to composite bridge plug. 31. Swap to slickwater and jet uphole at 80% running speed and max CT pressure. 32. Take barrel count to ensure 1:1 returns. 33. Slow down across all jewelry. Critical to maintain 500 psi backpressure at all times to keep pressure on the squeeze. Leave at least 1000 psi on the wellbore at rig down while waiting on cement. If WHP does not increase after pumping all cement: 34. Over displace all cement into perforations by -5 bbls. 35. Swap to biozan and clean out to composite bridge plug. POOH at 80 %. Page 9 of 14 1 • B -29A CT GSO with OrganoSEAL and SqueezeCRETE g q Discuss with Lea Duong (907 - 564 -4840 work or 720 - 951 -7238 cell) or Dan Robertson (907- 564 -5546 work or 907 - 529 -5818 cell) whether to resqueeze immediately or wait awhile. 36. If re- squeeze, repeats Steps 13.c. to 15. above. Pump cement only, NO OrganoSEAL, if re- squeeze. 37. POOH. Freeze protect well. RD CT. Leave 1,000 psi on Wellhead. Fullbore Procedure: 38. Pressure test tubing at 1000 psi for 15 minutes with diesel or methanol. Establish liquid leak rate if pressure test fails. Contact program authors with test results to confirm next steps. Slickline and Inflow Test Procedure (only if pressure test passes): 39. Install generic gas lift design with live GLV in top station, orifice in station 6 at 4990' MD (4950' TVD). If the tubing is blown down to this depth the underbalance applied to the formation will be 1250 psi. 40. Pump 20 bbls 60/40 MEOH down IA at 1 -2 bpm, 1000 psi maximum pressure taking returns down flowline. The objective is to prevent hydrates as the well is unloaded. 41. B -29A has fulltime gas lift service. Circulate lift gas down the IA taking returns down the flowline to remove the liquids from the top portion of tubing, above the screened orifice. Follow Arctic lift gas lift start up procedure for unloading well at a safe rate to prevent flow cutting GLVs. 42. Shoot fluid levels down tubing as needed to confirm tubing fluid level and applied underbalance. Target underbalance is 800 -1250 psi. 1250 psi underbalance is applied if the tubing is unloaded to station #6. After tubing is blown down to provide underbalance, close wing valve, allow whp to increase to 1000- 1500 psi due to gas lift pressure, then turn gas lift off. After pressures stabilize, shoot fluid level down tubing and IA to establish static fluid levels. Then bleed pressure off tubing down flowline to -300 psi. Shoot tubing and IA fluid levels again. A rising fluid level in the tubing indicates a failed inflow test. A stationary tubing fluid level indicates a passing inflow test. 43. If inflow test passes, proceed to mill out CIBP with ct. If inflow test fails, contact authors to discuss re- squeeze. 44. After successful pressure test and inflow test proceed to mill out cement. PU 1- 11/16" motor and milling assembly per Baker recommendations. The small diameter motors have relatively low torque, so it will be important to run a non - aggressive or short bladed type mill to avoid unnecessary stalls, something like a 3 -5 bladed flat bottom or concave mill. Do not run a diamond mill. 45. Mill down to bridge plug to ensure the liner is clear of cement to the bridge plug. Do not mill the bridge ,/ plug. Pressure test wellbore at 1000 psi. If a leak rate > 0.25 bpm is established, may want to resqueeze immediately. POOH. Note: The bridge plug has an equalizing feature. If the top 1' of it is milled up, i.e. if the plug is inadvertently partially milled some fluid losses or change in wellhead pressure may occur. 46. After successful pressure test is obtained, mill out composite bridge plug per plug supplier's recommended practice. Push plug remnant as deep as possible, preferably to the CIBP at 10,450' MD. iv ASRC Flowback Procedure: 47. Pop well through portable separator. Monitor for gel returns. After well stabilizes and an absence of gel returns is confirmed, obtain well test and divert to production. a. Expected rates: 900 bfpd, 7.0 mmscfd formation gas, 50% WC Page 10 of 14 • • B -29A CT GSO with OrganoSEAL and SqueezeCRETE WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV B -29A 7/24/2001 CEMENT SQUEEZE JACKSON - MONTGOMERY COST CODE PLUS DAILY WORK NIGHT SUPV 4P1467 MILL CEMENT, FLOW TEST, MILL CIBP UNKNOWN MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.441 " 8930 FT 0 " DS -MOORE CTU #3 DAILY SUMMARY CONTINUED FROM 7/23/01 WSR. REPAIR LEAKS ON INNER REEL HARD LINE. RIH W/2.30" JUNK MILL. MILUPUSH TO 10351.9'. POOH. VENTURI TO 10,370', POOH. CIBP & SAND IN VENTURI. RIH W/ 2.25" JUNK MILL. WORKED /MILLED DOWN TO 10450'- HARD BOTTOM. PUMP 30 BBL BIO ON BTM, CHASE TO 8820', RIH TO 10450', INCREASE AL UP TO 2.3MM, PUMP 70 BBL BIO SWEEP, CHASE TO SURFACE W/ X SLICK KCL. RIG DOWN, GO TO SHOP FOR MAINTENANCE. * * *WEL POP * ** LOG ENTRIES !nit Tbg, IA, OA -> 210 105011 TIME COMMENT 00:01 DS CREW CHANGE. SAFETY MEETING, REVIEW SAFETY ITEMS, SLIPS/TRIPS, SAFETY ISSUES AROUND HARDLINE FITTING REPAIRS, CURRENT JOB STATUS, CHANGES TO RIG -UP /LOCATION FOR THIS TOWER. PROCEED W/ REPAIRS ON INNER REEL FITTINGS. 01:40 PT4500 PSI UP TO REEL VALVE. GOOD. RIH PUMPING MIN RATE. 03:15 CTD= 9000', KICK PUMP UP TO 1.7 BPM. CONTINUE RIH. SAW SOME MOTOR WORK AT 10330'. MILL AHEAD. STALLED @ 10333'.PULLED SOMETHING BACK UP HOLE. RESUMED MILLING AT 10324'. RUN AGAIN, STALL @10332.5' 04:17 MILLING AHEAD, STALLED @10340. PU, SD PUMP, ATTEMPT TO PUSH IT, SET DOWN @ 10340', PULLED HEAVY. GO BACK TO MILLING @ 1.7 BPM, 04:50 WORK TS UP /DOWN. APPEAR TO HAVE A PIECE ABOVE BHA. SI AL. PULLED UP TO 10110'. RIH. SIT DOWN @ 10210'. PU 10', RIH, SI WING.WHP IMMEDIATELY CAME UP TO 1000 PSI, SD PUMP. ATTEMPT TO PUSH DOWN. SITTING DOWN @ 10338'. OPEN WING. 05:08 MOTOR STALL @ 10344.5'. PU, MOTOR STALL @ 10350.1'. SLOW DOWN PUMP TO 1 BPM. SIT DOWN @ 10351.9. PULLED SOME EXTRA WEIGHT UP. POH. 07:33 ON SURFACE, CHANGE TS FOR VENTURI RUN - MU TS, USE BAKER 2.25" CTC, 2 -1/8" DUAL BPV, BOWEN UP -DOWN JARS, HYD DISCO (5/8" BALL DISC), 2.25" VENTURI BASKET - OAL =16.8' 07:50 LPT TO 400, HPT TO 4000 #, GOOD TEST, BLEED PRESSURE - RIH 09:19 BEGIN PUMPING 0.7 BPM TUB =1188, WHP =280, DWN WT 11.6K, DEPTH 870 WT CHECK @ 8500' UP WT =19.5K 10:00 UP RATE TO 1.5BPM, @10,330' TAG @ 10,361', PUSH INTO HARD BOTTOM @ 10366', CLEAN PU. PUSH INTO BOTTOM @ 10370', PUMP 11 BBLS BIO AND CHASE TO SURFACE - 13:00 AT SURFACE - VENTURI CONTAINED BRASS PIECES, FORMATION SAND, CEMENT & RUBBER PIECES - RIH W /SMALLER MILL. 14:00 MU BAKER TS: CC, CKS, JARS, HYD DIS (5/8" BALL), CIRC SUB (1/2" BALL), MOTOR, 2.25" 3 -BLADE JUNK MILL. OVERALL LENGTH = 23.46' 14:22 PT CT; LPT TO 400 #, HPT TO 4000# - GOOD TESTS; BLEED PRESSURE & RIH IA =1020, 0A =0, WHP =190 15:46 WT CHECK @ 7095' 7679 HANGING, UP WT. =15K, WHP =199 16:19 TAG BOTTOM @ 10365.8' CLEAN PU @ 23K. BEGIN MILLING, FREE SPIN 1700PSI. MOTOR WORK @ 10,367'. 17:21 SLOW DOWN PUMP 0.9 BPM. MOTOR STALL @ 10374.2'. PU, MOTOR STALL @10382.3', PU. STACKING WEIGH - PU WEIGHT = 22K. 17:41 EASE DOWN 10388.6', PUMP 0.9 BPM, WHP =213, TUB PRESS= 1026, ROP 36 FPH, MILLING @ 10391.5'. STALLED MOTOR @ 10393.3', PU. PU WEIGHT IS 30K - PULL TO 10,300. PU WEIGHT BACK TO 23K. 17:55 RIH, DWN WT =12K. BITE @ 10383', BITE @ 10399.5'. STALLED AT 10415' PU AND EASE DOWN. STALLED AT 10450'. 18:15 PUMP 30 BBL SLUG OF BIO FOR CLEANOUT 18:30 CHANGEOUT AND PJSM (DS- ATWOOD, 2 DS, DOUG - BAKER, 1 -BP), MUSTER AREA, JOB SCOPE, WATCH TANKERS & CARS ON PAD, BE AWARE. 18:58 30 BBLS BIO OUT NOZZLE, CHASE UP FROM 10450' W/X SLICK AT 80 FPM TO 8820' (INTO 3 3/16" LINER). PUMP BACK TO TD. INCREASE AL BY 1 MM. SWAP TO BIO @ 9424'. HARD BTM@ 10450. SIT ON BTM AND PUMP 70 BBL BIO. SWITCH TO X SLICK. 20:42 BIO CLEAR OF NOZZLE, PULL UP HOLE PUMPING X SLICK, CHASING TO SURFACE@ <80 %. 22:08 ON SURFACE. BEGIN RIG DOWN. LEAVING WELL FLOWING ON 2.3MM AL. 23:59 RIG DOWN COMPLETE. GO TO SHOP FOR MAINTENANCE. Page 11 of 14 B -29A CT GSO with OrganoSEAL and SqueezeCRETE i Final Tbg, IA, OA -> 260 1500 j o J JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL BAKER THRU TUBING $30,076 $36,761 BP $1,800 $12,600 DOWELL $16,310 $125,545 HOT WATER PLANT $3,010 $13,714 VECO $5,500 $47,500 UNKNOWN $0 $110 BAKER OIL TOOLS $0 $3,004 HBR $0 $5,600 PEAK $0 $750 1 SCHLUMBERGER $0 $13,055 HALLIBURTON $0 $16,198 WAREHOUSE $0 $6,458 LITTLE RED $0 $613 TOTAL FIELD ESTIMATE: $56,696 $281,907 FLUID SUMMARY 850 BBLS 2 %KCL W/ X SLICK 120 BBLS 2 %KCL W/ 1.5 PPG BIO SAFETY NOTES WELL LIFTING W/ 2.3 MM AL, 100 DEGREE WH TEMP, UNLOAD TO CLEAN UP. Tie -In Log: Schlumberger MCNL; February 10, 2001 I CH FILE COPY 111•111111111■1111■Norrown.... '...1/110 COMPENSATE() NEUTRON LOG MEMORY CNL /GR /CCL Schlumberger 10 FEBRUARY 20011 Company BP Exploration (Alaska) Inc. , W Well B -29A FINAL ft Field Prudhoe Bay Unit Borough North Slope State Alaska a Location: SEC 31, TWP III, RGE. ME Other Services rl I � v..� Surface: 399 S1S WU. Noe & i892 Permanent Datum Mt. Elevation 0 FT Elev.. KB. 81.9 FT Log Measured from RKa 81.9 FL Above Datum D.F. 80.9 FT Drilling Meas. from MB G.L. 42.85 F Dote i m nefliaan 2001 _ 'Dirt in r Prof labrsW Run No 1 tlnr Denotes Shorts From To Fupe Log E HMSO) t Prat Reedln0 WOO FA &MI6 FT , PYi. Deviatitel '30.0 t 110500 FT 1?MTnte Reecrlect 10464 Fl _ . Bottom Driller I .... _... /tR`,,451 It I Well tread Pressure } a 6r Type w f Kid Level ! SURFACE and Size Truck No 2123 CASMM6 RECORD Site - Inform Wro lrt °141I From To Recorded By Rgeert a 50 MN 9 3 L01FT 1 8508 FT 593o FT Witnessed Sy Aral lurk 2alss IN -.s Lain 593o n 10498 FT COLLAR LOCATION OTHER SERVICES Lasing Totin g I service 1 Tape « Size Depth Page 12 of 14 f . • B -29A CT GSO with OrganoSEAL and SqueezeCRETE BP,Exploration t: i' Short Well Name: B -29A t,R I 460- _W Name ORILLPAO 8 NO 29A Operator BPX it 3 L RUN DATE: 23- May -2001 Drilled Depth. 10503' Spud Date 2001 -01 -21 00 00:00 K Coordinate :663733 Measurement Ref KB Y Coordinate 5950245 Ref. Elevation 81.9 Depth Range - 20' -20 _ayout Name Ijl hari7nntat NA. Vertical Scale 1 1900 WORD ICL i_- POPM e _ a DEPTH TVQ EWP T. T y.-la 0 In `./_f FEET SS PE Info Perf$ - GRMM Borehole Profile EVVR 0 Apt zto :ono TSGR — 8850 I TSHA = 1 890 TSHC — A. 46P } — 8950 se a a . ..R4: 1 54 1 1 4 -g++r E. 4wt4ag:.0000 o9 n T Q T 3 t . '1 .oi : 4:,GMq ocaxc'pn 4 •8620 .1> �[i.[ ..�.+ wlglt 1 �0 7 9000 -8630 u -8840 .-10 .. 14- +11&7104ParMupr E0ag2cc0000'g� — 45P a .,_ -8650 `` 5_ — ^�_ -- 9050 -8660 S. — 9100 -8670 44P --T - Z Y -- 8150 45SB �,.. -- 9200 -3680 a 9230 43P 1 - -8690 0300 y 0 e8. 0 00 t5-09r -501 P 550ag :.CaXCOrgun d --. - 8700 — — — 9350 _8710 PGOC 42P — 8400 -8720 - 8737'ss - „� _ -8730 �- 0s 801 --0 tr -.p,- O1 Pelr , n14. , rgtn 9450` -8740 41P — 9500 _8750 Potential oil — 9556 8760 column 40'TVDss — 9600 Future across 320'md 4258 = —,.=-___=__________— — 0650 , APF -, . 8770 i _ - �a.�_ -�� 9700 9750 31P Z= � -- _ — 9800 8790 Set CIBP at 9480'md or 10150'md based ■ Potential water .-_ 9650 influx based on — 9900 -8790 on PPROF offset prod data — 9950 -8300 OWC - 8777'ss 8810 – 10000 :8888 Logged - ti� TCGL 8950 — – 10050 -8850 OWC -- 0. I - 3 C.. _ _ , � - -c � - .__�.s _8960 4, "'��e — — 10100 -88:70 - 8848'ss 77P l -8880 — 18150 -8900 ® y y -8910 BCGL — — 10200 -6920 26P — 10850 -8930 10300 4 -8940 25N — 10350 -8950 � 23SB fi % 10400 0Y0 ]EO Fr 60 C t.n 1 Peeldil F0489' ..•. 841 25P V _ 10450 — I -- - 10500 Page 13 of 14 • • B-29A CT GSO with OrganoSEAL and SqueezeCRETE III TREE = 4-1/16* CM I SAFETY NOTES: WELL ANGLE > Ms@ 10221' WELLHEAD= MCEVOY ' ACTUATOR = BAKER B -2 9 A c .E TOG"' KB. ELEV = 81.9' BF. asi = 43.95 I KOP= 4230' Max Angie = 92' 6 10450' 2130' H4-1/2" ORS 1-1X0 SSSV NP, ID= 3.813' I Celia' 1:46. ' ' ' iiiiii' ri GAS (JET FANS . .. _ -. .... . . _ ...... .. Datim TV() = 88W SS [ ST AO TVD oat TYPE VLV LATCH Farr DATE , 7 301 7 3017 1 CAMCO LIMY FE 0 10/16/06 20' CONDUCTOR, ID =? 110' 6 499 0 4950 21 CAMCO DMY FE 0 1016/06 Ar I 13-3 CSG, 720,1-80 BTRS, CI= 12.34 7' H 2853' W 5 626 3 6125 23 CAMCO DIA' FE 0 4 7103 6910 19 CAMCO CMY RK 0 3 766 8 7449 15 CAMCO MY Flit 0 2 8200 7966 13 CAMCO CMY PIK 0 1 8305 8068 14 CAMCO CMY Fat 0 8371' H4-1/2. SWS NIP, ID= 3.813" 1 ' Minimum ID =2.387" @ 8930' - I 8438' H8KR LOC SEAL ASSY , ID = 3.875' I 3-3/16" X 2-7/8" X0 8440' F19-5/8' X 4-1/2' BKR1DB" MR, 0 = 4.750' I II PT. ...■ . 8445' FIIIKR SEAL BOREEXTB4SION, ID = 4.750' I ----- 8453' HI" IALLOUT EVENSON, 0 = 6.00' I -------- 8460 1 X 4-1/2' XO, C = 3.958' I 8488 H4 1/2" SWS NIP, 0.3.8ir I 3-1/2' X 3-3/16' X 2-7/8' I.NR TOP 8509' I IP BKRLNRCIEFLar sty woos FROf, C =3.00' ITCP OF r Utli H 8541' 8541' H9-6/8" X 7' BOY LIP, CI =? I 3-1/2' LW., 9.30, 1-80, .0087 CO, 13=2.992' ...,M 11 . M. , r NI -13-1/2' X 3-3116* X0, 0 = 2.7 86' I 8582 H4-1/7 SWN NIP - MLLE) T03.80' (12.17/00) I 4-1/2' TBG, 12.60, 13CR-80, MS, .0152 bpf ID= 3.958' 1-1 8594' 8594' H4-1/2" WLEG, 0 = 3.958' I , I 8613" H Euoorr - Loom:loan vos I 41---1 8779' I-1 r IARKER ,orir I 9-58' CSC, 4 71,1-80 BUTT, 0= 8.681' I-1 8800 ir WHFSTOC( (12/0800) 8848' I MUCCI W WIDOW CB-29M 8851' - 8B6T' I IPA TAG (1209/00) I 8858 PERFORATON SUMARY REF LOG: HIE° MWOCR CN 02/03/01 109fetrti 8930' 3-3/16' X 2-7/8' X0, 0= 2.387' I ANGLE AT TOPPERP. 78 @ 9230' fit....• 01.4141/1 10.14.1. Note: Refer to Producton ( B for netorca peri data 001.44•1 1 ? Co Odd 1.04.1001 SIZE SPF INTERVAL Ore/Srp GATE ■1114.0•114141 441..6.1 \ FWD 0,484' 2' 6 8934 - 8984 S 07,03/01 #41-014440 •••••••• % 2' 6 9290 - 9303 0 04/15;01 lte.t.111 b.f....MA.4.4 Nit 2' 6 9418 - 9428 0 04/15/01 2" 6 10370- 10450 0 02/11/01 3-116' LM, 6.20, -I 8930' I Nip L-80, D376 bpi, } 4111 1) = 280" I r LNR, Al, L-80 BTRS, .0371 bpi, 0= 6.184' -I 9500' Cjffe i 2-7,8' LNR, 6.50, L-80 STL, .0358 bpf, ID = 2441' m 10,500' DATE REV BY COMMENTS DATE REV BY CONWENTS I PRUDHOE BAY UNIT 0112886 ORIGINAL COMPLETION 10/1806 JRPPILH GLV CI) WEIL. B-29A 0525*2 AUDI 02 RWO 05/31.08 DRSPJC SHY NOTB MN ID CORRECTION PERMIT No. 200-203 0211111 AUTO 14 C.T. SIDETRACK fE1-29A1 AP No 50-029-21623-01 042901 O-kTP OCRRELTONS Sec. 31, T11N, Ri4E 07/1 101 Jt-MAK PILL PKRGQZ PEWS 08034)1 DMITF REMDVE CEP BP Exploration (Alaska) Page 14 of 14 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, ~a~ ~~~~ DE(; ~ 2~1Ci9 Ala~s~ta ~3i1 ~~ LOrls, ~plTlfl1ssior~ A~n~r~o~~~~ aoa- a~q ~- a9A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B 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, at 659-5102. 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) Date: 12/11/09 Well Name PTD # API # Initial to of cement Vol. of cement um d Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-058 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to Iasi NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1:70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1,70 8/20/2009 8-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA · . WELL LOG TRANSMITTAL REC:E:I\/E:[) ProActive Diagnostic Services, Inc. AUG 2 9 2006 Alaska Oil & Gas Cons. Commission Anchor<1ge To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and lor Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 ) EDE Disk B - 29A 2) 3) 4) 5) 6) 7) 26-Jul-06 Depth Determination ~çANNeD AUG 3 02005 Print Name: c~ D /L Qt\(·:1)~\J.?! Çnn-íA 1,1 k-01 Date: ?f/éJq!OG Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGElâ!MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM 800 -e éP¡ ¡¡t 1'-1 D (f Õ C:\Documents and SeningsIPDS Anchorage - MPL\DesktoplTransmit_Original.doc F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Permit to Drill 2002090 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT B-29A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21523-01-00 MD 10503 J TVD 9034 Completion Dat 2/1112001 j Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Sample N_go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Med~a Fmt Name c R L D 'L ~L R (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH I Start Stop CH 8830 9630 Open Dataset Received Number ~,Comment~ 3/20/2001 09978e..~'830-9630 9956 FINAL ~ 2 FINAL Directional Survey ~//~ ~ FINAL Directional Survey FINAL Directional Survey FINAL Directional Survey FINAL ~Mapping 5 FINAL 8500 Tool c.MD GPJRES 2/5 FINAL 9623 ~'~GPJRES 2 FINAL 9623 9990 FINAL 8835 LIS Verification FINAL ~on Profile~ ~15 ~)'~ FINAL 8400 9978 FINAL 8830 GR 2 FINAL 8870 "I~GR 5 FINAL 8870 LIS Verification FINAL 8830 8835 10454 Case 4/1212001 8406 10460 Case 3/16/2001 8406 10460 ch 3/16/2001 8406 10460 ch 3/16/2001 ch 3/712001 ch 10400 ch 10503 oh 10503 oh 10454 1O4O0 CH 9630 oh 9623 oh 9623 oh 9630 3/7/2001 4/5/2001 41512001 5/15/2001 4/1212001 4/12/2001 4/12/2001 4/1212001 611512001 3/20/2001 3/2012001 3/20/2001 3/20/2001 09990 ~I~35'~0454 o995s -1o46o 9956 ~-~1'06-10460 Digital Data 8406-10460 BL, Sepia Directional Survey Digital Data Directional Survey Paper Copy Directional Survey Paper Copy Directional Survey Digital Data 8500-10400 Color Print 9623-10503 BL, Sepia 9623-10503 BL, Sepia 9990 ~8~35-10454 Digital Data LIS Verification Paper Copy 8400-10400 BL, Sepia 9978 ~/8830-9630 Digital Data 8870-9623 BL, Sepia 8870-9623 BL, Sepia 8830-9630 Paper Copy Well Cores/Samples Information: Permit to Drill MD 10503 Name 2002090 TVD DATA SUBMITTAL COMPLIANCE REPORT 4/112003 Well Name/No. PRUDHOE BAY UNIT B-29A Operator BP EXPLORATION (ALASKA) INC 9034 Completion Dat 2/11/2001 Completion Statu 1-OIL Current Status 1-OIL Interval Start Stop Sent Received Dataset Number Comments APl No. 50-029-21523-01-00 UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis ~ Rece. ived? Daily History Received? ~/N Formation Tops i~)/N Comments: Compliance Reviewed By: Date: (' Transmittal Form Baker Atlas BAKER - HUGHES Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: BP Amoco C-37APB1 Pmdhoe Bay Unit North SloPe'~Oi. 10 BP Amoco C-37APB2 P;lll;dhoe Bay Unit North Slope.,)y - "' BP Exploration, Inc. 05-;~[A Pmdho~i~ig....y.:,~,Unit BP Exploration Alaska B-29APB 1 P~hoe Bay Unit~o3~o ARCO Alaska Inc. 15-20APB 1 Pmdhoe BayiliUnit Contains the following For Each Of The Abov~ Wells: I LAS Format disk 'i 2 - Films !-.-- Meas...~¢d Depth M-~ ~!i~ri_'nt :. : z f .