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212-141
STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION CO ION • WOCOMPLETION OR RECOMPLETION R T AND LOG JUN 0 7 2018 la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 • Suspended 0 1b.Well Class: 20AAC 25.105 20AAC 25.110 Developme 4 9 .y GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp. or Aband., 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc !z'/1, ' 212-141 ' 318-052 3. Address: 7. Date Spudded: t 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 3/10/2013 50-029-20434-02-00 • • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 4/17/2013 PBU F-13B • Surface: 1988'FNL,2865'FEL,Sec.02,T11N,R13E,UM • 9 Ref Elevations KB 80.26 17. Field/Pool(s): Top of Productive Interval: 285'FNL,3699'FEL,Sec.02,T11N,R13E,UM GL 34.98 ., BF 35.98 • PRUDHOE BAY,PRUDHOE OIL" Total Depth: 136'FNL,3843'FEL,Sec.02,T11N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9222'/8873' ADL 028280 • - 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 651958 •y- 5974812 • Zone - ASP 4 • 9680'/9202' • 87-035 TPI: x- 651088 y- 5976498 Zone - ASP 4 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: Total Depth:x- 650940 y- 5976644 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 Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 6638'/6516' 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/at-bit-GR/RES,MWD/GR/RES/NEU/DEN 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20"x 30" 47' 127' 47' 127' 36" 8.5 cu yds Permafrost Concrete 13-3/8" 72# L-80 46' 2682' 46' 2682' 17-1/2" 3813 cu ft Arctic Set II 9-5/8" 47# L40 44' 6638' 44' 6516' 12-1/4" 1164 cu ft Class'G',130 cu ft Arctic Set] 7" 26# L-80 6462' 9033' 6341' 8711' 8-1/2" 142 sx Class'G' 4-1/2" 12.6# 13Cr85 8850' 9678' 8545' 9200' 6-1/8" 120 sx Class'G' 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;Date Perfd): 4-1/2"12.6#13Cr85 8862' 8741'/8446' o..6 e,J.uv.crh 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. D/'2'1B Was hydraulic fracturing used during completion? Yes 0 No 0 • f Per 20 AAC 25.283(i)(2)attach electronic and printed JUN )(}1Q 1/=F��;rHf.!_, information � ' 1�J L lJ!l) T1_..1_ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9269' Set CIBP 9222' 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(corn): Press 24 Hour Rate "...1 Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS.1.klJUN 0 8 2018 1/7-1- 6/12-lc A /, / ,AI �,45/g 6 28. . CORE DATA • Conventional Core(s) Yes ❑ No 10• Sidewall Cores Yes 0 No 0 ' If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes 0 No II Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9390' 9000' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Colville Mudstone 7126' 6986' HRZ 7405' 7239' Base of HRZ/LCU 7606' 7421' Sag River 9015' 8695' Shublik A 9063' 8738' Shublik B 9106' 8777' Shublik C 9124' 8792' Shublik/Sadlerochit-Zone 4 9147' 8812' CGL-Zone 3 9301' 8934' Base of CGL-Zone 2C 9390' 9000' Zone 2B 9491' 9070' 22TS 9565' 9122' Zone 2A 9631' 9167' Formation at total depth: Zone 2A - 9631' 9167' 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: SIM list 8 Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: ^ pates (oil fit 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 1 b.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 TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • • Daily Report of Well Operations F-13B ACTIVITYDATE SUMMARY ***JOB STARTED ON 08-APRIL-2018***(SLB ELINE SET CIBP) WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 1650/0/0 RU. PT. 4/8/2018 ***JOB CONTINUED ON 09-APRIL-2018*** T/I/0=1600/0/0 Temp= S/I Assist E-line (CTD) Drove to location, loaded diesel on unit,spot 4/8/2018 unit. ***Continued on 04-09-18 WSR*** ***Continued from 04-08-18 WSR*** Assist E-line. Pumped 2 bbls 60/40 and 290 bbls 1% KCL capped with 3 bbls 60/40 and 38 bbls diesel. E-line in control of well upon departure. 