~L~.~ ¢~1 ~[i .:r:': --: ; ; ' '= : ;-- . r ~r~}[j ~ ~ ~ ~{~ -- - Sent By: Josef Berg Received By:~~, ' I l~ ii Ill _ l.~_- [~ ~..~ ..... . ...... _l~ ..... 1 l, ~l--~ll PLEASE ACKNOWLEDGE RECEIPT BY-SIGNING & RET~G OR FAXING YOUR COPY FAX: (403) 53%3767 Baker Atlas #1300, 401-9t~ Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ CIBP, CMT SQZ, Clean Out Pu, tubing _ Alter casing _ Repair well _X Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service_ 4. Location of well at surface 399' FNL, 1892' FEL, Sec. 31, T11 N, R14E, UM (asp's 663733, 5950245) At top of productive interval 2523' FNL, 1720' FEL, SEC 31, T11 N, R14E, UM (asp's 663959, 5948125) At effective depth 2449' FNL, 1678' FEL, Sec. 31, T11N, R14E, UM (asp's 663999. 5948199) At total depth 2398' FNL, 1663' FEL, SEC 31, T11 N, R14E, UM (asp's 664012, 5948251) 12. Present well condition summary Total depth: measured true vertical 10503 feet Plugs (measured) 9034 feet 6. Datum elevation (DF or KB feet) RKB 81.9 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-29A 9.~pproval number 10. APl number 50-029-21523-01 11. Field / Pool Prudhoe Bay Oil Pool Tagged PBTD @ 10450' MD on 07/24/2001. Effective depth: measured 10450 feet Junk (measured) true vertical 9034 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" x 30" 72 c.f. concrete 110' 110' Surface 2602' 13-3/8" 3255 c.f. PFE & 465 c.f PF 2684' 2684' Production 8718' 9-5/8" 1760 c.f. Class 'G' 8800' 8546' Liner 310' 7" 340 c.f. Class 'G' 8851' 8595' Sidetrack Liner 1995' 3-3/16" / 2-7/8" 188 c.f. 15.8 ppg LARC 10503' 9034' Perforation depth: measured Open Perfs 9290' - 9300'; 9418' - 9428'; 10370' - 10450'. Leaking Sqzd Perfs 8934'- 8984' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) true vertical Open Perfs 8776'-8778'; 8809'-8812'; 9033.5'- 9034'. S~'P ~, 4 20~r)t Leaking Sqzd Perfs 8934'- 8984' 4-1/2", 12.6#, L-80 Tbg @ 8594' MD. Alaska Oil & Gas Cons. Commissi(.,n Anchorage 9-5/8" X 4-1/2" Baker D Packer @ 8840' MD; Liner Top Packer @ 8480.5' CTM. 4-1/2" Otis Landing Nipple SSSV @ 2130' MD. 13, Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 04/19/01 225 10591 4 - 2438 Shut in due to high GOR 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _X 16. Status of well classification as: Oil ~X Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . Signed , .~,,,~~ Title: B Pad Surveillance Engineer R. Andy Parker " ~ Form 10-404 Rev 06/15/88 · ORIGINAL Date September 10, 2001 Prepared by DeWayne R. Schnorr 564.5174 SUBMIT IN DUPLICATE ~ B-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/16/2001 06/17/2001 06/18/2001 06/24/2001 06/25/2001 O7/O222OO1 07/03/2001 07/04/2001 07/06/2001 07/15/2001 07/21/2001 07/2222001 07/23/2001 07/24/2001 06/16/01 06/17/01 06/18/01 06/24/01 06/25/01 07/02201 CEMENT SQUEEZE: DRIFT & TAG, DMY OFF GLM'S 7,6,4,1. CEMENT SQUEEZE: DUMMY OFF GLM'S 7,6,4,1, PULL 4.5" XX PLUG. CEMENT SQUEEZE: DUMMY OF GLV #1, PRESSURE TEST INNER, PULL 4.5" PLUG. CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: CEMENT SQUEEZE: INJECTIVlTY TEST. SET CI BRIDGE PLUG PULL LINER TOP PKR/CEMENT SQUEEZE CONTINUED-PULL PKR/CEMENT SQUEEZE CEMENT SQUEEZE INJECTIVlTY TEST DRIFT RUN, SET GENERIC GL DESIGN MILL CEMENT, FLOW TEST, MILL CIBP MILL CEMENT, FLOW TEST, MILL CIBP MILL CEMENT, FLOW TEST, MILL CIBP MILL CEMENT, FLOW TEST, MILL CIBP EVENT SUMMARY DRIFT TBG W/2.25" CENT TO 9080' WLM / SET 4 1/2" CATCHER SUB ONTOP OF SEAL ASSY. @ 8484 / PULL S/O GLV FROM STA.# 1 @ 8314' WLM / PULL LGLV FROM STA.# 4 @ 7110' WLM PULL LGLV'S FROM STA.# 7 & 6, SET DUMMY GLV'S IN STA.# 7, 6, 4 / PULL CATCHER, SET XX- PLUG IN X- NIPPLE @ 8371' WLMD. RIGGED UP PUMP CREW TO TBG AND PUMPED 625 BBLS. OF DEAD CRUDE / SET DUMMY GLV IN STA.# 1 / PRESSURE TEST INNER TO 2500 PSI. FOR TUBING INTEGRITY TEST, EQUALIZE 4.5" XX PLUG PULL 4.5" XX-PLUG @ 8317' WLM. RDMO. INJECTIVITY TEST. PUMPED 225 BBLS @ 5 BPM @ 460 PSI. SET CIBP. RIH TO 9076' (TD), LOG TIE IN PASS, LOGGED INTO POS. & SET 2 7/8" CIBP @ 9000', POOH RDMO, NOTIFY DSO OF STATUS AND WELLSITE CONDITION, LEFT WELL SI. MIRU CTU#8. MAKE UP BAKER FISHING STRING FOR BK PKR., LOAD & KILL WELL, RIH, INJECTIVlTY TEST 2.5BPM @ 300PSI; LATCH FISH. @ 8477', JAR TWICE, POOH W/KB LNR PACKER; POST INJ TEST @ 6824'; 2.5 BPM @ 450 PSI DIESEL FOR THIS INJ TEST- PUMP 27.5 BBL OF 15.8 PPG LARC CEMENT. COULD NOT GET SQUEEZE PRESSURE. CONTAMINATE AND JET (3 PASSES) W/SLICK FROM 8000'- 9000'. WAIT FOR MORE CEMENT. Page 1 07/03/01 07/04/01 07/06/01 07/15/01 07/21/01 07/22/01 07/23/01 B-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS WAIT ON 2ND BATCH OF CEMENT. TOP OFF TBG W/DIESEL, COOL PERFS, SQZ 26BBLS, CO W/BIO & KCL, SYSTEM STILL BLEEDING OFF. WAIT ON 3RD BATCH CEMENT. PUMP 31.4 BBLS CEMENT. LAY IN, PUH TO SAFETY, BUMP AND WAIT FOR 3 HOURS. WORKED PRESSURE UP TO 1825, WELL WENT ON INJECTION @ .4 BPM. BLEED WHP TO 200, CONTAMINATE FROM 7000' TO BTM @ 2:1, JET X SLICK BETWEEN BTM - 7200', TWICE, SPOT 14.5 BBLS TEA @ PERFS, CONTINUE JET OUT OF HOLE @ 80%. MAKE 3 PASSES AT 30 FPM ACROSS ALL GLMS AND SSSV NIPPLE. FP TOP 2000'. RDMO. INJECTIVITY TEST APPX.2.8 GPM @ 1000PSI RIH W/1.90" CENT. TO 8931' WLM -- SET 4.5" WIDDEN CATCHER SUB @ 8430' WLM -- PULL DGLV FROM GLM # 6 @ 4981' WLMD-- PULL DGLV FROM GLM # 7 @ 3001' WLMD -- SET 16/64" 1500 TRO GLV IN GLM # 7 @ 3017' MD -- SET 5/16 OGLV IN GLM # 6 @ 4990' MD -- PULL CATCHER FROM 8430' WLMD. RDMO, RETURN WELL TO OPERATOR MIRU CTU#3, MILL 4-1/2" TUBING TO 8509' W/3.75" BLADE MILL, NO RESTRICTIONS, POOH, MILL REMAINING TUBING FROM 8509-8985' (15' ABOVE ClBP) W/2.3" 3-BLADE JUNK MILL, PUMP 5 BBL BIO SWEEP, CHASE TO SURFACE W/X SLICK @ 80%. MU TEST SEAL TS. PT SYSTEM. RIH. RIH W/3" TEST SEAL TS. LAND TEST SEALS IN DEPLOYMENT SLEEVE. PT BACKSIDE TO 1000 PSI, 4 ATTEMPTS. CHASING SURFACE LEAKS. GREASE ALL VALVES. RE-TEST BACKSIDE, AVG 0.42 GPM LEAK OFF. TEST CT SIDE. AVG 1.68 GPM LEAK OFF. POH. MU MILLING STRING W/2.30" JUNK MILL. RIH, MILL CIBP @ 8988. PUSH 2-7/8" CIBP TO 9786'. TRIP OUT TO CK TS. CHANGE OUT MOTOR/MILL. RIH W/2.30" JUNK MILL. RIH W/NEW MOTOR/2.30" JUNK MILL. TAG FISH. MILL. GOT HUNG ON FISH. GOT FREE. PUMP 20 BBL BIO SWEEP. MILL & PUSH DOWN HOLE TO 9786', POOH, RIH W/VENTURI BASKET, WORK/PUSH ClBP TO 10240', VENTURI FULL OF SLIPS, RUBBER,METAL, RIH W/2ND VENTURI, VAC/PUSH ClBP TO 10313'. POH. RETRIEVED LOWER ClBP BODY IN VENTURI NOZZLE. MU JUNK MILL TS. 07/24/01 REPAIR LEAKS ON INNER REEL HARD LINE. RIH W/2.30" JUNK MILL. MILL/PUSH TO 10351.9'. POOH. VENTURI TO 10,370', POOH. CIBP & SAND IN VENTURI. RIH W/2.25" JUNK MILL. WORKED/MILLED DOWN TO 10450'- HARD BOTTOM. PUMP 30 BBL BIO ON BTM, CHASE TO 8820', RIH TO 10450', INCREASE AL UP TO 2.3MM, PUMP 70 BBL BIO SWEEP, CHASE TO SURFACE W/X SLICK KCL. RIG DOWN. ***WEL POP*** Page 2 B-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/10/01 WELL SHUT-IN. PLAN FORWARD - SET A PATCH ACROSS THE PERFORATIONS THAT ARE PRODUCING GAS. FLUIDS PUMPED 1 PRESSURE TESTING SURFACE PRESSURE EQUIPMENT W/DIESEL 221 DIESEL 625 DEAD CRUDE 225 KCL H20. 805 1% KCL WATER 2050 2% KCL WATER W/X-SLICK - 85.6 CEMENT 25 1% KCL WATER W/1.5 PPG BIOZAN 190 2% KCL WATER W/1.5 PPG BIOZAN 12 TEA 4239.6 TOTAL Page 3 /~" STATE OF ALASKA (~'. ALASK ..,ILAND GAS CONSERVATION C .,MISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address P.O. Box 196612, Anchorage, Alaska 1. Operations performed: r-'] Pull Tubing [] Alter Casing [] Repair Well I~ Other 2. Name of Operator 15. Typep.[~well:. . IZ~ ueve~opmem BP Exploration (Alaska) Inc. I [] Exploratory [] Stratigraphic 99519-6612 [] Service [] Operation Shutdown [] Stimulate [] Plugging [] Perforate CTU Post-Work, Add-Perfs 6. Datum Elevation (DF or KB) KBE = 81.9 feet 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 398' FNL, 1891' FEL, Sec 31, T11N, R14E, UM At top of productive interval 2523' FNL, 1720' FEL, Sec 31, T11N, R14E, UM At effective depth 2494' FNL, 1700' FEL, Sec 31, T11N, R14E, UM At total depth 2398' FNL, 1663' FEL, Sec 31, Tt 1N, R14E, UM (asp's 663733, 5950245) (asp's 663959, 5948125) (asp's 663978, 5948154) (asp's 6640!2, 5948251) 12. Present well condition summary Total depth: measured 10503 feet true vertical 9034 feet Effective depth: measured 10400 feet true vertical 9035 feet 8. Well Number B-29A 9. Permit Number / Approval No. 2OO-2O9 / 10. APl Number 50-029-21523-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay i Pool Plugs (measured) Junk (measured) KOP (window) 8851' - 8867'. 7" liner abandoned from 8851' to 9500'. PBTD @ 10400' (04/13/2001) Casing Length Structural Conductor 110' Surface 2650' Intermediate 8766' Production Liner 310' Sidetrack Liner 1950' Size Cemented 20"X30" 72 c.f. concrete 13-3/8" 3255 c.f. PFE & 465 c.f. PF 9-5/8" 1760 c.f. Class 'G' 7" 340 c.f. Class 'G' 3-3/16"X2-7/8 188 c.f. LARC MD TVD BKB 110' 110' 2684' 2684' 8800' 8546' 8540' - 8851' 8296' -8593' 8550' - 10500' 8306' - 9034' ,, Perforation depth: measured Open Perfs 8934 - 8984, 9290 - 9300, 9418 - 9428, 10370 - 10450 true vertical Open Perfs 8669 - 8705, 8776 - 8778, 8809 - 8812, 9033.5 - 9034 Tubing (size, grade, and measured depth) 4-1/2" L-80 tubing to 8594', 3-1/2 from 8480' to 8550', 3-3/16 from 8550' to 8930'. Packers and SSSV (type and measured depth) 9-5/8" Packer @ 8440', 4-1/2" Baker 'KB' LNR 'PKR @8480' 4-1/2" SSSV (OTIS 'HXO') @ 2130'. 13. Stimulation or cement squeeze Summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure RECEIVED ,,~ 05 2001 Alaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 602 6224 68 SI due to high GOR Casing Pressure Tubing Pressure --- 188 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ScottLaVo,e ..,~~ ~,.!~ Title TechnicalAssistan~ Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Date ~'/.~,/~ / ~ De Wayne ~chnorr 564;51'74.,~,..~ Submit In DUplicate~ B-29A (. DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/16/2001 CTD-POST WORK: 02/19/2001 CTD-POST WORK: 02/21/2001 CTD-POST WORK: 02/22/2001 CTD-POST WORK: 04/05/2001 CTD-POST WORK: 04/13/2001 CTD-POST WORK: 04/14/2001 CTD-POST WORK: 04/15/2001 CTD-POST WORK: 04/16/2001 CTD-POST WORK: 04/18/2001 CTD-POST WORK: 04/20/2001 CTD-POST WORK: EVAL IA PRESSURE ANOMALIES INSTALL GLV DESIGN NEW GLV DESIGN SET GLV DESIGN DRIFT INTO LINER TOP SCMT ADPERF ADPERF ADPERF SET LINER PACKER SET LINER TOP PACKER SUMMARY 02/16/01 MITIA PASSED TO 3000 PSI. 02/19/01 SPOTTED UP AND READY FOR WORK IN AM 02/21/01 SET CATCHER SUB PULLED DGLV'S FROM GLM'S #1, #4, #6, #7 SET NEW GLV'S IN GLM'S #7, #6, #4 WELL LEFT SHUT IN 02/22/01 SET OGLV IN GLM #1 AND PULLED CATCHER SUB RELEASED WELL TO OPERATOR FOR PRODUCTION 04/05/01 DRIFTED PAST LINER TOP WITH 2.25" CENTRALIZER TO 9050' WLM. (TOP OF 2 7/8" LINER @ 8955' CT DEPTH). RDMO. LEFT WELL SHUT IN & NOTIFIED OPERATOR OF STATUS. 04/13/01 SCMT/ADPERF IN PROGRESS. COMPLETED SCMT & PRESS/TEMP SURVEY ACROSS LINER LAP. VERIFIED LEAK @ LINER LAP (8508'). CEMENT LOOKS GOOD. WILL RETURN IN A.M. TO CONTINUE WITH ADPERF. **** TURNED WELL OVER TO OPERATIONS TO POP **** 04/14/01 ATTEMPTED ADPERF, EQUIPMENT PROBLEMS RESULTED IN MISFIRE AND NEED TO REHEAD. MADE REQUIRED REPAIRS; WILL RETURN IN A.M. TO CONTINUE. **** LEFT WELL SHUT-IN AND FP'D **** 04/15/01 ADPERF IN PROGRESS. SHOT TWO 10' INTERVALS (9418'- 9428' & 9290'- 9300') WITH 2" POWERJET, 6 SPF, 60 DEGREE PHASED, RANDOM ORIENTED GUNS. WILL RETURN IN A.M. TO CONTINUE. **** WELL WAS LEFT FLOWING **** 04/16/01 COMPLETED ADPERF'S. SHOT 50' INTERVAL (8934'-8984') WITH TWO 2" POWERJET, 6 SPF, 60 DEGREE PHASED, RANDOM ORIENTED GUNS. **** LEFT WELL FLOWING; REQUESTED WELL TEST **** 04/18/01 WAITING ON WEATHER ... 04/20/01 MIRU, PElt..! ,.)RM BOP TEST. MU KB LINER~'~,' .,KKR, KILL WELL, RIH. STING IN, SET SLIPS, PT BACKSIDE, DISC. TAG PACKER 2' HIGH AT 8480.5' CTMD. POTENTIAL FOR BTM SEALS TO NOT BE DEEP ENOUGH INTO TIE BACK SLEEVE. RECOMMEND POP WELL, TEST, AND IF NEED BE, RELOG. ***LEFT WELL SI AND NOTIFIED PAD OP TO POP*** Fluids Pumped BBLS. Description 3 DIESEL FOR P/T 357 60/40 METHANOL 360 2% KCL 401 1% KCL 1121 TOTAL 04/16/2001 ADD PERFS SUMMARY The following intervals were perforated using 2" POWERJET, 6 SPF, 60 degrees phased, random orientation guns. 8934' - 8964' MD 8964' - 8984' MD 9290'- 9300' MD 9418' - 9428' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (liner top packer) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 399' FNL, 1892' FEL, Sec. 31, T11N, R14E, UM At top of productive interval 2523' FNL, 1720' FEL, SEC 31, T11N, R14E, UM At effective depth At total depth 2398' FNL, 1663' FEL, SEC 31, T11N, R14E, UM 5. Type of Well: Development mX Exploratory__ Stratigraphlc._ Service__ (asp's 663733, 5950245) (asp's 663959, 5948125) (asp's 664012, 5948251) 6. Datum elevation (DF or KB feet) RKB 81.9 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-29A 9. Permit number / approval number 200-209 10. APl number 50-029-21523-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2602' Production 8718' Liner 310' Liner 1995' 10503 feet Plugs (measured) 9034 feet 10400 feet Junk (measured) 9035 feet Size Cemented 20" x 30" 8 cubic yards concrete 13-3/8" 3255 cuft PFE & 465 cuft PF 9-5/8" 1760 cuft Class G 7" 340 cuft Class G 3-3/16" / 2-7/8" 33.5 bbls 15.8 ppg LARC Tagged PBTD @ 10400' MD on 4/13/2001. Measured Depth True Vertical Depth 110' 110' 2684' 2684' 8800' 8546' 8851' 8595' 10503' 9034' Perforation depth: measured 8934' - 8984'; 9290' - 9300'; 9418' - 9428'; 10370' - 10450'. RECEIVED true vertical 8669' - 8705'; 8776' - 8778'; 8809' - 8812'; 9033.5' - 9034'. MAY 2 9 Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg O 8594' MD. Alaska 0il & Gas Cons. Commissior~ Anchorage 9-5/8" X 4-1/2" Baker D Packer O 8840' MD; Liner Top Packer ~ 8480.5' CTM. 4-1/2" Otis Landing Nipple SSSV @ 2130' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 8O2 Representative Daily Average Production or Iniection Data Gas-Md Water-Bbl 6224 68 Shut in due to high GOR Casing Pressure Tubing Pressure 188 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the fore~qoing is true and correct to the best of my knowledge. Signed ~ ~ /' C,/~-,,~~F' Title: DS B Surveillance Engineer R. Andy Parker "' ' * Date May 22, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ B-29A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS & SET LINER TOP PACKER Date Event Summary 4/1312001: 4/14/2001 - 4/16/2001: 4/2012001: MIRU CTE. PT'd equip to 3500 psi. Performed SCMT & press/temp survey across liner lap. Results indicated gas leak @ the liner lap @ 8508' CTM. Deepest penetration was 10400'. Killed well w/2% KCI Water. POOH. LDFN. RIH w/perf guns & performed tie-in. Shot 70' of add perforations f/: 8934' - 8984' MD (Zone 4) Reference Lo~ BHCS i/25/1986. 9290'- 9300' MD (Zone.. 4) 9418' - 9428' MD (Zone 4) Used 2" PJ carriers & all shots @ 6 SPF, random orientation, 60° phasing, & underbalanced press. POOH w/guns - A_SF. RD CTE. MIRU CTU. PT'd equip. Killed well w/2% KCI Water. RIH & set liner top packer @ 8480.5' CTM. POOH. RD CTU. B-29A is currently shutin for high GOR. A CTE FSPL w/stop counts will be performed in the near future to determine the source of the gas entry. Page 1 0 5111/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57tl ATTN: Sherrie NO. 1135 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay & Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD .~ o o - O~ ~oa-lq5 .B-29A 2t204 SCMT 0411310t D.S. t5-45A 20392 MCNL 09108/00 D.S. t5-42A 20307 MCNL 071t6/00 D.S. 6-22A 20477 MCNL tt116100 D.S. 4-41A 21029 MCNL 01107101 OWDW-SW 2tt49 RST 03114/0t NK-12B 21130 OH EDIT IMP & DIN (PDC) 02/24101 NK-12B 21130 MD VISION RES 02/24101 NK-12B 21130 TVD VISION RES 02/24101 NK-12B 21130 MD VISION DIN 02124101 NK-12B 21130 TVD VISION D/N 02/24/01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received ~ ~ ~,~__.~ WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 29, 2001 RE: MWD Formation Evaluation Logs: B-29A, AK-MW-1003;C{~~ B-29A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21523-01 1 Blueline 1 Rolled Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21523-01 1 Blueline 1 Rolled Sepia 2"x 5" MD Neutron & Density Logs: 50-029-21523-01 1 Blueline 1 Rolled Sepia 2"x 5" TVD Neutron & Density Logs: 50-029-21523-01 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTALS' LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn:' Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Si APR 12 2001 AlaSa 0il & Oas Cons. Commission ( WELL LOG TRANSMITTAL To: State of Alaska March 26, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs B-29A, AK-MW- 10030 1 LDWG formatted Disc with verification listing. API#: 50-029-21523-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Arm: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVEDs 'APR 1 2'2001 Oil & Gas Cons. Commission Exploration (Alaska), nc. Baker Hughes INTEQ Survey Report INTEQ Comlauy: BP Amoco Site.' PBB Pad wen: Date: 3/14/2001 Time: 15:45:15 Page: 1 Co~rdtaatu(NE) Beference: Well: B-29, True Norlh Vertinl (TVD) Reference: 40: 29 1113/1986 00:00 81.9 Section (VS) Reference: Well (0.00E,0.00N,133.24Azi) Survey Caicnlatlou Method: Minimum Curvature Db: Omole 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: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 RECEIVED APR 06 Site: PB B Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map gusting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ft 5946440.22 ft Latitude: 70 15 662094.05 ff LougJtude: 148 41 North Reference: Grid Convergence: ,&laska 0il & Gas Cons. 36.475 N Anchorage 22.843 W True 1.23 deg Well: B-29 Slot Name: 29 B-29 WeH Posiflon: +NI-S 3768.89 ff Northing: 5950245.00 ft Latitude: 70 16 13.540 N +E/-W 1720.59 ff Easttng: 663733.00 ff Longitude: 148 40 32.755 W Position Uncertainty: 0.00 ff Welipath: B-29APB1 Drilled From: B-29 500292152370 Tic-on Depth: 8848.00 ft Current Datum: 40: 29 1113/1986 00:00 Height 81.90 ff Above System Datum: Mean Sea Level Magnetic Data: 1/26/2001 Declination: 26.75 deg Field Strength: 57474 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ff ff ff deg 0.00 0.00 0.00 133.24 Survey: MWD Start Date: 1131/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-au: From: Definitive Path Annotation · ' MD TVD 8848.00 8592.51 Kick-off Point 11000.00 9029.88 Projected to TD Survey MD hcl Azim TVD SSTVD N/S , E~V MapN MapE DLS VS ' , .~t, dee · ~ ~t . ft. ff. ft ft'.. ft. deg/lOOft ft' . . 8848.00 16.37 210.50 8592.51 8510.61 -1518.03 -29.84 5948726.79 663736.19 0.00 1018.20 8905.00 29.40 227.60 8644.96 8563.06 -1534.47 -44.32 5948710.03 663722.07 25.44 1018.91 8933.00 36.50 240.30 8668.47 8586.57 -1543.26 -56.68 5948700.98 663709.92 35.26 1015.94 8987.00 45.70 244.80 6894.07 6812.17 -1553.47 -76.50 5948690.34 663690.31 28.41 1008.48 9007.00 57.90 254.70 8718.80 8636.90 -1564.09 -105.95 5946879.08 683661.10 36.11 994.30 9033.00 63.80 254.00 8731.46 8649.56 -1570.22 -127.81 5948672.48 663639.39 22.81 982.58 9062.00 69.70 249.80 8742.90 8661.00 -1578.51 -153.11 5948663.54 663614.27 24.30 969.83 9100.00 81.60 246.60 8752.31 6870.41 -1592.18 -187.21 5948649.23 663580.48 32.36 954.35 9136.00 88.60 245.50 8755.38 8673.48 -1606.73 -219.97 5948633.97 663548.05 19.68 940.46 9179.00 83.40 237.40 8758.38 8676.48 -1627.20 -257.61 5946812.69 663510.68 22.34 927.06 9232.00 82.10 233.90 8765.08 8683.18 -1656.86 -301.01 5948582.10 663468.12 6.99 915.76 9262.00 83.90 230.10 8768.73 8686.83 -1675.19 -324.47 5948563.26 663445.07 13.93 911.23 9307.00 89.60 229.70 8771.28 8689.38 -1704.12 -356.82 5948533.60 663411.36 12.70 906.02 9352.00 90.30 237.10 8771.32 8689.42 -1730.93 -394.92 5948506.01 663375.85 16.52 898.09 9391.00 90.40 228.30 8771.08 8689.18 -1754.54 -425.91 5948481.73 663345.38 22.57 891.68 9425.00 88.60 215.30 8771.38 8689.48 -1779.83 -448.53 5948455.98 663323.33 38.60 892.53 9467.00 82.40 220.60 8774.68 8692.78 -1812.82 -474.25 5948422.42 663298.33 19.39 896.40 9495.00 79.10 218.80 8779.18 8697.28 - 1834.08 -491.90 5948400.78 663281.15 13.38 898.10 , . Exploration (Alaska), c. ~.~ ~P Baker Hughes INTEQ Survey Report Compaay: BP Amoco Date: 3/14F2001 'llme: 15:45:15 Page: 2 Field: I:'rudhoe Bay Co-ordb.te(N~) RefereBce: Well: B-29, True North Site: PB B Pad Vertical (TVD) Refereuce: 40: 29 1113/1986 00:00 81.9 Wen: B-29 Sm:rios (V$) Refermace: Well (0.00E,0.00N,133.24Az]) Weillmth: B-29APB1 $um'ey Caleuhtio,, Met]tod: Minimum Curvature Db: Oracle Survey MD Iud Azim TVD SSTVD N/S E/W MipN MapE DLS VS 9520.00 77.30 213.20 8784.29 8702.39 -1853.67 -506.26 5946380.69 663267.20 23.08 9565.00 78.10 202.30 8793.91 8712.01 -1892.72 -526.71 5946341.41 663247.62 23.73 9605.00 77.70 199.80 8802.29 8720.39 -1929.21 -540.76 5948304.61 663234.37 6.19 9635.00 77.40 193.90 8808.77 8726.87 -1957.24 -549.25 5948276.42 663226.49 19.23 9673.00 79.20 188.90 8816.48 8734.58 -1993.70 -556.59 5948239.80 663219.94 13.73 9702.00 81.80 181.90 8821.27 8739.37 -2022.15 -559.28 5946211.30 663217.88 25.44 9740.00 82.30 174.50 8826.53 8744.63 -2059.74 -558.09 5948173.75 663219.88 19.33 9778.00 83.00 169.60 8831.40 8749.50 -2097.06 -552.88 5948136.56 663225.90 12.92 9810.00 83.80 162.90 8835.08 8753.18 -2127.92 -545.33 5948105.87 663234.12 20.95 9851.00 84.00 157.30 8839.44 8757.54 -2166.23 -531.46 5948067.87 663248.82 13.59 9894.00 83.40 149.90 8844.16 8762.26 -2204.49 -512.47 5948030.04 663268.64 17.16 9927.00 83.20 145.70 8848.02 8768.12 -2232.22 -495.01 5948002.70 663286.70 12.65 9997.00 82.00 139.00 6857.04 8775.14 -2287.15 -452.64 5947948.71 663330.25 9.65 10030.00 83.50 129.20 8861.22 8779.32 -2309.90 -429.16 5947926.48 663354.22 29.81 10070.00 80.40 119.70 8866.83 8764.93 -2332.28 -396.55 5947904.81 663387.31 24.76 10127.00 83.00 108.40 8875.08 8793.18 -2355.21 -345.12 5947883.00 663439.21 20.14 10165.00 84.60 97.20 8879.20 8797.30 -2363.56 -308.34 5947875.46 663476.16 29.60 10196.00 86.90 92.30 8881.50 6799.60 -2366.12 -277.55 5947873.57' 663507.01 17.42 10231.00 91.10 68.60 8882.11 8800.21 -2365.78 -242.58 5947874.67 663541.96 20.22 10267.00 88.20 79.29 8882.33 8800.43 -2361.36 -206.88 5947879.86 663577.55 21.64 10306.00 87.20 71.90 8883.90 8802.00 -2351.68 -169.16 5947890.36 663615.05 19.11 10344.00 93.40 62.40 8883.70 8801.80 -2336,95 -134.20 5947905.85 683649.68 29.64 10380.00 102.80 68.00 6878.63 8796.73 -2322.00 -101.90 5947921.49 683681.64 30.30 10411.00 105.60 77.10 8871,01 8789,11 -2312.99 -73.28 5947931.13 663710.06 29.85 10437.00 100.50 81.70 8865.14 8783.24 -2308.34 -48.39 5947936.31 663734.83 26.11 10466.00 93.50 83.10 8861.60 8779.70 -2304.54 -19.88 5947940.74 683763.26 24.61 10492.00 87.70 63.80 8861.33 8779.43 -2301.57 5.94 5947944.26 663789.00 22.47 10521.00 79.90 87.00 8864.46 8782.56 -2299.26 34.65 5947947.20 663817.65 29.04 10556.00 77.30 85.60 8871.38 8789.48 -2297.05 68.88 5947950.16 683851.63 8.40 10592.00 71.20 80.30 8881.15 8799.25 -2292.82 103.24 5947955.13 663886.09 22.08 10621.00 69.20 71.20 8890.99 8809.09 -2286.13 129.66 5947962.39 663912.35 30.31 10654.00 65.60 72.20 8903.67 8821.77 -2276.56 156.56 5947972.59 683941.05 11.26 10689.00 63.80 69.40 8918.63 8836.73 -2266.16 1 68.45 5947983.63 663970.69 8.87 10721.00 60.40 74.70 8933.61 8851.71 -2257.43 215.33 5947992.94 683997.37 18.08 10757.00 58.40 77.80 8951.94 6870.04 -2250.06 245.42 5948000.97 664027.29 9.26 10788.00 62.40 78.90 8967.25 8885.35 -2244.62 271.82 5948006.98 664053.56 13.27 10819.00 64.50 85.60 8981.12 6899.22 -2240.g0 299.27 5948011.30 664080.93 20.48 10846.00 67.80 88.70 8992.04 8910.14 -2239.68 323.93 5948013.05 664105.55 16.11 10870.00 71.30 88.70 9000.42 8918.52 -2239.17 346.41 5948014,05 664128.01 14.56 10901.00 75,20 89.80 9009.35 8927.45 -2238,79 376.09 5946315.08 664157.67 13.03 10929.00 78.50 90.90 9015.72 8933.82 -2238.95 403.35 5948015.51 664154.93 12.39 11000.00 78.50 90.90 9029.88 8947.98 -2240.05 472.91 5948015.93 664254.49 0.00 901.18 912.91 927.68 940.69 960.32 977.86 1004.47 1033.83 1060.47 1096.63 1136.87 1168.58 1237.08 1269.77 1308.86 1362.03 1394.55 1418.73 1443.98 1466.96 1487.80 1503.18 1516.46 1531.14 1546.09 1564.26 1581.03 1600.36 1623.79 1645.92 1660.58 1675.09 1689.73 1703.34 1720.21 1735.71 1753.16 1770.29 1786.31 1807.67 1827.64 1879.07 BP Amoco WELLPATH DETAIL8 B-29A Parent Wellpath: B-29APB1 Tie on MD: 0025.00 VorUcal BectJon OHgin: User Defined (0.00~)J0) VorUcal SecUon Angle.' 13324° Rig: Nebom 38 Depth Reference: 40: 291/13/1986 Q0:O0 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: B.29. True North Vertical ([VD) Reference: SysWm: MsanSea Level SecUon (VS) Reference: User Defined (0.00,0.00) Measured Depth Reference: 40: 29 1113/1986 0~.00 81.9 Calculation Method: Minimum Curvature N~4OTATIONS TVD iV&) A,, ,.~,~,~ 864~g2 g02~00 Kid[df Pcin~ 8961.98 10503.00 Projected to TD O /t' M Megnatic North: 26.74'1 ~ ~ Magnetic Fieldl co,,Lac,. s~.;~ 5~474nT I Dip_AJ~. la: 80.75'1 INTEQ / 0~:2,~0011 .~ ............ ~,,,,',..,.~ ...... , ....... Mede~ BGGM20001 Baker II~.,§hes IN -1300 !.. -1400" !., limb , . 0 ~k.m- 1800 l ??00 .-' ,.. West(-)lEast(+) [lOOft/in] 900 950 1000 1050 1100 1150 1200 1250 1300 1350 141X) 14~0 1500 1550 1600 1850 1700 1750 1800 1850 1000 1950 200O 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2B50 Vertical Section at 133.24' [SOft/in] 311412001 3:42 PM TRANSMITTAL FORM BAKER HU~H~ Baker Atlas Canada Geoscience Centre TO: Alaska De.pt of Natural Resources/Division Of Oil Anf Gas 550 West 7'" Avenue Anchorage, AK 99501 Attn: Lori Taylor Reference: Prudhoe Bay North Slope Alaska oo-gofl Package contents · 1 LAS Format disk ~ co 1 Film ~ O_.. 1 Measured Depth GR print 1 TVD-GR print / Sent by: Brad Pramberg Date: March 16, 2001 Received by: Date: RFCEIVED MAR ~ 0 ZOO1 PLEASE ACKNOWLEDGE RECEIPT BY $lal~lgll~}~ons. Commission RETURNING A COPY TO Anchorage BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 . Baker Atlas, 1300, 401 - 9'" Avenue S.W., Calgary, Alberta T2P 3C5 (403) 537-3400 Fax (403) 537-3767 2/28101 Schlumkerger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1034 Company: Field: State of Alaska Alaska Oil & Gas Cons Comm · Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C~ Color i' ~ ? Well Job # Log Description Date Blueline Sepia Prints CD B-29A 21091 MCNL 021001 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED HAR 1 62001 ~Jaska Oil & Gas Cons. C~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AI-I'N: Sherrie Receive~ (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas F~ Suspended F~ Abandoned r"] service 2. Name of Operator' ""----'-'l,j~~' ,' 7. Permit Number BP Exploration (Alaska), Inc. VEI~ i! 200-209 3. Address i~~i 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 ~ 50-029-21523-01 4. Location of well at surface -;-. .... "~::.,'.',~.e~ 9. Unit or Lease Name 399' FNL, 1892' FEL, Sec. 31, T11 N, R14E, UM (asp's 663733, 5950245)'- :!.".71'.. ".;'"-'~i'" Prudhoe Bay Unit At Top Producing Interval ;. ;.; 7. 10. Well Number 2523' FNL, 1720' FEL, SEC 31, T11 N, R14E, UM (asp's 663959, 5948125) ~ -~....' Z/.'....~?/- ~ B-29A At Total Depth ','.' ;."!.~;' ' ;'! -' ;' ' 11. Field and Pool 2398' FNL, 1663' FEL, SEC 31, T11 N, R14E, UM (asp's 664012, 5948251) [;"....-7.~ 'S'-..,.';'..; Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 81.9 feetI ADL 28310 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., ~u/~.p. Or Aband. ~ 15. Water Depth, if offshore 16. No. of Completions January 21, 2001 February 8, 2001 February, 2001'1 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10503' MD / 9034' TVD 10464' MD / 9034' 'I'VD YES ['~ No DI 2130' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR, Resistivity, & Mere GR/CNL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" x 30" n/a n/a Surface 110' 36" 8 cubic yards concrete 13-3/8" 72# L-80 Surface 2684' 17-1/2" 3255 cu tt PFE & 465 cu It PF 9-5/8" 47# L-80 Surface 8800' 12-1/4" 1760 cuft Class G 7" 29# L-80 8541' 8851' 8-1/2" 340 cu It Class G 3-3/16" - 2-7/8" 6.2#/6.4# L-80 8508' 10503' 3-3/4" 33.5 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (all shots w/2" carriers) 4-1/2" 12.6# L-80 8594' 8440' 10370' - 10450' MD; 9033.5' - 9034' TVD; @ 6 SPF Zone 2B , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Surface to 2000' MD FP'd w/MEOH Water (See Sidetrack Summary for details) 27. PRODUCTION TEST ~.~ Date First Production Method of Operation (Flowing, gas Ii,, etc.)U ! b ll l L February 22, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/23/2001 4.0 Test Period >I 10347 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -188 psi 24-Hour Rate > 602 6224 68 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ,Perm,tP ,,oECE VEO * This 10-407 is submitted as directed per the 10-401 form approved December 22, 2000 ~ ' 0-209) & 001 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKE~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sag River Sand 8821' 8567' Top of Shublik 8849' 8593.5' TSAD (Zone 4B) 8932' 8668' Top of Zone 4A 9315' 8781.5' Top of Zone 3 9940' 8882' Top of Zone 2B 10365' 9033' 31. LIST OF ATTACHMENTS Summary of B-29A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~'~~'~'""'""~' Title Coil Tubln,q Drillln.q En,qineer Date March 14. 2001 Lamar (~ntt / Dan Kara INSTRUCTIONS Prepared by Paul Rauf 564-5799. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24-' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water I~jec.~tio, n,, c,~3~ J~j,ection, Shut-in, Other-explain. REG -IV -U Item 28: If no cores taken, indicate "none". Form 10-407 MAR ]. 4 2001 Al~ka 0il & Gas Cons. Commission Anchorage B-29A ~ DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 12/17/2000: MIRU CTU. PT'd BOPE. RIH & milled out XN Nipple @ 8582'. Tagged TOC @ 8830' MD. 12/18/2000: · Milled cement stringers / cement to pinch point @ 8851' MD. Commenced window milling .operations through 7" casing. Milled window & drilled 10' of FM to 8867'. TOW = 8851'. ~BOW = 8857'. Conditioned window. Sat down 17' high. Unable to get through window. Suspect TT broke off & sitting @ Whipstock. POOH. FP'd well. RD CTU. 12/22/2000: RIH w/LIB & tagged Top of broke off 4-1/2" TT @ 8837' SLM. 1/01/2001: MIRU CTU. PT'd equip. RIH w/TEL & located tailpipe. POOH w/TEL. LDFN. 1/02/2001: RIH w/CT & performed injectivity test: 0.3 bpm @ 1000 psi. Tagged top of fish @ 8830' MD. Unable to get further down hole. Pumped 8 bbls of Class G Cement & attained a constant squeeze press of 700 psi WHP. Contaminated cement w/Biozan & cleaned out to 8800'. POOH w/CT. FP'd well to 2100'. RD CTU. WOC. 1/05/2001: MIRU CTU. Safety meeting. 1/06/2001: PT'd BOP. RIH & milled cement f/8805' to 8867' (remilled original window interval). Pumped Biozan & POOH. FP'd well. 1107/2001: RIH w/hydraulic tubing end Iocator. Unable to determine tubing end location. POOH. RD. 1/15/2001: PPPOT-T to 5000 psi - passed. 1/18/2001: MIRU Nabors 3S. Rig accepted 1200 hrs. (see DIMS attached operations summary) REcEiVED MAR .1 7001 Alaska Oil & Gas ConS. Commission Anchorage BP EXPLORATION Page 1 of 1 Final Well I Event Summary Legal Well Name: B-29 Common Well Name: B-29A Event Name: REENTER+COMPLETE Start Date: 1/18/2001 End Date: 2/11/2001 DATE TMD ! 24 HOUR SUMMARY 1/18/2001 8,867.0 (ft) MIRU 1/19/2001 8,867.0 (ft) ', Tag TD @8865'. Lost 600 psi. Lost MWD signal. 1/20/2001 8,867.0 (ft) Bait fish with overshot using slickline. Fish w/coil -- recovered. 1/21/2001 8,867.0 (ft) Drill to 8995'. Lost mud at 0.8 bpm. 1/22/2001 9,100.0 (ft) Pumped Forma-A-set pill. Driled to 9100'. Change out orienter. 1/23/2001 9,990.0 (ft) Drilled to 9990' MD with 25-35 bph mud losses. 1/24/2001 10,238.0 (ft) Pump L.C. pill. Trip f/motor. W/R to TD. DD ahead. 1/25/2001 10,557.0 (ft) Directionally drill f/10238' to 10557'. 1/26/2001 10,635.0 (ft) Pump/squeeze LCM pill. TOH. Cut CT. TIH. Drill ahead. 1/27/2001 10,635.0 (ft) W trip. DD to 10664'. TOH. Test BOP's. P/U BHA #7 TIH 1/28/2001 10,853.0 (ft) Drill to 10710'. Trip f/PDC. Drill to 10853' 1/29/2001 10,853.0 (ft) Rig repair, no-go through shales. Trip f/bi-cneter bit. TIH 1/30/2001 11,001.0 (ft) Found old hole, DIr to 11001. Diff stuck. Wiper trip. Lost old hole. 1/31/2001 11,001.0 (ft) Trip f/2.5 motor. Unable to find old hole. Pump LCM pill. TOH 2/112001 9,000.0 (ft) Cmt plug openhole, P/U drlg BHA, tag cmt, TOH failed MWD. 2/212001 9,555.0 (ft) TIH. Sidetrack well at 9250'. Drilled according to lastest well plan. 2/3/2001 9,623.0 (ft) Dig to 9623 TOH. Test BOP. Make 2 rd trips. I f/MWD and 1 f/Orienter 2/4/2001 9,704.0 (ft) XO orienters. Failed. XO orienters. Drill to 9704'. TOH f/orienter XO 2/5/2001 9,914.0 (ft) Finish TIH. Drilled to 9914'. TOH due to slow ROP. P/U new bit TIH 2/6/2001 10,064.0 (ft) Drill to 10064'. Failure on sperry tool. Lost mud at 20 BPH 2/7/2001 10,288.0 (ft) Drill to 10288'. Mud losses 25 BPH. POH to change bit. 2/8/2001 10,503.0 (ft) TD well @10503'. Ream shale @9400'-9500'. PU 2 7/8" liner 21912001 10,503.0 (ft) Ran and cement liner. 2110/2001 10,503.0 (ft) Liner lap test. Ran CNL log 2/1112001 10,503.0 (ft) Perforate 10370'- 10450'. FP 2000'. Set BPV. RECEIVED 1 4 7_001 Naska Oil & Gas Cons, commission Anchorage Printed: 3/12/2001 3:50:17 PM ,, , BP EXPLORATION Page 1 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/18/2001 12:00 - 15:00 3.00 RIGU PRE Accept rig 12:00 hrs. Rig-up and spot equipment. NU BOPE. 15:00 - 15:30 0.50 RIGU PRE Spot Coil unit. 15:30 - 16:00 0.50 RIGU PRE Safety meeting. 16:00 - 00:00 8.00 RIGU PRE Continue rigging up. ~1/19/2001 00:00 - 05:00 5.00 BOPSUR PROD1 Change out rams. 05:00 - 06:00 1.00 BOPSUR PROD1 Stab onto well, Pump 1 5/16" ball. Bump at 50.5 bbls. 06:00 - 07:00 1.00 BOPSUI:; PROD1 Safety meeting with day crew. Discussed hazard analysis/risk mitigation expectations. Conduct same for BOP test. :07:00 - 09:00 2.00 BOPSUF PROD1 RU test joint, tongs for BOPE test. 09:00 - 17:00 8.00 BOPSUF PROD1 PT BOPE. Witnessed waived by AOGCC (Jeff Jones). 17:00 - 19:30 2.50 BOPSUF PROD1 RU lubricator and pull TWC. Jet top of BPV. 19:30 - 20:00 0.50 DRILL PROD1 Hold safety meeting. 20:00 - 21:45 1.75 DRILL PROD1 PU Drilling BHA #1. 21:45 - 22:05 0.33 DRILL PROD1 Testing Orienter. OK. 22:05 - 23:00 0.92 DRILL PROD1 Displace to water 23:00 - 00:00 1.00 DRILL PROD1 Stab onto well 1/20/2001 00:00 - 01:50 1.83 DRILL PROD1 RIH w/BHA #1 01:50 - 02:10 0.33 DRILL PROD1 Orient to high side. 02:10 - 02:45 0.58 DRILL PROD1 Tag TD at 8865'. 02:45 - 03:20 0.58 DRILL PROD1 Tie in w/GR swapping to mud. Lost 600 psi. No signal from MWD. 03:20 - 04:45 1.42 FISH BHA PROD1 POH to check out BHA. 04:45 - 06:00 1.25 FISH BHA PROD1 OOH. Lost half of the orienter (4.67' orienter recovered). Orienter backed off. 3.0" OD box looking up with 3' of orienter shaft sticking up thru it. TOF in 7". Total fish = 55.67'. 06:00 - 09:15 3.25 FISH BHA PROD1 Call for slickline crew (on Z-Pad). Gather-up fishing tools. 09:15 - 09:45 0.50 FISH BHA PROD1 Safety meeting with slickliners. 09:45 - 11:00 1.25 FISH BHA PROD1 RU slickliners. 11:00 - 13:15 2.25 FISH BHA PROD1 RIH with impression block. Tag at 8800'. POOH. LD tools. Top of orienter shaft is lower left. 13:15 - 16:15 3.00 FISH BHA PROD1 MU and RIH with overshot w/extensions to swallow prong and grab 3.0 OD body. Jar down to set spiral grapple. PUH to 1800 lbs (max slickline). No movement. Shear off (4-1/2" GS FN up). POOH and RD slickline. 16:15 - 16:45 0.50 FISH BHA PROD1 Wait on Baker tools to fish with coil. 16:45- 17:00 0.25 FISH BHA PROD1 Safety meeting. 17:00- 18:30 1.50 FISH BHA PROD1 MU Baker fishing BHA. C/O connector. Pull and PT. 18:30 - 20:20 1.83 FISH BHA PROD1 RTIH 20:20 - 21:45 1.42 FISH BHA PROD1 Latch into fish. 4K heavier on PU. No overpull. POOH 21:45 - 22:05 0.33 FISH BHA PROD1 OOH. Recovered fish. 22:05 - 00:00 1.92 FISH BHA PROD1 MU drilling BHA #3. 1/21/2001 00:00 - 02:20 2.33 FISH BHA PROD1 Continue MU drilling assembly. 02:20 - 02:45 0.42 FISH BHA PROD1 Pull test CT connector 02:45 - 04:30 1.75 FISH BHA PROD1 RIH w/new drilling assembly. 04:30 - 05:00 0.50 FISH BHA PROD1 Orienting. 05:00 - 05:15 0.25 FISH BHA PROD1 Tag TD @8871'. 05:15 - 06:30 1.25 DRILL PROD1 PU to 8800'. Tie-in. Correct depth (-2'). 06:30 - 08:15 1.75' DRILL PROD1 Orient high right. Can't get past top of tailpipe. PU and orient high left. Poke nose into open hole and orient to 45R. TF flopped to 90R. Drill a couple feet and then orient around again. 