4/9/2018 FWHPS=0/5/500 ***JOB CONTINUED FROM 08-APRIL-2018*** LRS LOAD WELL. RUN 1. RIH W/ BAKER 1A BRIDGE PLUG. SET ME AT 9270'. RUN 2: RIH W BAKER 4-1/2" WHIPSTOCK. TOWS AT 9224', ORIENTATION = 18.4 DEG ROHS. FINAL T/I/O = VAC/0/0 WELL SHUT IN ON DEPARTURE. 4/9/2018 ***JOB COMPLETE*** T/I/O=Vac/0/0 Temp= S/I MIT-T **PASSED** @ 2719 psi, Max Applied Pressure= 2750 psi, Target Pressure= 2500 psi, (CTD) Pumped 15 bbls diesel down TBG to reach test pressure, TBG lost 5 psi in 1st 15 min and 3 psi in 2nd 15 min for a total loss of 8 psi in 30 min test. Bled TP back to 0 psi. Bled back 2.4 bbls. Pad op notified of well status and tree valve postions as 4/10/2018 follows: SV,WV,SSV= closed. MV=open. IA and OA open to gauges. FWHP=0/0/6 T/I/O = 0/0/0. Pre CDR2 tree work. Removed 4"tapped blind flange off of FC Companion side. Installed CDR#3 target 90. Torqued to API specs. Removed tree cap assembly and replaced with 4"tapped blind flange. Torqued to API specs. PT to 350psi low and 5000psi high for 5 minutes each (PASS) RDMO ***Job Complete*** Final T/I/O = SI/0/0. SEE LOG 4/26/2018 FOR DETAILS T/I/O = SSV/Vac/5. Temp = SI. WHPs (Pre Rig). All flowlines, wellhouse, scaffolding and ladder removed. 5/5/2018 SV= ?. WV= LOTO. SSV= C. MV= 0. IA, OA= OTG. 15:00 T/I/O= SI/0/0 Pree CDR Installed Nordic Platform for upcoming CDR2 Work. RDMO ***Job 5/6/2018 Complete*** FWHP = SI/0/0 T/I/O = 31/Vac/5. Temp = SI. WHPs (Pre Rig). Well is demobed for the rig. No ladder to or hand rails on tree cap platform. 5/7/2018 SV= ?. WV= LOTO(ops lock). SSV= C. MV= 0. IA, OA= OTG. 02:50. • • North America ALASKA BP Page 1 1X Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/8/2018 I End Date:5/19/2018 X3-018X6-C:(2,599,041.00) Project:PBU Site:F Rig Name/No.:CDR-2 Spud Date/Time:2/5/1980 12:00:00AM Rig Release.5/20/2018 Rig Contractor.NABORS ALASKA DRILLING INC. BPUOI:USA00000738 Active datum:KB @80.26usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT Total Depth Phase I Description of Operations (hr) (usft) 5/8/2018 17:00 - 22:00 5.00 MOB P PRE PJSM, PULL TEST GRAPPLE. PULL COIL BACK TO REEL. SECURE FOR TRANSPORT REMOVE 2"REEL INSTALL NEW 2-3/8"REEL. SECURE WITH SADDLE CLAMPS. 22:00 - 00:00 2.00 MOB P PRE PJSM, REMOVE STRIPPER AND GOOSENECK. REMOVE STRIPPER. 5/9/2018 00:00 - 07:00 7.00 MOB P PRE REMOVE GOOSENECK TO CHANGE ROLLERS.CHANGE OUT GRIPPER BLOCKS. PREPARE TO PULL CT ACROSS INTO INJECTOR. !INSTALL GRAPPLE AND PULL TEST. REMOVE SHIPPING BAR FROM REEL. .CONDUCT PJSM FOR PULLING CT OFF REEL AND INTO INJECTOR. USE WINCH TO PULL CT OFF REELAND DOWN INTO INJECTOR. 07:00 - 09:00 2.00 MOB P PRE FINISH RIG DOWN CHECKLISTS. PREP TO MOVE RIG OFF WELL L2-14C. 09:00 - 15:00 6.00 MOB P PRE CONDUCT PJSM FOR MOVING OFF WELL WITH PEAK AND NABORS CREW. PULL PIT MODULE OFF WELL. I PULL SUB MODULE OFF WELL. INSTALL JEEPS AND PREP FOR TRAVEL. MOVE RIG FROM L2 PAD,RIGHT ON WEST DOCK,LEFT ON OXBOW,RIGHT ON SPINE TO F-PAD. 15:00 - 17:00 2.00 MOB P PRE RIG ARRIVES F-PAD. I CONDUCT PJSM AND SPOT STOP BLOCK. PULL SUB OVER WELLAND SET DOWN. WITNESSED BY TOOLPUSHER AND WSL. PULL PIT MODULE ALONGSIDE AND SET DOWN. ACCEPT RIG AT 17:00. 