08:15 - 14:15 6.00 DRILL PROD1 Drill Shublik 10 FPH to 8890'. Started seeing losses at 0.5 BPM here. Increased to 1.5 BPM at 8896'. Slowed to 0.2 BPM, but picked-up again to 1.2 BPM at 8905'. Drill to 8914'. 14:15- 16:30 2.25 DRILL ClRC PROD1 PU above window while waiting on mud. Fill across top. Losses 9 Printed: 2/2612001 3:08:41 PM BP EXPLORATION Page 2 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/21/2001 14:15- 16:30 2.25 DRILL CIRC PROD1 BPH. 16:30- 17:00 0,50 DRILL PROD1 Mud on location. Orient 17:00 - 20:45 3.75 DRILL PROD1 Continue drilling Shublik at 2.4/1.6 and 3400 psi. 20:45 - 23:20 2.58 DRILL PROD1 Drill to 8948'. 2.7/2.1 and 3000 psi. Drill to 8984'. Mud losses 0.6 bpm. 23:20- 00:00 0.67 DRILL PROD1 Continue drilling. Drill to 8995'. 1/22/2001 00:00 - 02:15 2.25 DRILL PROD1 Drill to 9034'. Mud losses 1.0 BPM at 9010'. 02:15 - 02:30 0.25 DRILL PROD1 Orienting 02:30 - 03:00 0.50 DRILL PROD1 Drill to 9040' 03:00 - 03:20 0.33 DRILL PROD1 Waiting on mud. POH to casing. 03:20 - 04:00 0.67 DRILL PROD1 Mud on location. RIH 04:00 - 05:00 1.00 DRILL PROD1 Orienting to 30L 05:00 - 11:00 6.00 DRILL MOTR PROD1 Drill and orient 2.7/1.9 and 2800 psi. Still unusually slow ROP in Zone 4 -- 15 FPH, Motor stalls too easily, but stalls are strong. Give-up at 9100'. Should be able to get rest of build with smaller bend motor. 11:00 - 12:00 1.00 DRILL ClRC PROD1 PU to 8800', get MI moving for Form-A-Set pill. Establish injectivity 1.5/500; 2.0/600; 2.5/650. Mix activator. 12:00 - 13:15 1.25 DRILL ClRC PROD1 Circ 23 bbls Form-A-Set pill to bit at 8800', SI BS and bullhead pill 2.0/600 intial 1.0/650 final. Pumped 14 bbls into loss zone. Open choke, and with 2 bbls behind coil, lay in remaining 7 bbls of pill. 1.5 bbls lost to formation while laying in at 1.0 BPM. Pull to safety and circ at minimum rate. Lost another 1.5 bbls in 20 minutes. About 4 bbls of LCM remaining inside well. No sense putting any more ECD on this. 13:15 - 15:45 2.50 DRILL PROD1 POOH filling, No additional losses to formation while POOH. 15:45 - 16:00 0.25 DRILL PROD1 Safety meeting. 16:00 - 18:00 2.00 DRILL PROD1 LD BHA #3. Bit had junk or metal damage on shoulder; motor suspect. MU drilling BHA #4 (new probe, 1.37 deg motor; used DS49), 18:00- 18:40 0.67 DRILL PROD1 RIH. 18:40 - 19:10 0.50 DRILL PROD1 Testing MWD & Orienter. Orienter did not work. 19:10- 19:55 0.75 DRILL ORNT PROD1 POHto change Orienter. 19:55-20:50 0.92 DRILL ORNT PROD1 OOH, Change orienter. 20:50- 21:45 0.92 DRILL ORNT PROD1 RIH. Test Orienter & MWD. OK. 21:45 - 23:00 1.25 DRILL PROD1 RIH. Tag TD. Tie in w/GR. -4' correction 23:00 - 00:00 1.00 DRILL PROD1 Orienting to HS. Drill to 9100', 1/23/2001 00:00 - 00:30 0.50 DRILL PROD1 Orienting. had some problems when orienting. Erratic clicks, 00:30 - 01:00 0.50 DRILL PROD1 Drill to 9140'. 2.5/2800. Loosing 30 BPH. 01:00 - 03:00 2.00 DRILL PROD1 Orienting, Not able to orient in the horizontal section. PU to BU section, 03:00 - 04:30 1.50 DRILL PROD1 Drill ahead. Drill to 9252'. 04:30- 05:00 0.50 DRILL PROD1 PU to 9232'. Orienting. 05:00 - 05:20 0,33 DRILL PROD1 RIH. Continue drilling. Drill to 9289' 2.8/3000 psi. 25 BPH mud losses, 05:20- 05:40 0.33 DRILL PROD1 Orienting 05:40 - 06:40 1.00 DRILL PROD1 Drill ahead to 9350' 06:40 - 07:20 0.67 DRILL PROD1 Wiper to window. 07:20- 07:40 0.33 DRILL PROD1 Orient 07:40 - 11:45 4.08 DRILL PROD1 Drill and orient 2.8/2.5 at 2800 psi. Losses still about 20 - 25 BPH. (Loss rate cut in half after Form-A-Set job). Hit a hard spot at 9490', TF did a dance, and lost a big slug of fluid. Then settled out. Losing 50 BPH. Drill to 9523'. 11:45 - 12:30 0.75 DRILL PROD1 Wiper to window, waiting on new mud. 12:30 - 15:15 2.75 DRILL PROD1 Drill to 9660'. Losses 40 BPH. 15:15 - 16:15 1.00 DRILL PROD1 !Wiper to window. 16:15 - 17:00 0.75 DRILL PROD1 Drill to 9715'. Got slug of Form-A-Set back on last wiper trip, Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/23/2001 17:00- 17:15 0.25 DRILL PROD1 Orient around. 17:15 - 19:00 1.75 DRILL PROD1 Drill to 9835'. 19:00 - 20:15 1.25 DRILL PROD1 Wiper trip to window 28 BPH losses while tripping. Start mixing 2nd Form-A-Set pill. 20:15 - 23:10 2.92 DRILL PROD1 Drill to 9990'. 30-35 BPH losses. 23:10 - 23:59 0.82 DRILL PROD1 Wiper trip to 8900'. 1/24/2001 00:00 - 00:10 0.17 DRILL PROD1 Finish wiper trip. Lost 36 bbl during trip. Hit shale bridges at 9050' and 9550'. Continue mixing Form-A Set pill. 00:10 - 01:30 1.33 DRILL ClRC PROD1 Circulate and monitor mud losses. Finish mixing pill. P/U to 9500'. 01:30 - 02:30 1.00 DRILL ClRC PROD1 Pump 26.5 bbl Form-A-Set pill. Displace 2 bbl in annulus at 9500'. Lay-in remainder at 1:1 Top of pill at +/- 8400'. Pull to safety at 7800'. 02:30- 03:30 1.00 DRILL ClRC PROD1 WOC. Pump at minimum rate 0.3 bpm 03:30- 05:00 1.50 DRILL ClRC PROD1 Shut-in annulus at choke manifold and squeeze pill. Pumped at rain rate. After 1.3 bbl pumped annulus pressure 950 psi. After 15 rain decreased to 600 psi. Maintain 950 - 600 psi on annulus. 05:00 - 07:00 2.00' DRILL PROD1 TOH to pick-up stronger motor to ensure we don't swing too far south. 07:00 - 08:30 1.50 DRILL PROD1 LD BHA. MU BHA #5 (1.7 deg motor; DS49) 08:30 - 11:00 2.50 DRILL PROD1 RIH. Wash to 9200'. Divert returned LCM. 11:00 - 13:30 2.50 DRILL CIRC PROD1 Diverted a bunch of mud/LCM. Started seeing losses with bit at first loss zone. Pull to casing and wait for mud. 13:30 - 14:30 1.00 DRILL PROD1 RIH. Bobbles at top of tailpipe and window show we're on depth. RIH. Tag with stall at 9000' (area of LC zone). PU. RIH dry to 9005'. Tag. Push something to 9010', then cleaned-up. Finish washing to TD. 14:30 - 16:45 2.25 DRILL PROD1 Drill 2.5/2.1 at 2800 psi to 10135'. Losses about 25 BPH. 16:45 - 17:30 0.75 DRILL PROD1 Wiper to window. 17:30 - 17:50 0.33 DRILL PROD1 Log tie-in at PA. Correct depth (-7'). 17:50 - 19:20 1.50 DRILL PROD1 Wash to bottom. Ream tight shale at 9500'. 19:20 - 21:10 1.83 DRILL PROD1 Drill 2.5/2.1 at 2850 psi to 10238'. Losses continue 25-30 bph. 21:10 - 23:59 2.82 DRILL PROD1 Wiper trip into casing. Shutdown pumps clean screens on mud pump suctions. RIH wash and work shales at 9500' to 9560'. 1/25/2001 00:00 - 00:20 0.33 DRILL PROD1 Finish wiper trip. 00:20 - 01:15 0.92 DRILL PROD1 Orient TF 01:15 - 03:20 2.08 DRILL PROD1 Drill from 10238' to 10367' Losses 20-25 bph. 03:20 - 04:30 1.17 DRILL PROD1 Wiper trip 04:30 - 09:30 5.00 DRILL PROD1 Drill to 10485'. Stacking in shale here. 09:30 - 10:30 1.00 DRILL PROD1 Wiper trip to window. Ream shale at 9500'. 10:30 - 11:30 1.00 DRILL PROD1 Orient 11:30 - 15:45 4.25 DRILL , PROD1 Drilling. Very slow. Stacking, then stalling. The kink we put in isn't helping. Drill to 10533'. 15:45 - 18:15 2.50 DRILL PROD1 Wiper trip to window to work shales. 18:15- 19:00 0.75 DRILL PROD1 Orient. 19:00 - 23:59 4.98 DRILL PROD1 Drilling ahead slowly. 2.5/2.1 2850 psi. Continued problems with stacking and stalling. Drill to 10557'. Losses 20-30 bph. 1/26/2001 '00:00 - 01:40 1.67 DRILL PROD1 TOH to 8790'. 01:40 - 02:00 0.33 DRILL PROD1 Hold pre-job safety and job assignment meeting about pumping LCM pill. 02:00 - 02:30 0.50 DRILL PROD1 Drop and pump down 0.8125" ball and open circ-sub. 02:30 - 04:00 1.50 DRILL PROD1 TIH to 8830'. Pump 50 bbl Afron LCM pill and displace 1:1 to 6800'. Pull to 5800' for safety. 04:00 - 05:30 1.50 DRILL PROD1 Shut-in well and bullhead 30 bbls at 0.3 bpm to loss zones. Steady increase in pressures to 635 psi. Shutdown pump. Observed pressure drop from 635 psi to 250 psi in 10 min. Bleed off remaining pressure. 05:30 - 07:00 1.50 DRILL PROD1 TOH f/tri-cone bit and orienter. Printed: 2/2612001 3:08:41 PM BP EXPLORATION Page 4 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/26/2001 07:00 - 08:00 1.00 DRILL PROD1 LD BHA. Bit had Zone 3 wear. 08:00 - 10:00 2.00 DRILL OTHR PROD1 Cut 200' of pipe for fatigue management. Up to 40% from reaming shales. Call this NPT. 10:00 - 11:45 1.75 DRILL PROD1 Rehead. Pull and PT connector. MU drilling BHA #6 (new orienter, 1,3 deg motor; HC tricone bit). 11:45- 12:30 0.75 DRILL PROD1 ,RIH, 12:30 - 16:00 3.50 DRILL ORNT PROD1 Shallow test tools at 4500'. Orienter not working. POOH. LD orienter. PU and surface test new orienter with Sperry eye-bailing it, RIH to 45O0'. 16:00- 17:00 1.00 DRILL PROD1 Continue RIH. 17:00 - 17:30 0.50 DRILL PROD1 Log tie-in, Correct depth (-7'). 17:30- 18:40 1.17 DRILL PROD1 RIH 18:40- 19:00 0.33 DRILL PROD1 Orient. 19:00 - 23:59 4.98 DRILL PROD1 Directionally drill f/10557' to 10635', On bottom drill time 2,75 hrs. Mud losses 25-30 bph. 1/27/2001 00:00 - 01:10 1.17 DRILL PROD1 Wiper trip to 8900' 01:10 - 02:30 1.33, DRILL PROD1 Orient toolface. 02:30 - 05:30 3.00 DRILL PROD1 Directionaly drill from 10635' to 10664'. Mud losses 25-30 bbl/hr, 05:30 - 08:00 2.50 DRILL PROD1 TOH due to slow ROP and hours on tri-cone bit. 08:00 - 09:00 1.00 DRILL PROD1 LD BHA. 09:00 - 18:30 9.50 DRILL PROD1 Change 3-1/2" pipe rams to 2-7/8", Perform weekly BOP test. Witness waived by AOGCC (Lou Grimaldi) 18:30 - 19:00 0.50 DRILL PROD1 Hold pre-job safety meeting concerning opening well after BOP test and p/u next BHA. 19:00 - 19:30 0,50 DRILL PROD1 Displace meth from coil. Fill hole, took 8 blls (517') to fill. 19:30 - 20:30 1.00 DRILL PROD1 P/U BHA #7. Surface test orienter. 20:30 - 23:59 3.48 DRILL PROD1 TIH (Test orienter @ 4000'). GR tie-in. TIH 1/28/2001 00:00 - 00:45 0.75 DRILL PROD1 Finish TIH. 00:45 - 01:00 0.25 DRILL PROD1 Orient 01:00 - 06:00 5.00 DRILL PROD1 Directionall drill f/10645' to 10710'. Mud losses 25-30 bph. 06:00 - 08:30 2.50 DRILL PROD1 TOH due to hours on bit, 08:30 - 10:00 1.50 DRILL PROD1 Swap Tri-cone (3-3 and in gage) with DS49. Change probe. 10:00- 11:30 1.50 DRILL LMWD PROD1 RIH. Shallow test, Couldnt' get MWD pulse, POOH. Troubleshoot. Change pulser. 11:30- 13:15 1.75 DRILL PROD1 RIH. 13:15 - 13:30 0.25 DRILL PROD1 Log tie-in at IRA. Correct depth (-15'). 13:30 - 14:30 1.00 DRILL PROD1 RIH, Ream last 100' to TD. 14:30- 14:45 0.25 DRILL PROD1 Orient, 14:45 - 16:45 2.00 DRILL 'PROD1 Drill. Good ROP with PDC in Zone 3 -- 30 to 40 FPH. At 10715' losses increased from 0.3 BPM to 1.3 BPM, then gradually healed to 0.4 BPM losses, Drill to 10750' 16:45- 17:15 0.50 DRILL PROD1 Orient 17:15 - 20:00 2.75 DRILL PROD1 Directionally drill 10710' to 10854'. 2.6/2.2 and 2800 psi. 20:00 - 22:10 2.17 DRILL PROD1 Wiper trip to window. 22:10 - 23:59 1.82 DRILL STAB PROD1 Wash and work shales f/9510' to 9560'. 1/29/2001 00:00 - 00:15 0.25 DRILL STAB PROD1 Wash shales to 9565'. CT horsehead assembly's cog engaging the levelwind shaft bound up and split 1 bearing on the shaft. 00:15- 00:30 0,25 DRILL OTHR PROD1 Pull into casing at 8790'. Circulate at rain rate, 00:30- 12:30 12.00 DRILL OTHR PROD1 Levelwind shaft damaged along with both end bearings and bearing housings. Replacement parts locally available and repairs being made. Circulating at min rate 1,0/.7 @ 1460 psi and moving pipe within 7" casing, 12:30 - 16:45 4.25 DRILL STAB PROD1 Orient and try to work past 9500' shale. Worked bit to 9552' w/o Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 5 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/29/2001 12:30 - 16:45 4.25 DRILL STAB PROD1 pumps. No progress. Tagging on bit. Tried all TF's, varied rates, and bounced it down at different speeds. 16:45 - 19:30 2.75 DRILL STAB PROD1 Discuss options w/town. Decided to POOH and PU bicenter bit. POOH. 19:30 - 21:20 1.83 DRILL STAB PROD1 Cut 150' of 2.375" CT. Weld on connector. Pressure test same. 21:20 - 22:15 0.92 DRILL STAB PROD1 P/U BHA # 8 and bit #9. Surface test orienter. 22:15 - 23:59 1.73 DRILL STAB PROD1 TIH. Test MWD and orienter at 4000'. TIH. 1/30/2001 00:00 - 01:00 1.00 DRILL STAB PROD1 Tie-in log @ 8850'. -12' correction. 01:00 - 01:20 0.33 DRILL STAB PROD1 TIH Tagged bridge at 9555'. 01:20 - 03:00 1.67 DRILL i STAB PROD1 Attempt to push through bridge with and without pumps at varies TF settings. Concentrating mainly at 40-50L which is were hole was drilled. 03:00 - 04:15 1.25, DRILL STAB PROD1 With pumps at 2.5 bpm and 40-50L TF washed very slowly 5'/hr from 9555' to 9561' without motor work. Attempted to push through without pumps without success. Washed (drilled) at 2'/min f/9561' - 9572' stopping at intervals and without pumps trying to push through to old hole without success. 04:15 - 07:00 2.75 DRILL STAB PROD1 Orient TF to 80-70L and wash/ream hole section f/9555' to 9572'. 07:00 - 10:00 3.00 DRILL STAB PROD1 Decide to drill ahead at 50L. Drill to 9608' at 100 FPH. PUH to orient around to 90L. Work thru shale at 1.0 BPM, tagging at 9508', 9530', 9552', 9572'. Overpulls when PU (haven't seen this in awhile). Work past 9572', wash to bottom -- no bottom found. In old hole. Ream to TD slowly (ratty weight and some motor work w/this bicenter bit). Note: Survey seen at 9568' shows inclination about 1.5 deg higher than survey at 9565' when it was first drilled. 10:00 - 12:00 2.00 DRILL PROD1 Drill 2.5/2.0 and 2800 psi with highside TF to 10950' 12:00 - 12:45 0.75 DRILL 'PROD1 Do 500' wiper, get a click. 12:45 - 14:00 1.25 DRILL i PROD1 Drill 2.6/2.0 and 2900 psi to 11000'. Pick up to get click, RIH and tag TD, and got stuck differentially. 14:00 - 14:45 0.75 DRILL DS I pROD1 Work stuck pipe. Call for crude. Let things relax for a bit, push to negative wt, pull to 80k, and pulled free (w/o crude). 14:45 - 21:45 7.00 DRILL STAB PROD1 Wiper trip to window. Pulled free through shales f/9550' - 9500' worked back down though shales but unable to go deeper then 9802'. (sidetrack hole?). Attempted to work through with varying TF settings. Talked with town decided to trip for 2+ deg motor and re-attempt. Also spot/squeeze 10ppb OM Seal & 10ppb Liq Csg pill prior to TOH. 21:45 - 22:45 1.00 DRILL STAB PROD1 Pull into casing 8800'. Mix LCM pill. 22:45 - 23:59 1.23 DRILL STAB PROD1 Lay-in LCM pill 1:1 close Super Choke hestitaion squeeze into formation. 1/31/2001 00:00 - 01:00 1.00 DRILL STAB PROD1 Finish squeeze with LCM pill. Held 450-500 psi pump min rate for 30 min. Let well bleed down to 200 psi and open Super Choke. Pump with well open and observe losses. Down from .7 bph to .3 bph. 01:00- 02:30 1.50 DRILL STAB PROD1 TOH 02:30 - 03:30 1.00 DRILL STAB PROD1 Displace coil w/methenol. L/D motor. 03:30 - 04:45 1.25 DRILL STAB PROD1 Cut 150' CT. Dimple on new connector and pull test same. 04:45 - 05:30 0.75 DRILL STAB PROD1 M/U MHA, orienter and surface test same. P/U 2.57 deg motor. 05:30 - 07:30 2.00 DRILL STAB PROD1 TIH w/BHA # 10, OAL = 88.33'. Attempt SHT @ 4000'. Assume 2.57 AKO is too much in tubing. RIH past tubing tail. Attempt SHT. No pulses. 07:30 - 09:30 2.00 DRILL LMWD PROD1 POH for pulser. 09:30 - 10:25 0.92 DRILL LMWD PROD1 Change out MWD tool. Find pulser not working. Test orienter. Circulating pressure through MHA and Orienter normal. 10:25- 12:15 1.83 DRILL LMWD PROD1 RIH w/BHA#10. SliT @ 250' good pulses and pressure. Mix 30 Bbl pill of 15 ppb OM-seal and Liquid casing. Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 6 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/31/2001 10:25-12:15 1.83 DRILL LMWD PROD1 12:15 - 12:45 0.50 DRILL STAB PROD1 Log GR tie in, (-8'), Pumping 2.6 bpm, getting 2.2 bpm returns. Getting 1 for 1 returns at .7 bpm. 12:45 - 16:00 3.25 DRILL STAB PROD1 Attempt to find old hole to 11000'. Try various orientations w/minimum pump rate. Appear to find old hole by seeing hole take weight from 9570' to 9600'. Keep working down with pump at 1 bpm, Confir with town players. Confirm if leg is sidetrack. Making hole at 100 fph to 9638'. Two surveys confirm sidetrack. Drift w/Iow pump rate and confirm sidetrack. Plan on cement plug back to ~ 9000' and re-drill. 16:00- 19:30 3,50 DRILL STAB PROD1 Pull up into casing. Drop 13/16" ball to open circ. sub. Pump 30 bbl LCM pill. Losing 12-14 bph prior to pill. Lay in pill. Shut in choke and squeeze pill into open hole. 19:30 - 20:30 1.00 DRILL STAB PROD1 Maintain 200-300 psi on well while TOH paint marker at 5500'. 20:30-22:15 1.75 DRILL STAB PROD1 L/D BHA#10. M/U BHA#11 22:15- 23:59 1.73 DRILL STAB PROD1 RIH to paint marker, make -12 correction. Tag-up at 9612'. 2/1/2001 00:00 - 03:15 3.25 REMCM;'STAB ABAN Circulate and condtion hole for cement plugback. Circulating back some LCM from pill #2. Rig-up cementers. 03:15 - 03:30 0.25 REMCM"STAB ABAN Hold pre-job safety / assignment meeting. 03:30 - 04:45 1.25 REMCM"STAB ABAN Pressure test lines to 4000 psi. From 9600', pump 10 bbl KCL ahead followed by 30 bbls 15,8ppg cement displace with 48.5 bbl KCL laying in 1:1 using Dowell pump. Fluctuating out rates while displacing indicating some loses to formation slowly returning to 1:1 rates toward end of displacement. CIP @ 0400 hrs. Pull to safety @ 7000'. 04:45 - 06:00 1.25 REMCM"STAB ABAN Switch over to rig pumps drop 3/4" ball. Displace annulus to KCL water 1:1 rates while displacing, No cement to surface 06:00 - 08:00 2,00 REMCM"STAB ABAN Lose returns at high pump rate. Maintain minimum rate and 1 for 1 returns to allow cement to gel. Mix and circulate in 1.5 ppb biozan pill. Wash down to 9000' with gel at nozzle. Pumping 1.5 bpm and getting full returns. Make two passes to 9000' and chase out of hole, 08:00 - 09:45 1.75 REMCM' 'STAB ABAN Get cement returns with bottoms up along with 100% returns. POH jetting. 09:45 - 11:00 1.25 REMCM' 'STAB ABAN OOH, Jet stack with swizzle stick. 11:00 - 13:30 2.50 STKOH STAB WEXlT Wait on directional plan and cement. 13:30- 14:30 1.00 STKOH STAB WEXlT M/U BHA#12; Bicenter+ 1,69AKO. Surface test orienter. 14:30-16:30 2.00 STKOH STAB WEXlT RIHw/BHA#12, OAL=68.33'. Shallow hole test good. 16:30 - 17:30 1.00 STKOH STAB WEXlT Log GR tie-in. Cement compressive strength on UCA · 1600 psi. Can not sustain MWD signal on KCL water. 17:30 - 18:00 0.50 STKOH STAB WEXlT Run in hole pumping minimum rate to find cement top @ 9032' uncorrected. 18:00 - 19:35 1.58 STKOH STAB WEXlT Pull up hole and circulate in Flopro for tie-in. MWD signals still very weak 5psi vs 50 psi. Unable to bring to life, 19:35-21:00 1,42 STKOH STAB WEXlT TOHf/MWDfailure. 21:00 - 23:25 2.42 STKOH STAB WEXlT Change out MWD and P/U bit #10. 23:25 - 23:45 0.33 STKOH STAB WEXlT TIH to 400' shallow test MWD. 23:45 - 23:59 0.23 STKOH STAB WEXlT Continue TIH. 2/2/2001 00:00 - 01:00 1.00 STKOH STAB WEXlT Finish RIH with BHA #13 OAL = 68.03'. 01:00 - 03:15 2.25 STKOH STAB WEXlT Log GR tie-in -5' correction. 03:15 - 03:25 0.17 STKOH STAB WEXlT RIH tagged cement at 9024', 03:25 - 04:35 1.17 STKOH STAB WEXlT Toolface 60L no orienting. Drilling 2.6/2.6 2630 psi. Broke through and drilled cement stringers from 9042' to 9064'. Drill rate 2'/rain consistant from 9064' to 9111'. Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 7 of 11 Operations Summar Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/2/2001 04:35 - 05:05 0.50 STKOH STAB WEXIT Orient TF 90L 05:05 - 05:30 0.42 STKOH STAB WEXlT Drilling ahead. Appears we are in old hole. No losses at this time. 05:30 - 06:10 0.67 STKOH STAB WEXlT Short trip to 9000'. Stay below Shublik shale. '06:10-06:30 0.33 STKOH STAB WEXlT Tour safety meeting. 06:30 - 06:40 0.17 STKOH STAB WEXlT Reduce pump rate to lbpm. RIH. Tag up and stack 20k# @ 9145'. ' Bottoms up sample shows primarily cement. Surveys indicate old hole. 06:40 - 07:00 0.33 STKOH STAB WEXlT Orient TF f/30L to 90L. 07:00 - 11:00 4,00 STKOH STAB WEXlT Make couple of trenching passes with TF at 90L. 11:00 - 12:30 1.50 STKOH STAB WEXlT Time drill from 9149' @ 2 min/10th foot to establish side track. Slightly higher to desired plan, still ok directionally. Pump 2.5 bpm/2.4bpm returns, 2600 ctp, 26.8k# string weight. Losing @10 bph. Time drill to 9153.5'. 12:30 - 17:00 4.50 STKOH STAB WEXlT Increase ROP to 10 fph. Stalling motor possibly in shale, Confirm side track by survey data when bit @ 9300' 17:00- 19:55 2.92 DRILL STAB PROD1 Drill ahead toward plan in zone 4. Pumping 2.5 bpm/2.3 bpm returns, 2600/3000 ctp, 23k# string weight. Drill to 9440'. 19:55 - 21:00 1.08, DRILL .STAB PROD1 Wiper trip to 9000'. 21:00-21:15 0.25 DRILL ~STAB PROD1 Orientto 120LTF. 21:15 - 23:59 2.73 DRILL STAB PROD1 Drill ahead in Zone 4. Pump 2.6 / 2.3bpm @ 3060 ctp 20-26 bph mud losses. 2/3/2001 00:00 - 01:15 1.25 DRILL STAB PROD1 Drilled in Zone 4 f/9555' to 9623' 2.6 / 2.3 3050 ctp. 01:15 - 03:00 1.75 DRILL STAB PROD1 Pump 10 bbl LCM pill (15ppb OMSeal-15ppb Liq csg) lay-in 1:1 while making wiper trip to window. 03:00 - 03:35 0.58 DRILL LMWD PROD1 LCM pill plugged MWD. Pumped 5 bbl KCL water in an attempt to clear probe, no responce from MWD. 03:35 - 05:30 1.92 DRILL LMWD PROD1 TOH to clear MWD of LCM. 05:30- 06:15 0.75 DRILL LMWD PROD1 OOH and lay down BHA 06:15 - 07:45 1.50 BOPSUF STAB PROD1 Lay down BHA, Changing out BHI for Sperry Sun MWD. Circulate out coil to MethNVtr for BOP test. 07:45 - 14:30 6.75 BOPSUF STAB PROD1 Test BOP equipment. Test witness waived by AOGCC inspector John Crisp, All tests pass. 14:30 - 17:00 2.50 DRILL STAB PROD1 M/U Sperry orienter (surface test) and Sperry MWD in BHA #14. 17:00 - 18:30 1.50 DRILL LMWD PROD1 RIH w/BHA #14, OAL = 62.06'. Shallow hole test MWD as running in hole to 1600', Can not get signal. Deduce tool problem. 18:30- 19:10 0.67 DRILL LMWD PROD1 POH to change MWD, 19:10- 20:15 1.08 DRILL LMWD PROD1 Change out Sperry MWD. 20:15 - 22:10 1.92 DRILL STAB PROD1 RIH w/BHA #14. Shallow test at 300' MWD checks out good, Continue RIH, 22:10 - 22:40 0.50 DRILL STAB PROD1 Log GR tie-in -4' correction. 22:40 - 23:59 1.32 DRILL ORNT PROD1 Orienter (Sperry) failing to respond in openhole or cased hole. Prep to TOH. 2/4/2001 00:00 - 01:30 1.50 DRILL ORNT PROD1 TOH f/Sperry orienter. 01:30- 04:15 2.75 DRILL ORNT PROD1 Change out Sperry orienter and surface test same. Change out non-rotating joint on CT. 04:15 - 06:00 1.75 DRILL ORNT PROD1 TIH and shallow test MWD at 400', Continue TIH. 06:00- 06:30 0.50 DRILL ORNT PROD1 Log GR tie-in. (-6') 06:30 - 08:00 1.50 DRILL ORNT PROD1 Attempt to orient in open hole, no success. Pull up into casing. No luck. 08:00- 10:30 2.50 DRILL ORNT PROD1 ;POH for orienter. 10:30 - 11:50 1.33 DRILL ORNT PROD1 Trouble shoot BHA. Surface test of orienter is good, equalizing port is clear, orifice is good, surface test another orienter drop upper flex-sub. Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 8 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code ,,. 2/4/2001 11:50 - 13:30 1.67 DRILL ORNT PROD1 RIH w/BHA. SHT - 300', OK. SHT 4000', OK, Can not pass window. 13:30 - 14:45 1.25, DRILL ORNT PROD1 Orient TF around the clock. Finally pass window high side. 14:45 - 15:15 0.50 DRILL ORNT PROD1 Log GR tie in to pip-tag. (-11') 15:15 - 18:00 2.75 DRILL STAB PROD1 Tag bottom at 9626'. Orient tool face to 70L. Only getting 10degree clicks sometimes. Can't orient in casing or may not get past tubing tail at whipstock. 18:00 - 19:05 1.08 DRILL STAB PROD1 Directional drill w/TF 90-95L to 9704'MD. 19:05 - 21:40 2.58 DRILL STAB PROD1 Getting little to no responce from orienter. Plan is to TOH change out "non-locking" orienter for a "locking" type. Also reduce bleed sub nozzle to 11/32" from 13/32". 21:40 - 23:59 2.32 DRILL STAB PROD1 TOH 2/5/2001 00:00- 00:15 0.25 DRILL ORNT 'PROD1 TOH, 00:15- 00:30 0.25 DRILL ORNT PROD1 Hold PJSM and ops. review concerning BHA handling. 00:30 - 01:30 1.00 DRILL ORNT PROD1 P/U Sperry "locking" orienter and change bleed-sub internal jet/nozzle from 13/32" to 11/32". (-additional 500 psi circ. pressure) 01:30 - 01:45 0.25 DRILL ORNT PROD1 TIH to 400' shallow hole test MWD - okay. TIH 01:45 - 03:15 1.50 DRILL ORNT PROD1 Continue TIH w/BHA #15 64.67'. Touble getting through window. 03:15 - 03:40 0.42 DRILL ORNT PROD1 Orient f/50R to 100R. Pass through window with 100R TF. 03:40 - 04:00 0.33 DRILL ORNT PROD1 Tie-in GR at 8880' -5' correction. 04:00 - 05:60 1,83 DRILL ORNT PROD1 RIH and orient TF to 100L. Allowing more time for tool to cycle, 05:50 - 06:30 0.67 DRILL STAB PROD1 Drilling ahead in Z4 - 130 fph. ROP slows, Stacking weight. Perhaps unconsolidated sand in lower zone 4. 9760' 06:30- 07:00 0.50 DRILL STAB PROD1 Short trip to improve weight transfer. 07:00 - 10:30 3.50 DRILL STAB PROD1 Drill to 9819'. Stacking and stalling, getting a few feet at a time, 10:30 - 11:30 1.00 DRILL STAB PROD1 Wiper trip to window, Hole in good condition. 11:30 - 13:30 2.00 DRILL STAB PROD1 Drill ahead through Z-4, Some shale/silt stringers may be preventing smooth weight transfer. 2.8 bpm, 3400/3800 ctp, 12k# string wt on bottom drilling, Losing @ 8 bph. 13:30- 14:00 0.50 DRILL STAB PROD1 Shorttrip. 14:00- 14:45 0.75 DRILL STAB PROD1 Drill ahead slowly, 14:45 - 15:15 0,50 DRILL STAB PROD1 Orient tool face around the clock. Short cycle-time = 1 for 1 clicks. (orienting process back in business) 15:15 - 16:30 1.25 DRILL STAB PROD1 Drill ahead to 9911' with frequent pick-ups for lack of motor work/weight transfer. 16:30- 17:45 1.25 DRILL STAB PROD1 Wiper trip to window. 17:45 - 18:10 0.42 DRILL STAB PROD1 Try to drill ahead. Looks like bit is toast. 20% chert in last sample. Drilled to 9914'. 18:10-21:00 2.83 DRILL STAB PROD1 Pullout of hole fortri-cone bit. 21:00- 22:20 1.33 DRILL STAB PROD1 Have PJSM. Change out bit and MWD 22:20 - 23:59 1.65 DRILL STAB PROD1 TIH w/BHA #16 64.64' to 400'. Shallow hole test MWD - okay. TIH 2/6/2001 00:00 - 00:30 0,50 DRILL STAB PROD1 TIH, Orient 60R through window. 00:30 - 00:45 0.25 DRILL STAB PROD1 Log GR tie-in at 8880' -7 correction. 00:45 - 03:15 2.50 DRILL STAB PROD1 Orient through side track, TIH and orient 134L TF to drill ahead. 03:15 - 09:30 6.25 DRILL STAB PROD1 Tag bottom at 9925'. Correct TD. Drilling ahead 2.7/2,6bpm, 3800 ctp, 4.5K wob. Pick up off bottom to get surveys. Drill 5 hours on tri-cone bit to 10023'. 09:30 - 11:45 2.25 DRILL STAB PROD1 Pull out of hole for bit. 11:45- 12:20 0.58 DRILL STAB PROD1 L/D BHA# 16 12:20 - 14:15 1.92 DRILL STAB PROD1 M/U BHA # 17, Sperry Resistivity, Surface test failed of Sperry directional package. Stand by for replacement tool. Lay down failed directional package, 14:15 - 15:45 1.50 DRILL LMWD PROD1 ;Wait for Sperry Directional package. 15:45- 16:30 0.75 DRILL STAB PROD1 M/U BHA#17. OAL= 89.98'. Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 9 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations 2/6/2001 16:30 - 18:45 2.25 DRILL STAB PROD1 RIH w/BHA # 17. Shallow hole test good. Orient to get through window. 18:45 - 19:30 0.75 DRILL STAB PROD1 Log GR Tie in. Corrected -6'. 19:30-20:00 0.50 DRILL STAB PROD1 Orienting 20:00-21:10 1.17 DRILL STAB PROD1 RIH, Orienting 21:10- 00:00 2.83 DRILL STAB PROD1 Drilling at 2.4 bpm/3480 psi/97L. Drill to 10064'. 2/7/2001 00:00 - 01:00 1.00 DRILL STAB PROD1 Drill ahead. 2.5/3550. Received new mud. 01:00- 03:00 2.00 DRILL STAB PROD1 Drillto 10090'. 2.5/3600. Mud losses 26 BPH, 03:00-05:30 2.50 DRILL STAB PROD1 Drillto 10123'. 05:30 - 07:45 2.25 DRILL STAB PROD1 Wiper trip to the window, Wait for mud volume, 07:45 - 10:30 2.75 DRILL STAB PROD1 Drill ahead. Losing 20-30 bph. Pumping 2.5 bpm, 3800 ctp, 19,5k# string wt on bottom, ROP ~ 10-20 fpm. ROP trending on an increase as BHA clears Z-3. 10:30- 11:30 1.00 DRILL STAB PROD1 Wiper trip. Mud losses @ 25bph. 11:30 - 12:30 1.00 DRILL STAB PROD1 Circulate at Iow rate to minimize losses while waiting on load of mud, 12:30- 14:00 1.50 DRILL STAB PROD1 Drilling ahead f/10145'. Pumping 2.4/1.9 bpm returns, 3500 ctp, 17k# string weight. 14:00- 15:10 1.17 DRILL STAB PROD1 Drill to 10186'. Get one orientation click to 50L. 15:10- 18:00 2.83 DRILL STAB PROD1 Drill ahead inZ-2. 18:00 - 19:30 1,50 DRILL STAB PROD1 Drill ahead. 2.5/ROP still Iow. Bit stalling. Looking for shale marker. 19:30-20:30 1.00 DRILL STAB PROD1 Orienting 20:30 - 23:30 3.00 DRILL STAB PROD1 Drilling ahead. 2.6/3600/56L. Stalling several times. Not much progress. Low ROP 15 FPH. Drill to 10288'. 23:30- 00:00 0.50 DRILL STAB PROD1 POH to change out bit. 2/8/2001 00:00 - 02:00 2.00 DRILL STAB PROD1 Continue POH. Note, still plenty of chert in last sample. 02:00 - 03:40 1.67 DRILL STAB PROD1 OOH. Bit slightly undergauge (3.73"), Slightly worn on cutters. Change out bit and motor. Maintenance on Nabors pump 03:40 - 06:00 2.33 DRILL STAB PROD1 RIH with new bit BHA #18. OAL = 89.98'. Made MWD shallow test. OK. Continue RIH. 06:00- 09:00 3,00 DRILL CIRC PROD1 Repair mud pump. 09:00- 09:15 0.25 DRILL STAB PROD1 Log GR tie in, (-9'). 09:15 - 10:50 1.58 DRILL STAB PROD1 Continue to bottom. Set down at 9426'. P/U. Reduce pump to minimum rate and pass shale. 10:50- 11:30 0,67 DRILL STAB PROD1 Orient tool face to 45L, 11:30- 13:00 1.50 DRILL STAB PROD1 Drill f/10288'. ROP @ 60 fph. Pumping 2.7 bpm, 2.5 returns, 3800/3900 ctp, 17k# string weight. Drill to 10365'. 13:00 - 13:45 0.75 DRILL STAB PROD1 Orient tool face to 45L. 13:45- 14:55 1,17 DRILL STAB PROD1 Drill ahead, Losing 19 bph. Pumping 2.6 bpm, returns @ 2.2 bpm. 3800/3900 ctp, 16.5k# string wt. ROP ~ 90 fph. Land in 25P sand at 10347'. 14:55 - 16:00 1.08 DRILL PROD1 Circulate bottoms up to check for HOT. Losing mud @ 36 bph. 16:00 - 17:00 1,00 DRILL PROD1 Drill ahead toward TD w/inclination of 90 degrees. Drill to TD of 10500' ctm. 17:00 - 19:40 2.67 DRILL PROD1 Pull up hole to 10,050' and log resistivity to 9250' at 360 fpm. 19:40 - 20:30 0.83 DRILL PROD1 PU to window and log GR tie in (+4.5'). 20:30 - 21:45 1.25 DRILL PROD1 RIH at minimum rate. Pass through 9400'-9500' w/o problems. Continue RIH 21:45 - 23:00 1.25 DRILL PROD1 Tag TD @10503' (8952' TVD), Pump new mud. POH. Ream from 9600' 23:00 - 00:00 1.00 DRILL PROD1 Pull bit into casing. Drop the ball for circulation sub. Pump LCM pill. Flag pipe @8500' and 6800'. POH 2/9/2001 00:00 - 01:30 1.50 DRILL PROD1 POH. Printed: 2126/2001 3:08:41 PM BP EXPLORATION Page 10 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/9/2001 01:30 - 02:10 0.67 DRILL PROD1 Stop at 1500'. Monitoring mud losses. Lost 2 bbls in 15 minutes. POH 02:10 - 05:00 2.83 DRILL PROD1 OOH. Lay down BHA. 05:00- 05:15 0.25 DRILL PROD1 PJSM. PU 2 7/8" liner. 05:15- 12:00 6.75 DRILL PROD1 PU 2 7/8" liner. 12:00 - 12:20 0.33 CASE PROD1 PJSM for making up LRT and new CT connector. 12:20 - 13:15 0.92 CASE 3ROD1 Pull test 40k#, PT 4000~. M/U to LRT. 13:15-15:10 1.92 CASE PROD1 RIHw/BHA#19. OAL=2051'. Liner= 1991.23'. Circulate .75 bpm. Correct to flag @ 8800', (-11.5') Up weight 41k#. RIH to open-hole circulating 0.3 bpm 1300# ctp. Stack weight @ 10390', 441', 450'. Tag bottom 15:10 - 16:00 0.83 CASE PROD1 Circulate 5/8" ball to release from liner. Ball on seat at 41.5 bbls. Shears @ 3800 psi, 41.8 bbls. Pick up from liner. Released from liner, 34k# up weight. 16:00 - 18:30 2.50 CEMT PROD1 Rig up cementers. Blend cement. Cement to weight @ 18:20. 18:30 - 18:45 0.25 CEMT PROD1 Hold PJSM with all personnel. 18:45 - 19:20 0.58 CEMT PROD1 Flood and pressure test cementers. 19:20 - 21:00 1.67 CEMT PROD1 Pump 33.5 Bbls 15.8ppg Latex cement into the reel. 1.5 bpm in, 1.3 bpm returns. Launch Pee Wee plug. Chase with 1.5 ppb Biozan. 1.4 bpm in, 1.1 bpm returns. Zero return MMM and switch returns into Pit 3 when cement rounds shoe. Getting ~ 70% returns. Pee Wee dart lands on calculated displacement of 49 bbls. Shears LWD @ 3800 psi. Reduce rate as LWD approaches landing collar. No bump at calculated volume. Pump 1/2 bbl extra, no bump. Shut down, check floats. Holding. 24 bbls returns puts 1 bbl cement above top of liner. Pressure up to 400 psi. Pick up CT. Seals come free at 49k# up weight, pump remaining Biozan and circulate out above TOL. Switch to 1% KCL. Returns improving to 80%. Jet Biozan down to TOL. Check returns of @ 85+%. 21:00 - 23:15 2.25 CEMT PROD1 Pull out of hole jetting @ 1.5 bpm. Get some cement returns to surface. Recover 290 Bbls mud and send to MI for reconditioning. 23:15 - 00:00 0.75 CEMT PROD1 OOH. Back on well wash BOP. 2/10/2001 00:00 - 00:30 0.50 CEMT PROD1 Wash BOP's. 00:30 - 01:00 0.50 CEMT PROD1 Set injector on back deck. 01:00 - 01:15 0.25 CEMT PROD1 PJSM on PU Hydrill 01:15 - 02:15 1.00 EVAL PROD1 MU logging tools. 02:15 - 08:00 5.75; EVAL PROD1 MU CS Hydrill. Fluid level static in well. 08:00 - 08:30 0.50 EVAL PROD1 Displace methanol from Coil. M/U BHA to Coil. 08:30 - 10:00 1.50 EVAL PROD1 Run in hole w/BHA #19. OAL=2124.81'. Circulating KCL @ 1/2 bpm getting 100% returns. 10:00 - 13:30 3.50 EVAL PROD1 Log down from 8400' at 30 fpm. Set down on LWD @ 10,460' CTM. LWD expected to be at 10,466'. Log up at 30 fpm. Run back to bottom and lay in 100kLSRV new Flopro for perforating. 13:30 - 15:10 1.67 EVAL PROD1 POH. Swap coil to methanol. Getting 1 for 1 returns. 15:10 - 15:40 0.50 EVAL PROD1 Shut in choke and pressure up well head pressure to 500 psi. Bleeding slightly. Pressure up well head to 1000 psi. Bleeds to 500 psi in 8 minutes. Inner annular pressure stable at 270 psi indicating liner lap test fails. 15:40 - 17:45 2.08 EVAL PROD1 Bleed well head pressure and prepare to rig off well. Notice slight flow from well. Monitor condition and get back pressure test volume. I.A. pressure still 270 psi. Consult with Ann. Com. Eng. Bleed I.A. for 15 minutes with no pressure reduction. Pump 10 Bbls Meth/water into I.A. Printed: 2/26/2001 3:08:41 PM BP EXPLORATION Page 11 of 11 Operations Summa Report Legal Well Name: B-29 Common Well Name: B-29A Spud Date: 1/18/2001 Event Name: REENTER+COMPLETE Start: 1/18/2001 End: 2/11/2001 Contractor Name: NABORS Rig Release: 2/11/2001 Group: COIL Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Sub Phase Description of Operations Code 2/10/2001 15:40 - 17:45 2.08 EVAL PROD1 with no pressure increase. Suspect potential tubing x I.A. problem. Notify Wells and Ann. Com. representatives. Receive 24 hour extension from AOGCC inspector Jeff Jones to finish well without weekly BOP test. 17:45 - 18:00 0.25 EVAL PROD1 Resume operations. Rack back injector. Stand back CS Hydril. 18:00 - 18:15 0,25 EVAL PROD1 Pre tour safety meeting. 18:15 - 19:30 1.25 EVAL PROD1 Stand back CS Hydril, Recover MCNL tool. 19:30 - 21:30 2.00 EVAL PROD1 Finish stand back CS Hydrill. Lay down logging tools. 21:30 - 22:00 0,50 EVAL PROD1 Waiting on logs and perforating guns. Correct TD base on log. PBTD 10464'. TeL 8508'. 22:00- 22:15 0.25 PERF COMP PJSM. Discuss perforating procedures. 22:15- 00:00 1.75 PERF COMP PU guns. PU CS Hydrill 2/11/2001 00:00 - 02:00 2.00 PERF COMP Ice plug coil. Surge pump to break free w/o luck. 02:00 - 02:15 0,25 PERF COMP Start cutting coil, Cut 144'. 02:15 - 02:30 0.25 PERF COMP Wait on Baker for coil connectors. 02:30 - 03:30 1,00 PERF COMP Pull test on coil connector. P/T. OK. 03:30 - 03:50 0.33 PERF COMP Displace coil w/water 03:50 - 04:20 0.50 PERF COMP Stab injector. RIH w/guns 04:20 - 06:00 1.67 PERF COMP RIH w/guns. Tag TD at 10465.5'. Correct to 10464', P/U 14' for bottom shot at 10,450'. 06:00 - 06:45 0.75 PERF COMP Drop ball. Circulate KCL at 2.5 bpm. Ball on seat at 51 bbls away. Pressure up to 2800 psi. Ball seat shears. Pick up free with normal up weight of 40k#. No fluid loss indication. Circulate 1/2 bpm. Shot 10370' to 10450' at 6 spf. 06:45 - 09:00 2.25 PERF COMP Pull out of hole circulating 1/2 bpm. 09:00 - 14:00 5.00 PERF COMP Rack and set down injector. Lay down wash pipe. Lay down guns, All shots fired. 14:00 - 15:00 1,00 PERF COMP Make up nozzle for freeze protecting well. 15:00 - 16:00 1.00 PERF COMP RIH w/nozzle. BHA #21, OAL 6.29'. Circulate out well bore from 2000' with 60/40 methanol water. Clean out pits. 16:00 - 16:30 0.50 PERF COMP Well dead. Set BPV in well, 16:30 - 17:30 1.00 RIGD COMP Clean pits. Pick up coil unit. 17:30 - 20:00 2.50 RIGD COMP Blow down reel with N2. 20:00 - 23:00 3.00 RIGD COMP Install cap, P/T OK. Rig release at 23:00, Printed: 2/28/2001 3:08:41 PM TREE = 4 CIW J WELI'HEAD= MCEVOY ACTUATOR= ' .... BAKER 3F. 'ELEV '= .... 43'.95 KoP .... = ........................ 