17:00 - 00:00 7.00 RIGU P PRE START RIGGING UP. HOOK UP INTERCONNECT LINES. SPOT AUXILIARY EQUIPMENT. INSTALLING INNER REEL IRON ELECTRICIAN INSTALLING PRESSURE 'BULKHEAD. INSTALL HORSEHEAD ROLLERS AND COUNTER. SIMOPS:CREW INSTALLING MPD LINE. PERFORM LTT BETWEEN MASTER AND SWAB TO 3500# SIMOPS:NIPPLE UP BOPE PERFORMED PRESPUD WITH JURY CREW 5/10/2018 00:00 - 01:00 1.00 RIGU P PRE FINISH BULKHEAD FINISH NIPPLE UP ON STACK 01:00 - 04:00 3.00 RIGU P PRE PJSM, INSTALL 2-3/8"COIL CONNECTOR. PULL TEST TO 50K INSTALL E-LINE BOOT,AND STINGER. LOAD REEL WITH FRESHWATER SIMOPS:CHARGE ACCUMULATOR SYSTEM Printed 6/6/2018 3:23:19PM *AIL depths reported in Drillers Depths* North America-ALASKA-BP Page 2 . • • Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/8/2018 End Date:5/19/2018 X3-018X6-C:(2,599,041.00) Project:PBU Site:F Rig Name/No.:CDR-2 Spud Date/Time:2/5/1980 12:00:00AM i Rig Release:5/20/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000738 Active datum:KB @80.26usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth I! Phase Description of Operations (hr) (usft) 04:00 - 06:30 2.50 RIGU P + fi PRE PJSM, RIG UP TO TEST INNER REEL IRON _ _ I AND PRESSURE BULKHEAD. BRING PRESSURE UP TO 4600#, PRESSURE BULKHEAD LEAKED. BLEED PRESSURE OFF. GET 1/4 TURN ON PACKOFF NUT. BRING PRESSURE BACK UP TO 4600#, STILL }LEAKING. BLEED PRESSURE OFF, STAND INJECTOR BACK. GO INTO BOPE TESTING WHILE ELECTRICIAN FIXES BULKHEAD CONDUCT PJSM FOR TESTING BULKHEAD AND BOPS. 06:30 09:30 3.00 BOPSUR P PRE TRY BULKHEAD AGAIN,LEAKS AT 500 PSI. PURGE REEL WITH BIG AIR COMPRESSOR. ATTEMPT SHELL TEST ON BOPS,BLEEDING OFF. GREASE CREW SERVICES TREE VALVES AND CLOSE SSV, 09:30 - 18:00 8.50 BOPSUR P PRE TEST BOPS AS PER AOGCC,BP AND NABORS GUIDELINES. l TEST ANNULAR,BLIND/SHEARS,UPPER 2-3/8"PIPE/SLIPS,2-3/8"X 3-1/2"VBRS, I JLOWER 2-3/8"PIPE/SLIPS,CHOKE LINE AND MPD VALVES,AND TIWS. ALL TESTS 250-300 PSI LOW,3,500 PSI HIGH. PERFORM ACCUMULATOR DRAWDOWN TEST,WITNESSED BY TP AND WSL. REMOVE TEST JOINT AND INSTALL SAVER SUB FOR FINAL PORTION OF TEST. CONTINUE TESTING ANNULAR AND VBRS WITH 3-1/2"SECTION OF MULTI-JOINT. ANNULAR HAS FAILED ON 3-1/2"PIPE. CYCLE ANNULAR ON 3-1/2". TEST 300#LOW/ 3500#. TEST PASSED. 18:00 - 21:00 3.00 BOPSUR P PRE PJSM, INSTALL NOZZLE. MAKE UP LUBRICATORS TO BOPE STACK !REVERSE CIRCULATE FRESHWATER TO !REMOVE AIR FROM BLOWDOWN. LINE UP TO TEST IRV,PACKOFFS,C9/C10 BACKWARDS. PASS. RIG DOWN l EQUIPMENT. PREPARE FOR INNER REEL IRON TEST TO 4950#. 21:00 - 22:00 1.00 BOPSUR P PRE PJSM, DISCUSS PRESSURE CROSSCHECK. BRING PRESSURE TO 4500#WITH MUD PUMP. BYPASS MICRO MOTION. BRING PRESSURE UP TO 4950#WITH RIG 'TEST PUMP. TEST PASSED AT 4950#. BLEED DOWN. 22:00 - 23:00 1.00 RIGU P PRE REMOVE TEST PLATE AND INSTALL NOZZLE. STAB ON WELL. PUMP SLACK FORWARD AT 3.0 BPM FOR COIL VOLUME. SIMOPS:GREASE CREW OPEN SSV AND INSTALL FUSIBLE. BLEED HYDRAULIC PRESSURE OFF BARREL. SIMOPS:TORQUE TREE 23:00 - 00:00 1.00 RIGU P PRE PJSM, BHI INSTALL UQC WITH FLOATS. Printed 6/6/2018 3:23:19PM *All depths reported in Drillers Depths* • • North America-ALASKA-BP • Page 34W Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/8/2018 ' End Date:5/19/2018 X3-018X6-C:(2,599,041.00) Project:PBU Site:F Rig Name/No.:CDR-2 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:5/20/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000738 Active datum:KB @80.26usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 5/11/2018 00:00 - 02:00 2.00 RIGU P PRE FINISH MAKEUP UQC. TEST PRESSURE TEST BODY TO 3500# STAB ON AND TEST FLOATS TO 3500# PASS 02:00 - 02:30 0.50 RIGU P PRE SWAP REEL OVER TO METH SPEAR/1% SLICK KCL W/BARALUBE. SIMOPS:BUILD MILLING BHA ON PDL WINCH 02:30 - 03:00 0.50 RIGU P PRE OPEN WELL AGAINST CLOSED CHOKE. 0 PSI. FILL HOLE WITH METHANOL. HOLE FULL PERFORM 15 MIN FLOW CHECK. GOOD 03:00 - 03:30 0.50 STWHIP P WEXIT MAKE UP 3.80"MILLING BHA#1 -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES INJECTOR ON:03:30 03.30 - 05:00 1.50 STWHIP P - WEXIT RIH WITH 3.80"MILLING BHA#1 -RATE:0.40 BPM IN, 0.76BPM OUT.CIRC PRESSURE:63 PSI -MUD WEIGHT:8.38 PPG IN,6.82 PPG OUT -MAINTAIN 100 PSI ON CHOKE WHILE RUNNING IN HOLE. 05:00 - 05:30 0.50 STWHIP N WEXIT 'AROUND 1,700'COILTRAK TOOL LOSES STOPC N. AT O3,000' ND CIRC FREEZE PROTECTO TROUBLESHOOT WHILE CONTINUE TO RIH. FLUID IN THE WELL OUT TO THE TIGER TANK STILL TROUBLESHOOTING TOOL,GETTING INTERMITTENT FAILURES. CHECK ALL SURFACE BHI COMPONENTS,NO PROBLEMS FOUND. AFTER KCL BACK TO SURFACE,10 MIN _ PUMPS OFF FLOWCHECKAT 3,000'IS STATIC. 05:30 - 07:30 2.00 STWHIP N ' WEXIT POOH FOR LOSS OF COMS TO BHA. AT 200'CONDUCT 10 MIN PUMPS OFF FLOWCHECK,STATIC. OPEN RISER AND POOH TO SURFACE. CHANGE OUT COILTRACK TOOL. INSPECT AUTOMATIC CHOKE AND COLLECTOR,JUNCTION BOX AT SURFACE. FIND LOOSE CONNECTION IN JUNCTION BOX. 07:30 - 08:30 1.00 STWHIP P WEXIT CONDUCT H2S RIG EVAC DRILL WITH JURY CREW. ALL PERSONNEL MUSTER AND ACCOUNTED FOR IN 4 MIN. CONDUCT AAR,ALL CREWS RETURN TO POSITION. 08:30 - 09:30 1.00 STWHIP P WEXIT MAKE UP BHA#2,WINDOW MILLING BHA. MILLAND REAMER ARE 3.80"GO,3.79" NO-GO. INJECTOR ON AT 09:20. PRESSURE TEST QTS TO 3,500 PSI,GOOD. Printed 6/6/2018 3.23:19PM •AII depths reported in Drillers Depths` . North America-ALASKA-BP • Page 4 CL - Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/8/2018 End Date:5/19/2018 X3-018X6-C:(2,599,041.00) Project:PBU Site:F Rig Name/No.:CDR-2 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:5/20/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000738 Active datum:KB @80.26usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:30 - 11:50 2.33 STWHIP P WEXIT RIH BHA#2. 0.34/059 BPM IN/OUT. 8.38/8.44 PPG. KEEP 150 PSI WHP WHILE RIH,TAKE RETURNS TO TIGER TANK. LOG GR DOWN FROM 8,215',CORRECT+2.5 FT. STOP AT 8,000'AND CLOSE EDC. UP WT AT 8,000'IS 52K. RIH CAREFULLY,LIGHT TAG AT 8,847'XN NIPPLE. 11:50 - 14:20 2.50 STWHIP P WEXIT 'PICKUP AND BRING PUMP TO 2.6 BPM/1,530 PSI. RIH SLOWLY AND MILL XN NIPPLE. 'HOLD 200 PSI PRESSURE WHILE CIRCULATING AND MILLING NIPPLE. AT 12:50 BLEED OA FROM 600 PSI TO 80 PSI. STALL 4 TIMES GETTING STARTED. EASE THROUGH NIPPLE THEN SEE 1 STALL AND THEN SLIGHT MOTOR WORK WHEN REAMER PASSES PROFILE. START MUD DOWN CT. 14:20 - 15:20 1.00 STWHIP P WEXIT WHILE WORKING DOWN PAST NIPPLE SEE 'OUT RATE START TO INCREASE ABOVE IN RATE. NO DENSITY CHANGE. PICK UP ABOVE XN NIPPLE AND SHUT DOWN PUMP FOR FLOW CHECK. OUT RATE INCREASING AFTER PUMP IS SHUT DOWN,SHUT IN WELL WITH DRILLING CHOKE. INTIAL WHP ABOUT 210 PSI,STARTS TO CLIMB SLOWLY WITH GAS MIGRATION. NOTIFY ACTING WSUP,RECEIVE PERMISSION FROM ACTING WOM TO CIRCULATE GAS OUT TO TIGER TANK. 15:20 - 17:45 2.42 STWHIP N WEXIT EMPTY TIGER TANK. PJSM WITH NABORS CREW. REVIEW CIRCULATION PATHS AND VALVE LINEUPS. NOTIFY DSO VENTING GAS AT TIGER TANK. OPEN EDC. START CIRCULATING MUD AROUND HOLD 350 PSI WHP INITIALLY THEN USE ANNULAR PRESSURE GAUGE TO KEEP ABOUT 9.3 PPG ANNULAR PRESSURE WHILE CIRCULATING. MAKE REMAINING NOTIFICATIONS TO WELLS HSE REPAND DSO AS PER TIER 3 FLOW CHART. CONTINUE CIRCULATING MUD TO SURFACE. 17:45 - 20:00 2.25 STWHIP N 9,224.00 WEXIT PERFORM 10 MIN FLOW CHECK AFTER CIRCULATING BOTTOMS UP FROM ABOVE XN NIPPLE. GOOD NO FLOW. CLOSE EDC, ESTABLISH CIRCULATION. RUN TO BOTTOM WITHOUT ISSUE. LOG TIE IN WITH-0.5'CORRECTION. SHUT PUMP DOWN. DRY TAG WHIPSTOCK AT 9224' PICKUP AND PUMPABOTTOMS UP TO VERIFY WELL IS SWEPT. SHUT PUMP DOWN. PERFORM FLOW CHECK. GOOD FLOW CHECK.DISCUSS WITH ACTING WELL SUPT. Printed 6/6/2018 3:23:19PM *AII depths reported in Drillers Depths* (110 North America-ALASKA-BP • Page 5'ttt:Ilt Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/8/2018 End Date:5/19/2018 X3-018X6-C:(2,599,041.00) , Project:PBU Site:F Rig Name/No.:CDR-2 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:5/20/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000738 Active datum:KB l80.26usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 20:00 - 21:20 1.33 STWHIP N 9,224.