400.0; Max'Angle" 91'@ i0450, D~tum-M-D-~.. .......... -i-1~500u Datum TVD= 8951' 13-3/8"CSG,72#, L-80, 0.1481 bpf, ID= 12.347 r~---J 2683, ~L ]~ 2683' B-29A ( I SAFETY NOTES 2130' J--Isssv OTIS LAND NIP, ID:3.813" I GAS LIFT MANDRELS TYPEMANI LATCHI c~c° I ~< I CA~o I RK I C~MCO IRK I C~OI ~< I C~MCO IRK I CAMCO JRK J IMinimum ID = 2-7/8"LINER 2.441" @ 8955' ITOP OF 7" LNR Jd 8,~]~' J I 4-1/2"LNR, 12.6#,L-80, 0.0152 bpf,ID=3.953 Jd 8593' 9-5/8" LNR, 47#, L-80, 0.0732 bpf, ID=8.681 ]'"[ 8800' 8371' I~SWS NIP, ID=3.813" I 8439' J'"~ BKR PBR, ID= 3.875" J 8440' Id9 5/8" PKR, ID=-4.750" J J 8448' l--14 1/2" SWS NIP, ID=3.813" I 8508' J~TOP 3-3/16" LINER, ID=3" TO 2.8" J 8582' J--14 1/2" SWS NIP, ID=3.813" J 8593' I-Iw/~,~I I ~8o. I-I~'M~I IWH'~STOCKI--t MILLOUT, WINDOW 8851' - 8857' I J 8930' J~ 3-3/16" X 2-7/8" CROSSOVER J PERFORATION SUMMARY REF LOG: BHCS 1/25/86 ANGLE AT TOP PERF: 186@ 10070' I Note: Refer to Production DB for historical perf data IS~EJ SPFj INTERVAL I Opn/gqz J DATE I ,,,2,,,, I 6 I 10370'-10450'I 0 I 02/11/0tj I F~T~, Id 9448' I J 7" LNR, 29#, L-80, 0.0371 bpf, ID=-6.184 J-'l 9500' J I ~T,~J I ~0,464' J 3.75" OPEN HOLE T.D. J ~ 10,503' DATE REV BY COMMBq'I'S 1/28/1986 MCBRIDE ORIGINAL COMPLETION 5/25/1992 FARGO ROW/AUDI ~4 1/4/2001 SIS-MWH CONVERTED TO CANVAS(ADDED SIDETRACK INFO) 02/11/01 A. KIRK C.T. SIDETRACK PRUDHOE BAY UNIT WELL: B-29A PERMIT No: 186-0140 APl No: 50-029-21523-01 Sec. 31, 11N, 14E BP Exploration (Alaska) 01-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well B-29A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,775.00' MD 8,848.00' MD 10,503.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~...~.s..~ 0;ti 8[ Gas Cons. comm~ssio~ ~chomge DEFINITIVE North Slope Alaska- Alaska Drilling & Wells PBU_WOA B Pad, Slot B-29 B-29A Surveyed: 8 February, 2001 SURVEY REPORT March, 2001 Your Ref: API500292152301 Surface Coordinates: 5950245.00 N, 663733.00 E (70° 16' 13.4233" N, Kelly Bushing: 81.90fl above Mean Sea Level 148° 40' 32.8008" W) A Halliburton Company Survey Ref: svyf0757 Sperry-Sun Drilling Services Survey Report for B-29A Your Ref: API500292152301 Surveyed: 8 February, 2001 DEFINITIVE North Slope Alaska Measured Depth (ft) 8775.00 8800.00 8848.00 8905.00 8933.00 Incl. 16.050 16.370 16.370 29.400 36.500 45.700 57.900 61.980 67.900 85.300 89.100 84.600 82.300 82.000 80.200 76.900 74.400 74.400 74.100 73.200 8967.00 9007.00 9025.00 9059.00 9121.00 9148.00 9176.00 9207.00 9236.00 9267.O0 9306.00 9338.00 9376.00 9403.00 9446.00 Azim. 209.703 210.500 210.500 227,600 240.300 244.800 254.700 254.210 249.100 244.200 242,700 240.300 234.300 230.800 226.200 220.200 213.500 206.500 200,200 193,200 Sub-Sea Depth (fi) 8440.55 8464.56 8510.61 8563.07 8586.57 8612.17 8636.90 8645.92 8660.32 8674.64 8675.96 8677.50 8681.04 8685.00 8689.80 8697.54 8705.48 8715.71 8723.05 8735.17 Vertical Depth 8522.45 8546.46 8592.51 8644.97 8668.47 8694.07 8718.80 8727.82 8742.22 8756.54 8757.86 8759.40 8762.94 8766.90 8771.70 8779.44 8787.38 8797.61 8804.95 8817.07 9485.00 76.000 182.600 8745.55 8827.45 9514.00 79.700 174,900 8751.66 8833.56 9541.00 82.300 169.300 8755.89 8837.79 9585.00 82.200 163,300 8761.83 8843.73 9622.73 83.590 160,070 8766.50 8848.40 9656.33 86.130 150.860 8769.51 8851.41 9693.73 89.300 147.690 8771.00 8852.90 9723.33 88.420 144.530 8771.59 8853.49 9756.13 86.570 139.780 8773.03 8854.93 9795.53 84.810 128,880 8776.00 8857.90 Local Coordinates Northings Eastings (~t) (ft) 1500.37 S 19.85W 1506.40 S 23.35W 1518.06 S 30.22W 1534.50 S 44.70W 1543.28 S 57.04W 1553.50 S 76.88W 1564.12 $ 106.33W 1568.30 S 121.34W 1578.01S 150.53W 1601.90 S 205.64W Global Coordinates Northings Eastings (ft) (ft) 5948744.56 N 663745.79 E 5948738.45 N 663742.43 E 5948726.64 N 663735.82 E 5948709.89 N 663721.69 E 5948700.84N 663709.55 E 5948690.20 N 663689.93 E 5948678.94 N 663660.72 E 5948674.44N 663645.81E 5948664.09N 663616.83 E 5948639.00 N 663562.26 E 1613.95 S 229.76W 5948626.43 N 663538.41E 1627.29 S 254.32W 5948612.56 N 663514.14 E 1643.92 S 280.22W 5948595.38 N 663488.61E 1661.38 S 303.03W 5948577.42 N 663466.19 E 1681.67 S 325.96W 5948556.64 N 663443.70 E 1709.50 S 352.12W 5948528.24N 663418.16 E 1734.29 S 370.70W 5948503.06 N 663400.11E 1765.96 S 388.99W 5948470.99 N 663382.52 E 1789.81S 399.29W 5948446.93 N 663372.74E 1829.30 S 411.14W 5948407.19 N 663361.75 E 1866.48 S 416.27W 5948369.91N 663357.43 E 1894.79 S 415.64W 5948341.61N 663358.67E 1921.19 S 411.98W 5948315.30 N 663362.92 E 1963.53 S 401.65W 5948273.20 N 663374.15 E 1999.07 S 389.89W 5948237.92 N 663386.69 E 2029.47 S 376.01W 5948207.83 N 663401.23 E 2061.59 S 356.92W 5948176.13 N 663421.02 E 2086.15 S 340.42W 5948151.93 N 663438.05 E 2112.02 S 320.32W 5948126.51N 663458.70 E 2139.44 S 292.26W 5948099.71N 663487.35 E Dogleg Rate (°/lOOff) 1.56 0.00 25.44 35.26 28.41 36.11 22.79 22.10 29.09 15.13 18.21 20.61 12.00 15.77 17.29 21.73 17.74 22.48 15.76 27.16 28.92 22,63 13.51 9.26 28.33 11.98 11.08 15.53 27.94 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 1487.76 Tie On Point 1493.34 1504.12 Window Point 1518.75 1526.03 1533.86 1540.96 1543.36 1549.59 1566.88 1576.03 1586.40 1599.88 1614.56 1632.03 1656.62 1679.06 1708.38 1730.85 1768.69 1805.01 1833.21 1859.86 1903.11 1939.78 1971.60 2005.73 2032.05 206O.O9 2090.60 · 1 March, 2001 - 15:50 Page 2 of 4 DrillQuest 2.00.08.002 Sperry-Sun Drilling Services Survey Report for B-29A Your Ref: APi500292152301 Surveyed: 8 February, 2001 North Slope Alaska Measured Depth Incl. ' Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Easfings Northings Eastings (ft) (ft) (ft) (rt) (ft) (ft) 9830.13 83.140 126.770 8779.63 8861.53 2160.54s 265.09w . 5948079.21N 663514.98 E 9864.33 81.910 121.850 8784.08 8865.98 2179.65 S 237.09W 5948060.71 N 663543.38 E 9890.33 79.630 118.160 8788.25 8870.15 2192.48 S 214.87W 5948048.37 N 663565.88 E 9932.13 73.120 114.640 8798.10 8880.00 2210.54 S 178.52W 5948031.10 N 663602.61 E 9970.33 66.530 109.020 8811.27 8893.17 2223.90 S 145.28W 5948018.47 N 663636.13 E 10006.34 62.030 106.230 8826.90 8908.80 2233.73 S 114.38W 5948009.31N 663667.24E 10039.74 62.110 100.060 8842.56 8924.46 2240.44 S 85.66W 5948003.23 N '663696.10 E 10070.14 61.320 91.250 8856.98 8938.88 2243.08 S 59.06W 5948001'.17 N 663722.75 E 10098.14 61.320 86.490 8870.43 8952.33 2242.59 S 34.51W 5948002.19 N 663747.28 E 10127.54 63.440 81.560 8884.06 8965.96 2239.87 S 8.62W 5948005.47 N 663773.11 E 10158.74 66.340 75.740 8897.31 8979.21 2234.30 S 19.06E 5948011.64N 663800.66E 10190.14 67.670 68.340 8909.59 8991.49 2225.39 $ 46.53 E 5948021.15 N 663827.93 E 10221.14 70.040 63.760 8920.78 9002.68 2213.65 S 72.94 E 5948033.46 N 663854.08 E 10251.74 73.480 56.010 8930.37 9012.27 2199.06 S 98.04E 5948048.59 N 663878.86 E 10287.95 76.650 50.540 8939.70 9021.60 2178.14 $ 126.06E 5948070.11N 663906.41E 10317.55 80.000 47.020 8945.70 9027.60 2159.04 S 147,85 E 5948089.68 N 663927.79 E 10358.15 85.550 39.270 8950.81 9032.71 2129.68 S 175.35 E 5948119.64N 663954.64E 10388.95 87.490 32.920 8952.68 9034.58 2104.85 S 193.45 E 5948144.86 N 663972.20 E 10419.35 90.840 28.340 8953.12 9035.02 2078.71S 208.93 E 5948171.33 N 663987.10 E 10449.95 91.890 20.060 8952.39 9034.29 2050.83 $ 221.46 E 5948199.48 N 663999.02 E 10477.55 90.310 13.540 8951.86 9033.76 2024.43 $ 229.43 E 5948226.04 N 664006.42 E 10503.00 90.310 13.540 8951.72 9033.62 1999.68 S 235.39 E 5948250.91N 664011.84E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.753° (03-Feb-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 173.286° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10503.00ft., Dogleg Rate (°llOOft) 7.75 14.71 16.53 17.59 22.09 14.31 16.32 25.65 14.91 16.51 19.28 22.10 15.76 26.55 17.02 16.24 23.35 21.52 18.66 27.27 24.30 0.00 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 2114.73 2136.98 2152.32 2174.52 2191.66 2205.04 2215.06 2220.79 2223.18 2223.51 2221.21 2215.57 2206.99 2195.45 2177.95 2161.52 2135.58 2113.03 2088.88 2062.66 2037.37 2013.49 Projected Survey · 1 March, 2001 - 15:50 Page 3 of 4 DrillQuest 2.00.08.002 Sperry-Sun Drilling Services Survey Report for B.29A Your Ref: API500292152301 Surveyed: 8 February, 2001 North Slope Alaska The Bottom Hole Displacement is 2013.49ft., in the Direction of 173.286° (True). Alaska Drilling & Wells PBU WOA B Pad Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8775.00 8522.45 1500.37 S 19.85 W 8848.00 8592.51 1518.06 S 30.22 W 10503.00 9033.62 1999.68 S 235.39 E Comment Tie On Point Window Point Projected Survey Survey tool program for B-29A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 10503.00 9033.62 Survey Tool Description MWD Magnetic (B-29A) 1 March, 2001 - 15:50 Page 4 of 4 DrillOuest 2.00.08.002 ALASKA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWL£$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit B-29A BP Exploration (Alaska) Inc. Permit No: 200-209 Sur Loc: 399'SNL, 1892'WEL, Sec. 31, T11N, R14E, UM Btmhole Loc. 2832'SNL, 926'WEL, Sec. 31, TI 1N, R14E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt yOu from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until'all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20/LAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice'may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner. BY ORDER OF THE COMMISSION DATED this ~.~_ 2.. ~-, .2 day of December, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA ,~1~(.~ ALASK ,JIL AND GAS CONSERVATION COM,.'..SSION( PERMIT TO DRILL ~J~J 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil 1 a. Type of work B Drill [] Redrill lb. Type of well Re-Entry [] Deepen Sen/ice Development Gas Single Zone Multiple Zone 2. Name of Operator :5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 81.90' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028310 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 399' SNL, 1892' WEL, SEC. 31, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1935' SNL, 1938' WEL, SEC. 31, T11N, R14E, UM B-29A Number 2S100302630-277 At total depth 9. Approximate spud date 2832' SNL, 926' WEL, SEC. 31, T11 N, R14E, UM 12/23/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028313, 2447' MDI No Close Approach 2560 11443' MD / 9057' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8830' MD Maximum Hole Angle 90 ° Maximum surface 2470 psig, At total depth (TVD) 8800' / 3350 psig 18. Casing Program Setting Depth Size Specifications Top Rnttom Quantity of Cement Hole Casin.q Wei.qht Grade Couplin.q Len.qth MD TVD MD TVD (include st~_~e data) 3-3/4" 2-7/8" 6.4# L-80 FL4S 2943' 8500' 8257' 11443' 9057' 168 cu ft Class 'G' 19. TOpresentbe completedwell conditionf°r Redrill,summaryRe-entry, and Deepen Operations. j~t £ ¢ £ I V E D Total depth: measured 9500 feet Plugs (measured) Cement Plug at 9200' true vertical 9216 feet Sand Plug at 9230' D~C 0 5 2000 Effective depth: measured 9200 feet Junk (measured) true vertical 8929 feet Alaska Oil & Gas Cons. Casing Length Size Cemented MD~nchorage Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2644' 13-3/8" 3255 cu ft Permafrost 'E', 465 cu ft PF 2684' 2684' Intermediate Production 8764' 9-5/8" 1760 cu ft Class 'G' 8800' 8546' Liner 959' 7" 340 cu ft Class 'G' 8541' - 9500' 8297' - 9216' Perforation depth: measured Perfs Above Sand & Cement Plug: 9102' - 9106', 9110' - 9122', 9125' - 9140', 9155' - 9175' Perfs Below Sand & Cement Plug: 9200' - 9322' true vertical Perfs Above Sand & Cement Plug: 8836' - 8839', 8843' - 8855', 8858' - 8872', 8886' - 8905' Perfs Below Sand & Cement Plug: 8929' - 9046' "~0. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Kuru, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreg~rue and correct to the best of my knowledge , Signed Dan Kara ~..., ~~'-,..,._==_._ Title CT Drilling Engineer Date .~'..~' ~,~"~'~,i. ti;' ~'~""~;~; ~'~'~ .... ~ ~;i; q~. '~;'~,~,~,';'~' ,~,~. ;w" {'' ~.~" ';~' ~'~'~ ~ ~" ~' '"~ *'~' ~ ' !I,~. ~ ~ '~ ~' ~. ~ ,"~ ~,~' , ~..~ ~ ' ', ;., ..~. iI~.......~ ',. ',,, ~:~,.1~,~{~.!~,,~, ..~.,,~ t,' .... i~;~ =~'~ ...'. '~.' , ~'.'~ .... ..~;~, ...... ~ · '...!.~ ..~t;'...,I !i .... ~ ~'~ ,~..~ ~!:'.'~',~'.' ~.~!~.'~,'.!!~I ~.~ ~ .... ~.!! ~, .. Permit Number APl Number Approve! Date _ I See cover letter '~C~_,.P-' ~ 50-029-21523-01 _ j/~- ~---~0I for other requirements Conditions of Approval: Samples Required [] Yes ~[ No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures I~ YesI~r No Directional Survey Required I~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,.J~[,,3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of _Approved By _r3 T_~¥1nr ?-.~=mn, ,r3t Comm, iss!oner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX B-29a Sidetrack Summary of Operations: B-29 is being sidetracked to target Zone 4 reserves. This sidetrack will be conducted in two phases. Phase 1: Install mechanical whipstock, P&A existing perforations: Planned for ASAP. · A Mechanical Integrity Test will be performed. · A 3.75" drift will be run. · E-line install mechanical whipstock. · Service coil will be used to cement the existing perforations and pressure test. Phase 2: Mill Window, Drill and Complete sidetrack: Planned for Dec 23, 2000. Drilling coil will be used to mill window, drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Water · Phase 2: Water for window milling, FIo-Pro (8.5 - 8.7 ppg) for drilling operatins. Disposal: · No annular injection on this Well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.4#, L-80, FL4S liner will be run from TD to approx. 8500' MD (TOL) and cemented with approx. 30 bbls. To bring the top of cement to the top of liner 8500'md. The liner will be pressure tested to 2000 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A Memory CNL will be run in cased hole. Hazards There is a medium risk of lost circulation. No faults are mapped inside the polygon 10 ppm H2S. B-29 recently tested Reservoir Pressure Res. pressure is approx. 3350psi @ 8800ss. Max. surface pressure with gas (0.1 psi/ft) to surface is 2470 psi. RECEIVED DEC 05 2000 Naska Oil & Gas Cons. Commission Anchorage (' B-29a Potential Drilling Hazards Post on Rig . Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Aisc, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S recently tested at 10 ppm from this well. Ensure H2S pit monitors and personal monitors are operational. 3. BHP is expected to be 3350psi (7.32ppg) @ 8800ss. 4. Maximum anticipated well head pressure w/full column of gas 2470psi. 5. Lost circulation risk is medium with anticipated faults near, but not in the polygon. RECEIVED DEC 05 ~000 Alaska Oil & Gas Cons. Commissio. Anchorage ! TREE: 4' ClW~ KB. ELEV = 81.90' WELLHEAD: McEVOY !""~ ~.CL BF. ELEV = 43.95' ACTUATOR: BAKER ....~ ( OTIS 'XHO')(3.813' ID) ~ ~oc~! i 13-3/8". 72fflfL k GAS LIFT MANDRELS L-80, BTRS , (CAMCO WI RK LATCH) Ne MD(BKB) TVDss 7 3017 2934 IKOP: 4000' i ' 6 5 4990 4871 MAX ANGLE: 23'15600' 6263 6047 I 4 7103 6828 ~ 3 7668 7366 7884 4-1/2', 12.6~/ft, L-80, ~ 2 8200 TDS TUBING (13-Cr) i 1 8305 7986 TUBING ID: 3.958" CAPACITY: .01522 BBL/FT ,I I----4'/2''SWS"N'PPLE I 8371 NOTE (Parker) (3.813' I D) I , CHROME TUBING 13.8,5',D) -- ~-5~- PACKER I 8440 I ( Baker"D" )(4.750" ID) 4 1/2", 12.6fflft, 13-Cr TOP OF [ 8540' ! '1 I 41/2" -sws- NIPPLE 7' ! ' i (Parker)(3.813"lD) I 8488 I LINER I I ~ 4112" "SWN"NIPPLE ,, (Parker)(3.725'lD) I 85821 I 8800' '4112"WLEGI 85031 L-80, BTRS (ELMD) I 8613 ~ MARKER JOINTI 8780'1 PERFORATION SUMMARY REF LOG: GEARHART- BHCS- 1-25-88 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8' 4 9102'- 9106' ( ~pen 7-5-94 3 3/8" 6 9110'-9122' ::)PEN 1-31-96 ,. 4 9125 - 9140' - ! 3/8" 4 9155 - 9175' 3pen 6112/94 /,Top of Cement Plug 9200' MD (est. } 3/8" 4 9277 - 9292' ::)pen 9/25/92 iii?.ii:':.:.::i.:'!':i?i i,: :i::,.::.!i: " 4 9300 - 9322' - - Top of Sand Plug 9230' ELMD 617194 ., , . ,, . , , . . . . :~,. :...'.:..:.,..:....'.::...:.: .: 7", 29~Wft, L-80, BTRS I 9500' 1 DATE REV. BY COMMENTS PRUDHOE BAY UNIT 1-28-86 McBRIDE INITIAL COMPLETION WELL: B-29 (32-31-11-14) 5-25-92 FARGO RWO/Audi ~4 APl NO: 50-029-21523 7-05-94 R. Uays AddPerfs SEC 31; TN 11N ; RGE 14E 1-31-96 DTR ~.DD PERES BP Exploration (Alaska) GAS LIFT MANDRELS (CAMCO W/ RK LATCH) N° MD(BKB) TVDss 7 3017 2934 6 4990 4871 5 6263 6047 4 7103 6828 3 7668 7366 2 8200 7884 1 8305 7986 i= TREE: 4" ClW WELLHEAD: McEVOY ACTUATOR: BAKER ('.,-29a Proposed Complet,,,n (' KB. ELEV = 81.90' BF. ELEV = 43.95' SSSV LANDING NIPPLE ( OTIS 'XHO')(3.813" ID) 13-3/8". 72#/ft, J 2683,I L-80, BTR$ 'KOP: 4000' MAX ANGLE: 23o/5600' 4-1/2", 12.6#/ft, L-80, TDS TUBING (13-Cr) TUBING ID: 3.958" CAPACITY: .01522 BBL/FT NOTE CHROME TUBING · o.o I 8840' I 7" LINER ~"~'~""~#~' [ 8800' I" L-80, BTRS Whipstock approx. 8880 MD Cement to be downsqueezed past whipstock. PERFORATION SUMMARY REF LOG: GEARHART-BHCS- 1-25-86 I INTERVAL O :)EN/SQZ'D 3 3/8] 4 9102'- 9106' 9110' -9122' 9125 - 9140' 9155 - 9175' 9277 - 9292' 9300 - 9322' C )en 7-5-94 OPEN 1-31-96 # Open 6/12/94 Open 9/25/92 ii II .- .- .':: :.:-:::..' - . '.':-": i:::::::':"":: :.:': · · · . · . · · . . · · .. -.. .." · - . .. - :..::., ..-:.. GAS LIFT MANDRELS ...(CAMCO W/ RK LATCH) Ns MD(BKB3 TVDss 7 3017 2934 6 4990 4871 5 6263 6047 4 7103 6828 3 7668 7366 2 8200 7884 I 8305 7986 4 1/2 .... SWS" NIPPLE (Parker) (3.813" I D) Baker PBR (3.875" ID) 9-5/8" PACKER ( Baker "D" )(4.750" ID) 4 1/2", 12.6#/ft, 13-Cr 4 1/2 .... SWS" NIPPLE (Parker) (3.813" ID) 4 1/2 .... SWN" NIPPLE (Parker) (3.725" ID) 4 1/2"WLEG (ELMD) 8371 8439 8440 8488 8582 8593 8613 2 7/8" Liner to be cemented to approx. 200 ft above window PBTD 7", 29#/ft, L-80, BTRS I ,9448' I I '95oo' I BP Amoco WELLPA TH DETAILS Plan #108 B-29A 500292152301 Parent We#path: B-29 Tie on MD: 8830.00 Vertical Section Origin: User Defined (0.00,0.00) Vertical Section Angle: 133,22° Rig: Nal~ors 3s Depth Reference: 40: 29 1/13/1986 00:00 81.901t REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: B-29, True North Verlical (TVD) Reference: System: Mean Sea Level SeclJon (VS) Reference: User Defined (-19.50,-1500.30) Measured Deplh Reference: 40: 29 1113/1986 00:00 81.9 Calculation Method: Minimum Curvature ANNOTATIONS No. TVD MD Annotation I 8440.55 8775.00 Tie-in Position 8493.34 8830.00 Kick off Point 3 8512,47 8850.00 1 4 8645.81 9025.76 2 5 8670.52 9121.93 3 8775.10 10127.86 8784.10 10368.6? 