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"LINER PER BAKER REP FROM 9222.5' -RATE:2.85 BPM IN,2.85 BPM OUT -MUD WEIGHT:8.62 PPG IN,8.66 PPG OUT -DWOB:0-3.5KLBS -CIRC PRESSURE:3042 PSI -STALLING MULTIPLE TIMES. TRIED , DIFFERENT SCENARIOS TO GET STARTED. STALLING IMMEDIATELY. -DISCUSS WITH ODE. PERFORM FLOW CHECK. 21:20 - 21:30 0.17 STWHIP N 9,224.00 WEXIT PERFORM 10 MIN PUMPS OFF FLOW CHECK. WELL STATIC 21:30 - 22:40 1.17 STWHIP N 9,224.00 WEXIT REAM XN NIPPLE FROM 8855'-8840'AT 1 FPM. -400 PSI MOTOR WORK SEEN AT 8847.3'TO 8846.5' UP PASS - 70 PSI MOTOR WORK SEEN AT 8848.5'TO 8848.7' DOWN'PASS -228 PSI MOTOR WORK SEEN AT 8846.9'TO 8846.6'UP PASS -70 PSI MOTOR WORK SEEN AT 8848.1'TO 8848.3'DOWN PASS I - -199 PSI MOTOR WORK SEEN AT 8847.1'TO 1 8846.8'UP PASS COME OFFLINE. DRY DRIFT. NO ISSUE EITHER WAY. 22:40 - 23:15 0.58 STWHIP N 9,224.00 WEXIT PERFORM CCL LOG ACROSS LOWER COMPLETION. -CCL IS SHOWING EVERYTHING IS WHERE IT 'SHOULD BE 23:15 - 00:00 0.75 STWHIP- N 9,224.00 WEXIT POOH FOR WINDOW MILL -MUD WEIGHT:8.58 PPG IN,8.63 PPG OUT , -RATE:3.45 BPM IN,3.44 BPM OUT 5/12/2018 00:00 - 01:30 1.50 STWHIP N 9,224.00 WEXIT STOP 200'WITH BHA. -PERFORM 10 MIN FLOW CHECK. STATIC 01:30 - 02:00 0.50 STWHIP N 9,224.00 WEXIT LAY DOWN BHA INJECTOR OFF:01:40 3.76"GO/3.75"NOGO ON STRING REAMER, 3.75"GO/3.74"NOGO ON WINDOW MILL DISCUSS WITH BOT REP AND ODE. MAKE UP 3.80"GO/3.79"NOGO D331 GEB AND NEW STRING REAMER 02:00 - 03:00 1.00 STWHIP N 9,224.00 WEXIT REPLACE PACKOFFS -PRESSURE TEST 250#LOW/3500#HIGH 03:00 - 04:00 1.00 STWHIP N 9,224.00 WEXIT MAKE UP 3.80"MILLING BHA#3 -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:03:50 Printed 6/6/2018 3:23:19PM •AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 6 of Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:5/8/2018 End Date:5/19/2018 X3-018X6-C:(2,599,041 00) Project:PBU Site:F Rig Name/No.:CDR-2 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:5/20/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000738 Active datum:KB @80.26usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT Total Depth Phase Description of Operations 04:00 - 06:45 2.75 STWHIP N j 9,224.00 WEXIT RIH BHA#3. LOG GR DOWN FROM 8,225'. CORRECT+0.5 FT. L i RUN DOWN TO 8,800'AND CLOSE EDC. UP WEIGHT DRY AT 8,800'15 52K. RIH TO 8,900',NOTHING SEEN. PULL BACK ABOVE WINDOW PUMPING MIN RATE,NOTHING SEEN. CONDUCT 1 REAMING PASS DOWN THEN UP, NOTHING SEEN DRY DRIFT IS CLEAN. 10 MIN PUMPS OFF FLOW CHECK IS STATIC. 06:45 - 08:30 1.75 STWHIP N 9,224.00 WEXIT POOH. OPEN EDC PUMP 4.05/0.54 BPM WHILE POOH. MUD WEIGHT IN 8.57 PPG,OUT 8.62 PPG. 08 30 - 09 30 1.00 STWHIP N 9,224.00 WEXIT 10 MIN PUMPS OFF FLOWCHECKAT BHA IS STATIC. INJECTOR OFF: 08:50 OPEN CT RISER AND INSPECT LAST 100'OF CT FOR CHROME RELATED DAMAGE,ONE SPOT SEEN ABOUT 5'ABOVE CONNECTOR WITH 0.175"WALL THICKNESS,8%WALL THICKNESS LOSS.(0.190"NOMINAL). CHANGE OUT MILL. " D331 AND REAMER BOTH COME OUT 3.80" GO,3.79"NO-GO. PUT ON NEW WINDOW MILL,3.80"GO,3.79" NO-GO. MAKE UP BHA#4. INJECTOR ON: 09:25 ------------- 09:30 - 12:20 2.83 STWHIP N 9,224.00 WEXIT RIH BHA#4. RATE: 1.06 BPM IN/1.56 BPM OUT 8.57 PPG IN/8.62 PPG OUT TIE-IN DEPTH,CORRECT+3 FT. DRY TAG WHIPSTOCKAT 9,223'. 12:20 - 16:15 3.92 STWHIP P 9,224.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"LINER PER BAKER REP FROM 9,222'MD TO 9,224.5'MD -RATE:2.87 BPM IN,2.87 BPM OUT -MUD WEIGHT:8.58 PPG IN,8.62 PPG OUT -DWOB:1-3 KLBS -CIRC PRESSURE: 2,600-2,750 PSI sYpr� 16:15 - 18:30 2.25 STWHIP P 9,225.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"LINER PER � BAKER REP FROM 9,224.5'MD TO 9,225'MD ,'2 G -RATE:2.86 BPM IN,2.87 BPM OUT f -MUD WEIGHT:8.58 PPG IN,8.62 PPG OUT -DWOB:2-3.3 KLBS -CIRC PRESSURE: 2,650-2,750 PSI 18:30 - 22:50 4.33 STWHIP P 9,225.