54 8 8835.03 10554.87 6 90 8935.10 10939.96 8935.10 11227.59 I 11 8974.75 11442.00 TD T,~IG ET DETNLS Name 'IVD *N/-S +E/-W ~ B-29ATatget#1 8'/75.00 -2340.68 -233.45 Peint 2-29ATa~geI#2 893S.00 -2447.3~ g59.~Point B-29A Poly Il o.oo -2188.55 -3~0.20 Polygon B-29A Pely 12 0.00 -22S6.20 486.5~ BPAmoco INTEQ | LEGEND Plan #108 B-29A M Magnetic Norlh: 26.80° [ ('r,:at~'O By: Brij Polni,. Date: 1~4/..'000 WclJpalh: (R-29/Plan B-29A) Azimufhs to True Norlh I I Magnetic Field I Strength: 57474nT I Contact IIlformabon. Dip Angle: 80.75° [ D~rect. (907) 267-6613 Date: 1214/2000 1 E-mad: brij.polnis@mteq.com Model: BGGM20001 Baker Hughes INTFQ: (907) 267-6600 I 8600 -1492 8400 8800 . iV.:D .. .I '18.2o ~B-20) ~ .......... . DEC 05 _. . -= _.A/ask;~ ~ii-& Gas Cons.. C~;mmissi0. .... ; : Anchorage : . ! ) B-29A TarIlet #1 I - I Plan #108 B-29A t ....... · . : ................... ¢A Terfl,t #~ IJ . . i i i [ -2388 - 1 B-29A TarIlet #1 I Tie-in Position I ' . -597 -298 0 298 597 895 ' West(-)/East(+) [ft] ..[~]. / . . ............. .................... ....__ ...... ~J ~ .................. ~ ...... ' [] IX[ ....... ........ I~-~$ ¢8:~,~ I ................. -200 0 200 400 600 800 1000 1200 Vertical Section at 133.22° [200ft/in] 1194 Plan ~108 B-29A J 1400 1600 _a__g_~lg__~~ Proposal Calculations ~ E ~' LE ~~~ Coordinat~ provided in: ~UE ~lative to Wellhead ~Q and ~AS~ STATE PLAN ~C 0 ~ ~000 Co~y: B~. ~lo~fio~ Ve~ Se~ rl~e: 134820 ~ Job ~o: Al~ka Oil & Gas Con~_ Well: B-~A ~108 Mag. De,nation: 26.870 ~ No: Aneharan~ ---~_ ~I No: 50-029-2152~01 G~d Co--ion 1.2~ D~Hed ~om B-29 ~g: No~c 1 ~p: 80.750 S~ Da~: ~eld: P~oe Bay, Alask~ ~ Hd~t: 81.~ End Date: M~ ~. ~ ~ ~ CoorS. - A~ Coo~ - ~ Do~eg Ve~l Tool Face B~d D~th ~e ~. S~sm ~ N(+)/S(-) E(+)~(-) N(+)/S(-) E(+)~(-) Seventy Se~on Co~ent~ (de~ (&~ (a) (~) Lat ~ De~. ~ Lat ~ D~. ~ (°/1~) ~ (°/l~a) (~/1~) 8775.~ 16.05 209.69 ~.55 8522.45 59~7M.71 ~37~.18 -1500.33 -19.~ 0.00 0.00 0.00 0.00 0.00 Ti~in P~ition 88~.~ 16.37 210.50 ~.56 ~.~ 59~738.59 ~3742.81 -1506.37 -22.96 1.57 1.59 35.~ 1.28 8830.~ 16.37 210.50 ~9~.M 8575.~ 59~731.21 ~3738.~ -1513.~ -27.~ 0.00 3.45 0.00 0.00 0.00 Kick off Po~t 8850.~ 17.57 210.50 8512.47 8594.37 59~726.12 ~3735.83 -1518.69 -30.21 6.00 4.74 0.00 6.00 0.00 1 88~.~ 19.56 216.71 8521.95 86~.85 59~723.~ ~37~4.13 -1521.33 -31.98 28.~ 5.26 47.88 19.85 62.15 8880.~ ~.~ 225.95 85~.52 8622.42 59~717.82 ~3729.32 -1526.85 -36.91 28.~ 5.45 41.99 22.22 ~.18 89~.~ 28.83 232.35 8558.43 8~.33 59~711.89 ~3722.70 -1532.63 ~3.65 28.~ 4.49 33.~ ~.15 31.98 8920.~ ~3.88 ~7.01 8575.51 8657.41 59~705.72 ~3714.33 -1538.61 -52.15 ~.~ 2.40 27.67 ~.25 23.31 89~.~ 39.~ ~0.57 8591.59 8673.49 59~699.37 ~37~.30 -15~.75 -62.33 ~.~ -0.82 23.~ 25.93 17.83 89~.~ ~.34 ~3.42 86~.52 8688.42 59~6~.89 ~3692.69 -1550.98 -74.~ ~.~ -5.11 20.81 26.36 14.22 8980.~ 49.67 ~5.77 8620.15 87~.05 59~6.34 ~3679.61 -1557.~ ~7.29 ~.~ -10.45 18.69 26.65 11.75 90~.~ 55.~ ~7.77 8632.36 8714.26 59~679.79 ~36~.20 -1563.47 -101.84 ~.~ -16.78 17.08 26.85 10.~ 9020.~ ~.~ ~9.53 8~3.~ 87~.94 59~673.30 ~3~9.59 -1569.62 -117.58 28.~ -~.05 15.86 27.~ 8.78 9025.76 62.~ ~0.00 8~5.81 8727.71 59~671.46 ~3~.89 -1571.36 -122.33 ~.~ -26.32 14.95 27.~ 8.1~ 2 9~.~ ~.83 ~1.23 8652.~ ~33.97 59~6.96 ~3632.92 -1575.~ -1~4.39 28.~ -32.20 16.35 26.91 8.6~ 90~.~ 71.~ ~2.84 8659.~9 8741.29 59~0.84 ~3615.35 -1581.34 -152.09 ~.~ ~1.17 15.81 26.98 8.04 9080.~ 76.~' ~4.35 86~.92 87~.82 59~655.02 ~3597.05 -1586.76 -170.52 ~.~ -50.89 15.22 27.05 7.54 91~.~ 82.05 ~5.79 86~.62 8750.52 59~9.55 ~3578.18 -1591.82 -189.51 ~.~ -61.~ 14.80 27.~ 7.21 9121.93 88.~ ~7.33 8670.52 8752.42 59~.01 ~3557.~ -1596.90 -210.74 ~.~ -73.~ 14.55 27.11 7.02 3 91~.~ 87.94 ~6.87 8670.63 8752.53 59~3.26 ~3554.~ -1597.58 -213.73 15.~ -74.96 -97.88 -2.05 -14.87 9150.~ 87.43 ~3.16 8671.~ 8753.54 59~636.27 ~3530.11 -1~.~ -237.86 15.~ -88.12 -97.86 -2.03 -14.87 9175.~ 86.93 ~9.43 8672.~ 8754.77 59~627.76 ~35~.~ -1612.05 -261.50 15.~ -99.86 -97.71 -1.99 -14.89 92~.~ 86.45 ~5.71 8674.32 8756.22 59~617.74 ~3483.79 -1621.57 -2~.57 15.~ -110.15 -97.53 -1.94 -14.90 92~.~ 85.98 ~1.98 8675.~ 8757.87' 59~6.26 ~3461.65 -1632.56 -3~.96 15.~, -118.94 -97.32 -1.88 -14.91 ~50.~ 85.52 238.25 8677.82 8759.72 59~593.37 ~3~.31 -1~.98 -3~.57 15.~ -126.18 -97.07 -1.81 -14.93 9275.~ 85.~ 234.51 8679.87 ~61.77 59~579.13 ~3419.88 -1658.78 -349.31 15.~ -131.85 -96.79 -1.73 -14.95 93~.~ ~.~ ~0.77 8682.10 87~.~ 59~563.60 ~34~.42 -1673.88 -369.10 15.~ -135.92 -96.49 -1.65 -14.97 93~.~ M.29 227.02 86M.50 87~.~ 59~546.84 ~3~82.~ -1690.~ -387.85 15.~ -138.38 -96.15 -1.56 -14.99 9350.~ 83.92 223.27 8687.07 87~.97 59~528.93 ~33~.80 -1707.78 ~05.47 15.~ -139.21 -95.79 -1.46 -15.01 9375.~ 83.58 219.51 8689.79 8771.69 59~509.93 ~33~.78 -1726.42 ~21.90 15.~ -138.42 -95.41 -1.36 -15.~ 94~.~ 83.27 215.75 8692.~ 8774.56 59~9.94 ~3334.05 -1746.08 ~37.06 15.~ -136.00 -95.~ -1.25 -15.05 94~.~' 82.98 211.98 8695.65 8777.55 59~9.05 ~3320.67 -1766.69 ~50.89 15.~ -131.97 -94.57 -1.14 -15.~ 9450.~ 82.7~ 208.21 8698.76 8780.~ 59~7.32 ~3308.71 -1788.15 ~63.33 15.~ -126.34 -94.12 -1.02 -15.08 9475.~ 82.51 2~.~ 8701.97 8783.87 59~4~.87 ~3298.20 -1810.36 ~74.32 15.~ -119.13 -93.65 -0.89 -15.10 95~.~ 82.32 200.66 8705.27 8787.17 59~1.79 ~3289.20 -1833.~ ~3.83 15.~ -110.38 -93.16 -0.76 -15.11 9525.~ 82.16 196.88 ~.65 8790.55 59~378.18 ~3281.74 -1856.69 ~91.79 15.~ -1~.13 -92.~ -0.63 -15.13 9550.~ 82.~ 193.10 8712.~ 8793.99 59~354.13 ~3275.86 -1880.61 d98.20 15.~ -88.42 -92.15 -0.50 -15.14 9575.~ 81.95 189.31 8715.57 ~.47 59~329.75 ~3271.58 -19~.89 -5~.01 15.~ -75.29 -91.63 -0.36 -15.14 96~.~ 81.89 185.52 8719.~ 88~.99 59~305.15 ~32~.92 -1929.43 -5~.20 15.~ -60.82 -91.10 -0.22 -15.15 96~.~ 81.87 181.73 8722.62 88~.52 59~0.43 ~3267.90 -1954.12 -5~.77 15.~ ~5.~ -90.57 -0.08 -15.15 Mess. Incl. TRUE TVD TVD Coords. - ASP Coords. - TRUE Dogleg Vertical Tool Face Build Turn Depth Angle Azi. Subse~ RKB - N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severit~ Section Comment~ (de~) (de~) (ft) (ft) Lat. (Y) DeB. CA') Lat. (Y) DeB. CA) (°/100n) TIP (°1100ft) (°1100~t) 9650.00 81.89 177.95 8726.15 8808.05 5948255.69 663268.50 -1978.87 -507.70 15.00 -28.05 -90.04 0.06 -15.15 9675.00 81.94 174.16 8729.67 8811.57 5948231.05 663270.74 -2003.56 -505.99 15.00 -9.90 -89.50 0.20 -15.15 9700.00 82.02 170.37 8733.16 8815.06 5948206.60 663274.61 -2028.08 -502.66 15.00 9.32 -88.97 0.34 -15.14 9725.00 82.14 166.59 8736.61 8818.51 5948182.46 663280.08 -2052.34 -497.72 15.00 29.54 -88.44 0.48 -15.14 9750.00 82.29 162.81 8739.99 8821.89 5948158.72 663287.13 -2076.23 -491.18 15.00 50.66 -87.92 0.61 -15.13 9775.00 82.48 159.03 8743.31 8825.21 5948135.49 663295.74 -2099.64 -483.08 15.00 72.60 -87.41 0.74 -15.11 9800.00 82.70 155.25 8746.53 8828.43 5948112.87 663305.86 -2122.48 -473.45 15.00 95.26 -86.90 0.87 -15.10 ,.. 9825.00 82.95 151.48 8749.66 8831.56 5948090.95 663317.46 -2144.65 -462.34 15.00 118.54 -86.42 1.00 -15.08 ~ 9850.00 83.23 147.71 8752.66 8834.56 5948069.83 663330.48 -2166.05 -449.78 15.00 142.35 -85.95 1.12 -15.07 ~ ~ ~ U! 9875.00 83.54 143.95 8755.55 8837.45 5948049.59 663344.86 -2186.59 -435.84 15.00 166.58 -85.49 1.24 -15.05 ~ 9900.00 83.87 140.20 8758.29 8840.19 5948030.34 663360.55 -2206.19 -420.56 15.00 191.13 -85.06 1.35 -15.03 ~ 9925.00 84.24 136.44 8760.88 8842.78 5948012.13 663377.49 -2224.76 -404.03 15.00 215.89 -84.65 1.45 -15.01 9950.00 84.62 132.69 8763.31 8845.21 5947995.07 663395.58 -2242.22 -386.31 15.00 240.76 -84.26 1.55 -14.99 ~ ~ ' 9975.00 85.03 128.95 8765.56 8847.46 5947979.21 663414.77 -2258.49 -367.47 15.00 265.63 -83.89 1.64 -14.97 10000.00 85.47 125.21 8767.63 8849.53 5947964.62 663434.96 -2273.51 -347.60 15.00 290.40 -83.56 1.72 -14.95 10025.00 85.92 121.48 8769.51 8851.41 5947951.38 663456.07 -2287.21 -326.78 15.00 314.95 -83.25 1.80 -14.93 10050.00 86.38 117.75 8771.19 8853.09 5947939.53 663478.02 -2299.54 -305.10 15.00 339.19 -82.97 1.87 -14.92 10075.00 86.87 114.03 8772.66 8854.56 5947929.13 663500.70 -2310.43 -282.65 '15.00 363.01 -82.72 1.93 -14.90 10100.00 87.36 110.30 8773.92 8855.82 5947920.22 663524.01 -2319.85 -259.53 15.00 386.31 -82.50 1.98 -14.89 10125.00 87.87 106.59 8774.96 8856.86 5947912.83 663547.87 -2327.75 -235.84 15.00 408.98 -82.31 2.03 -14.88 10127.86 87.93 106.15 8775.10 8857.00 5947912.15 663550.72 -2328.50 -233.00 15.37 411.56 -82.00 2.14 -15.23 4 10150.00 87.89 102.83 8775.91 8857.81 5947907.08 663572.25 -2334.03 -211.58 15.00 430.96 -90.67~ -0.16 -15.01 10175.00 87.86 99.07 8776.83 8858.73 5947902.87 663596.87 -2338.78 -187.06 15.00 452.08 -90.551 -0.13 -15.01 10200.00 87.84 95.32 8777.77 8859.67 5947900.28 663621.72 -2341.91 -162.28 15.00 472.28 -90.41 -0.09 -15.01 10225.00 87.83 91.57 8778.71 8860.61 5947899.32 663646.67 -2343.41 -137.34 15.00 491.48' -90.27 -0.05 -15.01 10250.00 87.82 87.82 8779.66 8861.56 5947900.00 663671.64 -2343.28 -112.37 15.00 509.59 -90.13 -0.01 -15.01 10275.00 87.83 84.06 8780.61 8862.51 5947902.31 663696.51 -2341.51 -87.45 15.00 526.53 -89.99 0.02 -15.01 10300.00 87.84 80.31 8781.56 8863.46 5947906.24 663721.17 -2338.11 -62.71 15.00 542.24 -89.84 0.06 -15.01 10325.00 87.87 76.56 8782.49 8864.39 5947911.78 663745.53 -2333.11 -38.24 15.00 556.64 -89.70 0.10 -15.01 10350.00 87.90 72.81 8783.41 8865.31 5947918.90 663769.47 -2326.51 -14.14 15.00 569.68 -89.56 0.13 -15.01 10368.67 87.93 70.00 8784.10 8866.00 5947925.25 663787.01 -2320.54 3.53 15.02 578.47 -89.49 0.15 -15.03 5 10375.00 86.98 70.00 8784.38 8866.28 5947927.54 663792.90 -2318.38 9.47 15.00 581.32 180.00 -15.00 0.00 10400.00 83.23 70.00 8786.51 8868.41 5947936.56 663816.il -2309.86 32.87 15.00 592.54 180.00 -15.00 0.00 10425.00 79.48 70.00 8790.27 8872.17 5947945.52 663839.14 -2301.41 56.10 i5.00 603.67 180.00 -15.00 0.00 10,150.0(} 75.73 'I(}.~'X) 8'/95.¢~ 8877.54 5947954.36 ¢'~'~3861 89 -2293 (Y,~ 79.04 15.(X) 614.67 18(}.(}0 - 15.(X) 0.00 .1(H75.0.0 71.98 70.(X~ 88¢I2.59 888~,.,47 .,594796?06 - ~?:!H~4.2'1 --2284~.85- - 10J.61) 15.(.)('! 625.,19 180.00 , -15.00 . . 0.00 '["~h'l'i~, ZONE 1(}500.00 68.2'~ 70.0(i 8811.09 88.92.99 . .5~4..7.9].[.58 .~¥,39~.t7 -227~*.8t . 123:~!8... I~iCX? 6.36.07 t80.00 -15.00 0.00 MD- 125' 10525.00 (gi.48 '70.(X} 8821. ! 2 8903.02 5947979.88 ¢6392'1.51 -2268.98 145.20 15.(X) (~6.39 180.00 = 15.fX) 0.00 10550.001 ¢~,).'13 70.(X) 8832.62 8914 52 594.'19~'i.92 (~'~3948.20 ..226'1.39 166J)6 15,(X) 65639 180.00 - 15.(X) O.(X) 10554,87 ¢~O,(XJ 70.00 8835..,03 8916.93 5947989.45 ...¢~,;39..52...J 5. :2259,9..4.. 170.04 lS,(X,I ¢:;58.30 -180.00 15.00 0.00 6 ......... _.!,O..~_.O,.O0.. ..................... .6.3,3.2 ........................ 7.3.,.,I.8. ............. 8.8.5.0',..4.6 .............. _89.3..~.3.6.. ....... .59.-4.~.00~:~_ ................ ..~.~.9.8.9.~8 ........... L .......... 22...4..7..,5_2 ................. 2.0.?.:7.5 ............................. J,.O,.(Y.,) ................ 6..?...?.:2_7. .................... ~3:52 ...................................... 7,.35 ......................... 7..7.0 ............................. 10650.00 6?.09 77.10 8877.43 8959.33 5948015.15 664033.20 -2236.01 251.64 10.00 701.38 41.87 7.54 7.24 10700.00 70.93 80.52 8895.34 8977.24 5948025.18 664078.77 -2226.97 297.42 10.00 728.55 40.35 7.69 6.85 10750.00 74.84 83.79 8910.05 8991.95 5948032.71 664125.94 -2220.47 344.75 10.00 758.57 39.12 7.81 6.53 10800.00 78.79 86.93 8921.46 9003.36 5948037.69 664174.35 -2216.54 393.25 10.00 791.23 38.16 7.90 6.29 10850.00 82.78 89.99 8929.47 9011.37 5948040.08 664223.63 -2215.23 442.57 10.00 826.27 37.44 7.97 6.12 10900.00 86.78 93.00 8934.02 9015.92 5948039.86 664273.40 -2216.53 492.33 10.00 863.43 36.95 8.01 6.02 10939.96 90.00 95.40 8935.10 9017.00 5948037.77 664313.29 -2219.49 532.17 10.05 894.48 36.69 8.06 6.0~ 7 10950.00 90.00 96.40 8935.10 9017.00 5948036.95 664323.29 -2220.52 542.16 10.00 902.46 90.00 0.00 10.00 11000.00 90.00; 101.40 8935.10 9017.00 5948030.29 664372.83 -2228.26 591.54 10.00 943.75 90.00 0.00 10.00' 11050.00 90.00 106.40 8935.10 9017.00 5948019.34 664421.59 -2240.27 640.06 10.00 987.33 90.00 0.00 10.00 11100.00 90.00~ 111.40 8935.10 9017.00 5948004.18 664469.22 -2256.46 687.35 10.00 1032.88 90.00 0.00 10.00 11150.00 90.00 116.40 8935.10 9017.00 5947984.93 664515.34 -2276.72 733.04 10.00 1080.05 90.00 0.00 10.00 11200.00 90.00 121.40 8935.10 9017.00 5947961.73 664559.61 -2300.88 776.80 10.00 1128.48 90.00 0.00 10.00 , Meas. Incl. TRUE TVD TVI) Coords. = ASP Coords. - TRUE Dogleg Vertical Tool Face Build Turn Depth Angle Azi. Subsea RKB N(+)/$(-) E(+)/W(.) N(+)/S(-) E(+)/W(-) Severity Section Comment~ (der0 (de~ (ft) (iX) Lat. 00 Del,. 00 LaC (Y) Del,. 00 (°/100i~) Tn, (°/100n) (°/100n) 11227.59 90.00 124.16 8935.10 9017.00 5947947.31 664583.13 -2315.80 800.00 10.00 1155.60 90.00 0.00 9.99 8 11250.00 87.76 124.16 8935.54 9017.44 5947935.14 664601.94 -2328.38 818.54 10.00 1177.73 179.99 -10.00 0.00 11300.00 82.76 124.16 8939.67! 9021.57 5947908.07 664643.75 -2356.35 859.76 10.00 1226.92 179.99 -10.00 0.0G 11350.00 77.76 124.16 8948.13 9030.03 5947881.31 664685.10 -2384.01 900.52 10.00 1275.57 179.99 -10.00 0.0C 11400.00 72.76 124.16 8960.84 9042.74 5947855.04 664725.68 -2411.16 940.52 10.00 1323.30 179.99 -10.00 0.0G 11442.99 68.46! 124.16 8975.11 9057.01 5947833.02 664759.72 -2433.91 974.07 10.00 1363.33 -179.96 -10.00 -0.01 TD - 2613' MD C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect---- I Alignment Guide Flange ~ I I ~ _ n oo,/~ ~,,~ 7-1/16", 5M Ram Type Dual ~ ~ GateBOPE ~ ~ (~ ' ' ~ Flanged Fire Resistant ~ ~'' ~ Kelly Hose to Dual HCR Man Choke Manifold _~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ .--- 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Combination Cutter/Blinds 2-3/8" Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" I D with 2-7/8" Pipe & Slip Rams Manual Master Valve · 0.458' (5.5") rl 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger Upper Annulus Lower Annulus RECEIVED DEC 05 2000 Alaska Oil & G~s Cons. Commissio~ Anchorage DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 10;2500 CK102500I 100. O0 100. O0 HANDL',:NG INST' S/H - TERRTE HUB;)LE X4&28 HE ATTACHED CHECK 15 IN PAYMENT FOR rI~MS or=sCHmF. D AaOw. 1 OO. OO 1 OO. OO .:~ :.,~BP..~XPLOFIA.T:ION (ALASKA),~.IN~, '! .:,. ;:: ':.. AN~hO'~:'.AG~;=!A~SE~ 799519.6612 ~i~.i.i:, . . ANCHORAGE AK, 99501 WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~:~ _4//~/~ INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING WELL NAME/~- ~_...4::} ~ PROGRAM: exp -~ ~" [,,'/ /~:)/~.,.- GEOL AREA 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ............. 23. If diverter required, does it meet regulations .......... dev t,/ redrll v~ serv wellboreseg ~,~ .~_~ UNIT# ann. disposal para req ON/OFF SHORE 24...-. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation '. ............... 26. BOPE press rating appropriate; test to ~(~ ;)sig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~_~]~) DATE · ~ Work will without operation shutdown. 28. occur .......... 29. Is presen~ of H2S gas probable ................. GEOLOGY . 30. P,rmit ~n be issued wlo hydrog,n sulfide measures ..... ~. Da~a presen~e~ on .o~e.~,a~ ove~. ressure zones ....... 32. Seismic analysis of shallow gas zones ............. ,~ ~ APPR DATE 33. Seabed ~ndition suwey (if off-shorn) ......... '.. ~~ ~ ~ /~ '~,~ 34. Conta~ name/phone for weekly progress repo~s [~~ only] ~LAR DISPOSAL35. With proper ~menting records, this plan APPR DATE (A) will contain waste in a suitable receiving zonei ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface;' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlCIAnnular COMMISSION: -'I~,~+ ~1;~/o~ Commentsllnstructions: O Z O -I Ill Z -I -r' c:~soffice\wordian~iana\checklist (rev. 111011100) 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 roadability of the Well History file and to simplify finding information, informati;3n 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 Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 23 11:36:34 2001 Reel Header Service name ............. LISTPE Date ..................... 01/03/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/03/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-10030 S. LATZ KIRK / FEKET B29A 500292152301 BP Exploration (Alaska), Inc. Sperry Sun 23-MAR-01 MWD RUN 3 AK-MW-10030 S. LATZ KIRK / FEKET MWD RUN 4 AK-MW-10030 S. LATZ KIRK / FEKET JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-10030 S. LATZ KIRK / FEKET MWD RUN 6 AK-MW-10030 S. LATZ KIRK / FEKET MWD RUN 7 AK-MW-10030 S. LATZ KIRK / FEKET JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 7 AK-MW-10030 S. LATZ KIRK / FEKET SURFACE LOCATION SECTION: 31 TOWNSHIP: liN RANGE: 14E FNL: 399 FSL: FEL: 1892 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 81.90 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 13.375 2683.0 3.750 9.625 8800.0 3.750 7.000 8858.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. SPERRY-SUN DRILLING SERVICES (SSDS) REPLACED BAKER HUGHES INTEQ (BHI)DURING THE DRILLING OF THIS WELL. 2. BHI PROVIDED GAMMA RAY AND ROP DATA FROM 8835'MD TO 9594'MD. 3. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 4. NO FOOTAGE WAS MADE ON SSDS RUNS 100 AND 200 DUE TO ORIENTER FAILURES. 5. MWD RUNS 300, 400, 500 COMPRISED DIRECTIONAL AND NATURAL GAMMA PROBE (NGP, UTILIZING SCINTILLATION DETECTORS'). 6. MWD RUNS 600, 700, AND MAD RUN 700 COMPRISED DIRECTIONAL, DUAL GAMMA RAY(DGR, UTILIZING GEIGER-MUELLER TUBE , DETECTORS ) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). MAD RUN 700 DATA WERE ACQUIRED WHILE POOH AFTER REACHING TD. 7. DIGITAL DATA ONLY ARE DEPTH SHIFTED/CORRECTED TO THE SCHLUMBERGER MCNL LOG RUN ON 10 FEBRUARY 2001. 8. MWD RUNS 300, 400, 500, 600, 700 AND MAD RUN 700 REPRESENT WELL B-29A WITH API# 50-029-21523-01. THIS WELL REACHED A TOTAL DEPTH OF 10503.00'MD/8951.71'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SGRD = SMOOTHED NATURAL GAMMA RAY SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING CURVE ACRONYMS WITH "M" SUFFIX DENOTE MAD-PASS DATA $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8835.5 ROP 8872.0 RPS 9990.5 RPX 9990.5 RPM 9990,5 FET 9990.5 RPD 9990.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8835.5 8848.0 8851.5 8856.5 8861.0 8870.0 8873.0 8875.0 8879.0 8882.0 8883.5 8890.5 8901.5 8906.5 GR 8835.0 8847.5 8852.5 8858.0 8861.5 8869.5 8874.0 8875.5 8878 5 8881 5 8883 5 8888 5 8901 5 8905 5 STOP DEPTH 10454 5 10500 5 10465 5 10465 5 10465 5 10465 5 10465.5 EQUIVALENT UNSHIFTED DEPTH 8913 8917 8923 8927 8941 8943 8955 8962 8973 8979 8986 8997 9011 9021 9055 9060 9065 9091 9096 9114 9121 9136 9164 9169 9176 9189 9194 9200 9257 9262 9306 9316 9322 9337 9343 9345 9361 9.379 9398 9438 9449 9453 9466 9469 9480 9490 9548 9560 9569 9592 9596 9607 9640 9655 9663 96'75 9709 9718 9730 9751 9754 .0 .0 .5 0 0 5 5 5 0 5 5 .0 .5 .5 .5 0 5 0 0 5 5 0 5 .0 5 0 0 5 5 5 5 5 0 0 5 5 0 5 5 5 5 5 5 0 0 5 0 5 5 5 0 0 5 5 5 0 5 0 0 0 0 8912.0 8916.0 8922.5 8926.0 8940.0 8942.5 8955.0 8961.5 8972.0 8979.0 8985.5 8995.5 9011.5 9020.5 9054.5 9059.0 9065 0 9091 0 9095 5 9114 0 9119 5 9133 5 9163 5 9168 0 9175 0 9186 5 9193 0 9199 5 9255 0 9261 0 9305.5 9316 5 9320 5 9335 5 9342 5 9345 0 9361 5 9379 0 9398 0 9437 0 9446 5 9453 0 9465 0 9467 5 9477.5 9488.0 9546.0 9558.5 9567.5 9588.5 9593.5 9606.5 9636.5 9655.0 9662.0 9674.5 9708.5 9716.5 9730.5 9750.0 9754.5 9763. 9767. 9773. 9791. 9879. 9888. 9894. 9910. 9932. 9937. 9949. 9959. 9964. 9981. 9989. 10013. 10041. 10143. 10154. 10168 10177 10188 10209 10249 10262 10270 10275 10292 10303 10314 10322 10334 10352 10365 10370 10381 10409 10415. 10446. 10500. $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: 9762.5 9768.0 9773.5 9791.0 9878.0 9889.0 9895.5 9909.0 9931.0 9935.5 9948.5 9959.0 9962.5 9978.5 9988.0 10011.5 10039.0 10142.0 10152.0 10166.0 10176.0 10187.5 10209.0 10248.0 10259.5 10269.0 10274.5 10296.0 10306.5 10316.0 10326.5 10334.5 10351.5 10365.0 10370.0 10381.0 10411.0 10415.5 10448.5 10503.0 BIT RUN NO MERGE TOP MERGE BASE 1 8835.0 9624.0 3 9594.0 9704.0 4 9672.5 9925.5 5 9894.5 10024.0 6 9978.5 10294.5 7 8941.0 10503.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Last Name Service Unit Min Max Reading DEPT FT 8835.5 10500.5 10500.5 ROP MWD FT/H 0 797.51 10500.5 GR MWD API 12.28 208.37 10454.5 RPX MWD OHMM 1.68 23.79 10465.5 RPS MWD OHMM 1.8 28.59 10465.5 RPM MWD OHMM 1.94 32.02 10465.5 RPD MWD OHMM 2.37 37.72 10465.5 FET MWD HOUR 0.36 17.92' 10465.5 Mean 9668 68.2267 36.9072 7.7442 8.37453 8.77241 9.4981 3.94989 Nsam 3331 3258 3239 951 951 951 951 951 First Reading 8835.5 8872 8835.5 9990.5 9990.5 9990.5 9990.5 9990.5 First Reading For Entire File .......... 8835.5 Last Reading For Entire File ........... 10500.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 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 ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPS FET RPM RPX RPD RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH STOP DEPTH 8942.0 10112.0 8942.5 10122.5 8942.5 10122.5 8942.5 10122.5 8942.5 10122.5 8942.5 10122.5 8974.0 10123.0 MAD RUN NO. MAD PASS NO. MERGE TOP 7 1 8941.0 MERGED MAD PASS. $ MERGE BASE 10503.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ........ . .............. -999 Depth Units ....................... Datum Specification Block ~ub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 8942 10123 9532.5 2363 First Reading 8942 10123 RAT MAD FT/H 241.71 3600 10123 GR MAD API 15.55 134.86 10112 RPX MAD OHMM 2.16 2000 10122.5 RPS MAD OHMM 2.35 2000 10122.5 RPM MAD OHMM 2.35 664.88 10122.5 RPD MAD OHMM 1.87 169.93 10122.5 FET MAD HOUR 36.38 101.05 10122.5 760.746 33.6113 14.8141 21.8248 27.8793 43.6687 87.9705 2299 2341 2361 2361 2361 2361 2361 8974 8942 8942.5 8942.5 8942.5 8942.5 8942.5 First Reading For Entire File .......... 8942 Last Reading For Entire File ........... 10123 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 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 ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8835.0 9593.5 ROP 8872.5 9624.0 $ # LOG HEADER DATA DATE LOGGED: 03-FEB-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Dat.a Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 0 Memory 9623.0 16.0 16.0 TOOL NUMBER BHI000 3.750 Flo Pro 8.6O 65.0 9.5 16500 12.6 .000 .000 .000 .000 .0 142.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Last Name Service Unit Min Max Reading DEPT FT 8835 9624 9624 ROP MWD010 FT/H 3.94 308.34 9624 GR MWD010 API 12.28 208.37 9593.5 Mean Nsam 9229.5 1579 68.4987 1504 40.1508 1518 First Reading 8835 8872.5 8835 First Reading For Entire File .......... 8835 Last Reading For Entire File ........... 9624 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 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 ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9594.0 9672.0 ROP 9624.5 9704.0 $ LOG HEADER DATA DATE LOGGED: 04-FEB-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9704.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data.Format Specification Record Data Record Type .................. 0 Data Specification Block Type ...... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ........... 2 .......... -999 Depth Units ....................... Datum Specification Block sub-type...0 83.6 86.1 TOOL NUMBER PCG002 3.750 Flo Pro 8.60 42.0 9.0 16500 13.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 . 2 GR MWD030 API 4 1 68 8 3 .0 150.1 .0 .0 Last Name Service Unit Min Max Mean Nsam First Reading Reading DEPT FT 9594 9704 9704 ROP MWD030 FT/H 10.25 705.94 9704 GR MWD030 API 19.2 54.59 9672 9649 150.76 28.4603 221 160 157 9594 9624.5 9594 First Reading For Entire File .......... 9594 Last Reading For Entire File ........... 9704 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 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 ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9672.5 9894.0 ROP 9704.5 9925.5 $ LOG HEADER DATA DATE LOGGED: 05-FEB-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9914.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.9 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER PCG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 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): E'WR FREQUENCY (HZ) : Flo Pro 8.60 42.0 9.0 16500 13.4 .000 .000 .000 .000 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record .............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 .0 154.0 .0 .0 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 9672.5 9925.5 9799 507 9925.5 ROP MWD040 FT/H 0.79 733.52 91.1825 443 First Reading 9672.5 9704.5 9925.5 GR MWD040 API 9894 18.53 93.51 27.8046 444 9672.5 First Reading For Entire File .......... 9672.5 Last Reading For Entire File ........... 9925.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 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 ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9894.5 9991.5 ROP 9926.0 10024.0 $ LOG HEADER DATA DATE LOGGED: 06-FEB-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10023.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.5 MAXIMUM ANGLE: 73.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data' Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 PCG017 3.750 Flo Pro 8.60 65.0 9.0 16500 13.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 .0 154.0 .0 .0 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 9894.5 10024 9959.25 260 10024 ROP MWD050 FT/H 1.78 67.73 26.2096 197 10024 GR MWD050 API 22.41 153.8 35.4527 195 9991.5 First Reading 9894.5 9926 9894.5 First Reading For Entire File .......... 9894.5 Last Reading For Entire File ........... 10024 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 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 ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9978.5 10248.0 RPD 9989.5 10259.5 RPM 9989.5 10259.5 RPS 9989.5 10259.5 RPX 9989.5 10259.5 FET 9989.5 10259.5 ROP 10024.5 10294.5 $ # 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 BOTTOM) 07-FEB-01 Insite 0 Memory 10288.0 62.0 73.5 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PBO1818RF3 PBO1818RF3 3.750 Flo Pro 8.70 44.0 9.0 19000 9.8 .190 .095 .150 .140 70.0 147.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel · DEPT FT ' 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPs MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 Last Name Service Unit Reading Min Max Mean Nsam First Reading DEPT FT 9978.5 10294.5 10294.5 ROP MWD060 FT/H 0.52 797.51 10294.5 GR MWD060 API 15.3 33.48 10248 RPX MWD060 OHMM 1.68 23.79 10259.5 RPS MWD060 OHMM 1.84 28.59 10259.5 RPM MWD060 OHMM 1.94 32.02 10259.5 RPD MWD060 OHMM 2.37 37.72 10259.5 FET MWD060. HOUR 0.73 14.86 10259.5 10136.5 27.2383 22.8641 5.60333 6.19689 6.66567 7.94381 4.76673 633 541 540 541 541 541 541 541 9978 5 10024 5 9978 5 9989 5 9989 5 9989 5 9989 5 9989 5 First Reading For Entire File .......... 9978.5 Last Reading For Entire File ........... 10294.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10248.5 FET 10260.0 RPD 10260.0 RPM 10260.0 RPS 10260.0 RPX 10260.0 ROP 10295.0 STOP DEPTH 10457.0 10468.0 10468.0 10468.0 10468.0 10468.0 10503.0 $ # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 08-FEB-01 Insite 0 Memory 10503.0 76.7 90.0 TOOL NUMBER PBO1818RF3 PBO1818RF3 3.750 Flo Pro 8.70 65.0 9.0 39000 10.2 .250 .118 .140 .150 70.0 155.9 70.0 70.0 Name Service Order DEPT FT ROP MWD070 FT/H GR MWD070 API RPX MWD070 OHMM RPS MWD070 OHMM RPM MWD070 OHMM RPD MWD070 OHMM FET MWD070 HOUR Units Size Nsam Rep Code Offset Channel 4 1 68 0 1 4 1 68 4 2 4 1 68 8 3 4 1 68 12 4 4 1 68 16 5 4 1 68 20 6 4 1 68 24 7 4 1 68 28 8 Last Name Service Unit Min Max Reading DEPT FT 10248.5 10503 10503 ROP MWD070 FT/H 14.73 163.81 10503 GR MWD070 API 18.09 147.12 10457 RPX MWD070 OHMM 1.68 17.31 10468 RPS MWD070 OHMM 1.8 18.63 10468 RPM MWD070 OHMM 1.95 21.28 10468 RPD MWD070 OHMM 2.54 19.5 10468 FET MWD070 HOUR 0.36 17.94 10468 Mean 10375.8 83 7533 55 4852 10 4335 11 1205 11 4122 11 3454 3.07765 Nsam 510 417 418 417 417 417 417 417 First Reading 10248.5 10295 10248.5 10260 10260 10260 10260 10260 First Reading For Entire File .......... 10248.5 Last Reading For Entire File ........... 10503 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 Maximum. Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. .5000 7 1 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8941.0 10110.0 FET 8941.5 10121.0 RPD 8941.5 10121.0 RPM 8941.5 10121.0 RPS 8941.5 10121.0 RPX 8941.5 10121.0 RAT 8973.0 10121.5 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S),: MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): 'RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD'CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 08-FEB-01 Insite 0 Memory 10503.0 76.7 90.0 TOOL NUMBER PBO1818RF3 PBO1818RF3 3.750 Flo Pro 8.70 65.0 9.0 39000 10.2 .250 .118 .140 .150 70.0 155.9 70.0 70.0 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value .................. ~...-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD071 FT/H 4 1 68 GR MAD071 API 4 1 68 RPX MAD071 OHMM 4 1 68 RPS MAD071 OHMM 4 1 68 RPM MAD071 OHMM 4 1 68 RPD MAD071 OHMM 4 1 68 FET MAD071 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Last Name Service Unit Min Max Reading DEPT FT 8941 10121.5 10121.5 RAT MAD071 FT/H 241.71 3600 10121.5 GR MAD071 API 15.55 134.86 10110 RPX MAD071 OHMM 2.16 2000 10121 RPS MAD071 OHMM 2..35 2000 10121 RPM MAD071 OHMM 2.35 664.88' 10121 RPD MAD071 OHMM 1.87 169.93 10121 FET MAD071 HOUR 36.38 101.05 10121 Mean Nsam 9531.25 2362 760.075 2298 33.7767 2339 14.8709 2360 21.9198 2360 27.9843 2360 43.7542 2360 87.961 2360 First Reading 8941 8973. 8941 8941.5 8941.5 8941.5 8941.5 8941.5 ' First Reading For Entire File .......... 8941 Last Reading For Entire File ........... 10121.5 File Trailer Service name ............. STSLIB.009 .Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/03/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/03/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/03/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number.· ..... 01 Next Reel'Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 01103108 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/03/08 113806 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ lllllllllllllllllll R ................... emark File Version 1.000 . !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP, NO: One line per frame -Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8830.0000: Starting Depth STOP.FT 9630.0000: Ending Depth STEP.FT 0,5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration Alaska WELL. WELL: B-29A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 1695' FNL, 4170' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 03-Feb-01 API . API NYUMBER: 500292175901 -Parameter Information Block #MNEM.UNIT Value Description SECT. 04 : Section TOWN.N 11N : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD ,F 0 : Elevation Of Perm, Datum LMF . RKB : Log Measured from FAPD.F 52.8 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 52.8 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F 9420 : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well B-29A was kicked off @ 9025' MD (8645' SSTVD) from the wellbore of Well B-29APB1. (5) Well B-29A was drilled to 9623' MD (8765' SSTVD) on run 15. (6) The interval from 9594' MD (8761' SSTVD) to 9623' MD (8765' SSTVD) was not logged due to sensor to bit offset. (7) The data presented is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BP Alaska (SWS, MCNL 10-Feb-01). (8) A Magnetic Declination correction of 26.89 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX ROPS TVD -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, feet/hour -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 15 26.13 ft. 31.12 ft. CURVE SHIFT DATA MEASURED, 8847.37 8855.20 8860.87 8870.07 8875.15 8883.56 8893.74 8901.76 8905.08 8908.02 8912.71 8916.62 8923.48 8926.81 8931.70 8940.89 8944.61 8947.54 8959.08 8962.21, 8968.28, 8972.97, 8986.28, 9011.65, 9059.94, 9066.20, 9088.50, 9121.67, 9165.59, 9176 74 9262 43 9302 31 9312 87 9328 33 9343 00 9351 41 9375 85 9439 16 9447 07 9450 50 9469 28 BASELINE 8848.16 8856.37 8861.26 8869.67 8875.15 8883.17 8891.39 8901.17 8904.30 8907.04 8911.73 8915.84 8923.09 8926.03 8930.72 8939.91 8943.63 8946.56 8958.50 8961.63 8967.30 8972 19 8985 49 9011 65 9059 16 9065 02 9088 50 9119 91 9163 83 9174 78 9261 06 9302 11 9311 89 9327 54 9342.41 9350 04 9375 85 9437 59 9444 72 9448 54 9467 71 DISPLACEMENT -0.782227 -1.17285 -0.390625 0.390625 0.00000 0.391602 2.34766 0.586914 0.782227 0.978516 0.977539 0.783203 0.391602 0.782227 0.978516 0 977539 0 977539 0 978516 0 585938 0 585938 0 977539 0 783203 0 782227 0 00000 0 782227 i 17383 0 00000 i 76074 1 76074 I 95605 1.36914 0.196289 0.978516 0.782227 0.586914 1.36914 0.00000 1.56543 2.34766 1.95605 1.56543 9477.89, 9480.23, ! 2.34668 9487.86, 9490.41, ! 2.54395 9520.16, 9522.31, ! 2.15234 Tape Subfile: i 111 records... Minimum record length: 8 bytes Maximum record length: 132 bytes [] Tape Subfile 2 is type: LIS **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN main.xtf LCC 150 CN BP Exploration Alaska WN B-29A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~~23456789~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BP Alaska 3. The PDC used is a Schlumberger Gamma Ray (MCNL) dated 10-Feb-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i GR GRAXll 0.0 2 ROP ROPSll 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type (13) Size ( 1) Repcode (66) One depth per frame (value= 0) Entry Type (16) Size ( 1) Repcode (66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: i 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 i 1 I 1 0 0 i 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size i GR MWD 68 1 API 4 2 ROP MWD 68 I F/HR 4 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 Tape File Start Depth = 8830.000000 Tape File End Depth = 9630.000000 Tape File Level Spacing = 0,500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 4807 datums Rep Code: 79 2 datums Tape Subfile: 2 29 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes [] Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 ....... 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN main.xtf LCC 150 CN BP Exploration Alaska WN B-29A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~234567890~234567890~234~67890123456789~~23456789~~234567890~23456789~~234567890 !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0 . 0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( 1) Repcode(66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode(66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 i I i i I 0 0 I i 0 i 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAXMWD 68 1 API 4 2 ROPS MWD 68 1 F/HR 4 *** Record Type (47) not decoded... *** Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 19 Tape File Start Depth = 8830.000000 Tape File End Depth = 9625.000000 Tape File Level Spacing = 0,500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 I datum Rep Code: 68 4777 datums Rep Code: 79 2 datums Tape Subfile: 3 28 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MWD 0~/03/08 113806 01 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 8 **** REEL TRAILER **** MWD 01/03108 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 8 MAR ** l:01p Elapsed execution time = 0.33 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 8830 8830 8900 9000 9100 9200 9300 9400 9500 9600 9630 GR 0000 -999 5000 -999 0000 167 0000 23 0000 29 0000 20 0000 18 0000 22 0000 15 0000 -999 0000 -999 2500 2500 5591 5959 5440 9193 0208 .4622 .0514 .2500 .2500 ROP -999 2500 -999 2500 10 5857 16 8078 118 9456 73 1261 91 7077 97.4486 56.0508 122.4660 -999.2500 Tape File Start Depth = 8830.000000 Tape File End Depth = 9630.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH 8830 8830 8900 9000 9100 9200 9300 9400 9500 9600. 9625. GRAX ROPS 0000 -999.2500 -999.2500 5000 -999.2500 -999.2500 0000 155.6310 10.8120 0000 25.0870 16.7730 0000 29.5440 119.2080 0000 18.3010 111.7790 0000 18.0010 91.9390 0000 19.3330 97,4250 0000 15.3370 89.7800 0000 -999.2500 124.5610 0000 -999.2500 -999.2500 Tape File Start Depth = 8830.000000 Tape File End Depth = 9625.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS