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"LINER PER BAKER REP FROM 9,225'MD TO 9225.5 -RATE:2.86 BPM IN,2.87 BPM OUT -MUD WEIGHT:8.58 PPG IN,8.62 PPG OUT -DWOB:2-3.3 KLBS -CIRC PRESSURE: 2,650-2,750 PSI !STALLED. COME OFFLINE, PICKUP AND RESTABLISH PARAMETERS. 22:50 - 00:00 1.17 STWHIP P 9,225.00 WEXIT MILL 3.80"WINDOW IN 4-1/2"LINER PER BAKER REP FROM 9,225.5'MD TO 9225.67' -RATE:2.88 BPM IN,2.89 BPM OUT -MUD WEIGHT:8.58 PPG IN,8.62 PPG OUT -DWOB:2-3.3 KLBS -CIRC PRESSURE: 2,669-2,840 PSI Printed 6/6/2018 3.23.19PM "AII depths reported in Drillers Depths* IT II= 4-1/16"CIW V aLFEAD•= McEVOY • F-13B ivy NOTES: AGTUATOR= BAKER C MITIALK KB.aa 63.5' REF aEv= a0.26 BF ECFV= 35.98' 2023' �4-1/2"HES X NP,D=3.813" KOP= 3400' 20'X 30'INSULATED - -110 I Max Angle 47"@ 9485' CONDUCTOR Datum ND= 9231' — 259q' H 9-5/8"DV PACKER Datum TV D= 8800'SS I J ` GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80 BTRS,D=12.347" - I 2665' ST MD TVD DEV TYPE VLV ATCI- PORT DATE 4 3740 3727 17 MMG DMY RK 0 12/25/17 Minimum ID =3.725" @ 8850' 3 5925 5809 12 MMG DAY RK 0 12/25/17 4-1/2" HES XN NIPPLE 2 7406 7240 25 KBG2 DMY BK 0 04/21/13 1 8633 8349 26 KBG2 DMY BK 0 04/21/13 TOP OF 7"LNR H 6462' is. I 6462" H9-5/8"X 7"BKR ZXFN LTP,13=6.19" 9-5/8"W-IPSTOCK(03/31/13) H 6638' `--- 6477' -19-5/8"X 7"BKR FLEX LOCK HGR,D=6.270" 9-5/8"CSG,47#,L-80 BTRS,D=8.681" H "6638' MILLOUT WINDOW (F-13B) 6638'-6655' ' —1 8710' -I4-1/2"HES X NE',D=3.813" z C 8741' -17"X 4-1/2'HES TNT PKR,D=3.856' I 8778' H4-1/2"HES X NP,D=3.813" 8860' -14-1/2"HES XN NP,D=3.725" TOP OF 4-1/2"LNR --I -8840' 8850' Hr X 5"BKR ZXP LIP w/11'PBR,D=4.340" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, H 8863' 8863' -14-1/2"WLEG,D=3.958" .0152 bpf,ID=3.958" 8858' H ELMD TT LOGGED ON 06/13/13 \ 8874' Hr X 5"BKR FLEX LOCK HGR,D=4.318" 7"LNR,26#,L-80 VAM TOP HC,.0383 bpf,D=6.276" H 9033' $887• {5"X 4-1/2"LNR XO,D=3.958" PERFORATION SUMMARY REF LOG:MWD-GR ON 04/17/13 ANGLE AT TOP PERF:46"@ 9448' 9222' H4-1/2"BKR WFPSTOCK w/RA TAG(04/09/18) Note:Refer to Production DB for historical perf data tiO SIZE SPF NTERVAL Opn/Sqz DATE SQZ 9269' -14-1/2"BKRCBP(04J09/18) 2-7/8" 6 9448-9455 C 08/18/13 2-7/8" 6 9485-9495 C 12/30/15 III 2-7/8" 6 9500-9540 C 06/12/13 I BPTD - 9591' I 4-1/2"LNR,12.6#,13CR-85 VAM TOP, --I 9678' .0152 bpf,D=3.958" DATE REV BY COIv?IBVTS DATE REV BY CONI UNITS PRUDHOE BAY UNIT 02/28/80 ? INITIAL COMPLETION 07/16/13 RKT/JMD GLV C/O(07/04/13) WB..L: F-13B 12/06/96 ? SIDETRACK(F-13A) 09/06/13 SET/JIVE) ADPERFS(08/18/13) PERMIT No:' 121410 04/23/13 PKR272 SIDETRACK(F-13B) 01/07/16 LAC/JMD ADPERFS(12/30/15) API Nb: 50-029-20434-02 04/30/13 BA/PJC DRLG DRAFT CORRECTIONS 12/27/17 CJWJMD GLV C/O(12/25/17) SEC 2,T11 N,R13E,1988'FM_&2415'FWL 05/16/13 FM/JMD FNAL ODE APPROVAL 04/10/18 NXW/JMD SET CDP&WS(04/09/18) 06/14/13 ATO/PJC PERE/ELMD TT LO(6/12-13/13) 06/07/18 JNUJMD ADDED REF/BF&EDITED WS DEPTH BP Exploration(Alaska) I • Loepp, Victoria T (DOA) From: Ciolkosz, Ryan R <Ryan.Ciolkosz@bp.com> Sent: Monday, March 05, 2018 10:18 AM To: Loepp,Victoria T(DOA) Subject: F-13B Sundry#318052 & F-13C Permit Attachments: Nabors CDR2 BOPE Stack- Bighole (11-21-17).xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, I was reviewing F-13C permit and F-13B sundry and realized that I attached the old CDR2 BOPE schematic both of them. Please see the correct BOPE schematic attached. Thanks, Ryan Ciolkosz Drilling Engineer BP Exploration Alaska Office: (907)564-5977 Cell: (907)244-4357 SCANNED 1 • • Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis — — — - Topof7"Otis 1 It CDR2 Rig's Drip Pan Distances from top of riser {J=:= Excluding quick-test sub I 4-- 7-1116"5k Flange X 7"Otis Box Top of Annular I 6.0 ft fr---cid 1.-/- '\ Hydril 7 1/16" Top of Annular Element 6.7 ft Annular J Bottom Annular I 8.0 ft 1 ► .minim Blind/Shear CL Blind/Shears 9.3 ft 4iimil 2-3/8"Pipe/Slips CL 2-3/8"Pipe/Slips I 10.1 ft I ►$•._, .I 61J1L _ B2 B3 P 8 Kill Line Ell] 1 .:41II• s m tl1 ., 1110 1 I 1 3. —1 r r2 Cross r 2-3,8"z 3-112"VBRs I CL 2-3/8"x 3-1/2"VBRs I 12.6 ft ---►low 4...1 AV S 2-318"PipelSlips _ CL 2-3/8"Pipe/Slips 13.4 ft -a - i V CL of Top Swab I 16.0 ft I ►►♦� —Swab Test Pump Hose • ' ' • if T1 ie T2 ►�� 4 CL of Flow Cross I 17.4 ft I .4', -s�' ► Master CL of Master I 18.8 ft I . W.. 1111111 Villriliti LDS _ . o1:4 : . .. al- IA Gr . nr lir 4 OA II It I II II LDS I I .- -. Ground Level i I 1 • • `,OF Tit 40)11/7i' THE STATE Alaska Oil and Gas OfAT AKA Conservation Commission llr#— 333 West Seventh Avenue t ' V GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 7 , wh �,�;_ P Main: 907.279.1433 A ,S� Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna J. Egbejimba Engineering Team Leader—CTD&RWO ' BP Exploration(Alaska) Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool,PBU F-13B Permit to Drill Number: 212-141 Sundry Number: 318-052 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. Asrovided in AS 31.05.080, p within 20 days after written notice of this decision, or such further time as the AOGCCgrants forgood cause shown,aperson affected byit mayfile 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, (A7C0 — Hollis S. French Chair DATED this t day of March, 2018. RE"'T' "5 2C18 STATE OF ALASKA RECEIVED •ALASKA OIL AND GAS CONSERVATION COMItI ON APPLICATION FOR SUNDRY APPROVALS n g 20 AAC 25.280 FEB 8 7 2018 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 piOger�ttiorss• yiyaf Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Chang*34, gr.iCp 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 Nu er:- 12-141 • Exploratory 0 Development p •, ,.. ; 3. Address: P.O.Box 196612 Anchorage,AK 92 6. API Number: 50-02434-02-00 • 99519-6612 Stratigraphic 0 Service ❑ 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 El PBU F-13B • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028280 • PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9680 4 9202 • 9591 9140 2318 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 47-127 46-127 Surface 2816 13-3/8" 46-2862 46-2861 5380 2670 Intermediate 6594 9-5/8" 44-6638 44-6516 6870 4760 Liner 2571 7" 6462-9033 6341-8711 7240 5410 Liner 828 4-1/2" 8850-9678 8545-9200 9020 8540 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9448-9540 9041-9104 4-1/2"12.6# 13Cr85 42-8862 Packers and SSSV Type: 4-1/2"HES TNT Perm Packer Packers and SSSV MD(ft)and ND(ft): 8741/8446 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary Il Wellbore Schematic m 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch El Exploratory 0 Stratigraphic 0 Development Q . Service 0 14.Estimated Date for Commencing Operations: February 28,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended El • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkosz,Ryan R be deviated from without prior written approval. Contact Email: Ryan.Ciolkosz@bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 5977 Authorized Title: En•in��eer/iing Team Leader-CTD&RWO / Authorized Signature: /r • ,,, - _ Date: a 7/g Q is p V� / COMMISSION USE ONLY/// Conditions of approval:Notify Commission so that a representative may witness Sundry Number Plug Integrity 0 BOP Test [' Mechanical Integrity Test 0 Location Clearance ❑ 3V3 - 0G2 Other: SOP t-5 t .1-0 3 5-0 C7 p 51 Anrvla� re- � ve' frr :�r51- I-0 y5°' Ps�si r�,t�� 1 Post Initial Injection MIT Req'd? Yes 0 No 61,--- �`ft M tr P iv," P /� r A1?r0 ✓7* Spacing Exception Re wired? Yes 0 No / cr as Q C 2-5- 5 , ` 1 2 e.‘---)o� p gqd Subsequent Form Required: 61:220-... APPROVED BYTHE ^ ft Approved by: COMMISSIONER COMMISSION Date: 5 fib kn. 31 ill est's & Rt'w . LL N' . S .' - AL 2r18 .�� ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz b-yep CTD Engineer '# Date: February 7, 2018 Re: F-13C Sundry Approval Sundry approval is requested to plug the F-13C wellbore as part of the drilling and completion of the proposed F- 13C CTD sidetrack. Parent well, F-13B has no remaining value and there are no good opportunities to add new perforation to improve well performance. Proposed plan: Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on or around June 1st, 2018. E-line unit will set a CTD whipstock. CDR 2 will mill a 3.80" window in the 4-1/2" liner and drill an lvishak well in Zone3/2. The lateral will be completed with a 3-1/2" x 3-1/4' x 2-7/8" 13Cr-80 liner which will be cemented and perforated. This Sundry covers plugging the existing F-13B perforations via the F-13C liner cement lob or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)) and via posi-set plug. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. /� C�n l 11(' rockGD"dv for l 4d tet'// hq drOPW PP 41.- /.1 /- GU�• � P O/ /IS Qt/Q/ 61CF/s7� L✓*,'fi i4 P,1 qK�'f e if cc /h���Sr!/ Do vt % wh,'le Ar PCI a,.vape �� N js� j tic god YIIL wOt C cuiject— wed if I r a t1ti �1ro�vt� Oi°Sy'^i rkce/� �c �e cif►'f( Sl,cad allot,,. kir I awe/ /e cOde, 144 1O6c r1 , of fie A/ ,/e0 7 • • CTD Drill and Complete F-13C program: Start Date: February 28th, 2018 Pre-Rig Work: MASP: 231.8_psi 1. E: Set CIBP 4-1/2" Monobore Whipstock 2. F: A/EL: Displace Well with 11)/0 KCL & FP. Pressure test CIBP to 2500 psi 3. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 4. 0 Remove wellhouse, level pad Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.80" window and 10' of rathole. Swap to 8.6 drilling mud 3. Drill 4-1/4" Build and lateral with GR/Resistivity to TD 4. Run 3-1/2" x 3-1/4" x 2-7/8" 13Cr-80 liner 5. Pump primary cement leaving TOC at TOL. 36.2 bbls of 15.3 ppg liner cmt planned 6. Test liner lap to 2,400 psi. 7. Freeze protect well, set BPV, RDMO Post-Rig Work: 1. V: Tree work as necessary 2. DHD: liner lap test. FB to test liner lap if DHD cannot 3. C: RPM log and perforating (100') 4. S: Set live valves. If liner lap fails, install LTP 5. F: Pressure test LTP (if installed) *Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka TREE= 4-1/16"CPA/ •WELLFEAD= MCEVOY F-1 3B i S NOTES: ACTUATOR= BAKER C NTIALK KB.ELE1 63.5' BF.ELEV= 34.60' /) ) KOMax A �9 le 47 3400 / 2023' —14-1/2"HES X Nom,13=3.813" @ 9485' 20'X 30'INSULATED —110 ( 0 Datum M)= 9231' CONDUCTOR Datum ND= 8800'SS 2594' —19-5/8"DV PACKER 13-3/8"CSG,72#,L-80 BTRS,D=12.347= TREE= 4-1/16"CIV 1NaL=EAD= McEVOY • F-1 _1 3 C SA NOTES: 1 ACTUATOR= BAKER C WALK KB.ELL), 635 BF.ELEV= 34.60' — KOP= 3400' Max Angle 47 @ 9485 I 0 2023' —{4-1/2'HES X NP,D=3.813" 20'X 30'INSULATED-- ^-110 + Datum MD= 9231' CONDUCTOR Datum TVD= 8800 SS 2594' 9-5/8"DV PACKER —{ 13-3/8"CSG,72#,L-80 BTRS,D=12.34r — 2665' L GAS LIFT MANDRELS ........_ ST MD 1 V O DEV TYPE VLV .ATCF PORT DATE 4 3740 3727 17 MMC DOME RK 16 07/04/13 Minimum ID = 3.725" @ 8850' 3 5925 5809 12 MMG SO RK 20 07/04/13 4-1/2" HES XN NIPPLE 2 7406 7240 25 KBG2 DMY BK 0 04/21/13 1 8633 8349 26 KBG2 DMY BK 0 104/21/13 TOP OF 7"LNR H 6462' U6462' —19-5/8"X 7"BKR ZXFN LNR,D=6.19" 9-5/8"WHPSTOCK(03/31/13) H 6638' 6477' —{9-5/8"X 7"BKR FLEX LOCK HGR,D=6.276" 9-5/8"CSG,47#,L-80 BTRS,D=8.681" —{ —6638' MLLOUT WINDOW (F-136) 6638'-6655' 8710' HI4-1/2"HES X NP,D=3.813" 8741' —17"X 4-1/2"HES TNT PKR,D=3.856" 8778' I—I4-1/2"HES X NP,D=3.813" S I ir TOP OF 4-1/2"LNR --1 —8840' ' )' 8850' H4-1/2"HES XN MP,I, n." _� 8850' --17"X 5"BKR ZXP LTP w/11'PBR,ID=4.340" 4-1/2"TBG,12.6#,13CR 85 VAM TOP, —1 8863' 1 0152 bpf,D=3.958" 8863' —I4-1/2"WLEG,D=3.958" 8858' —l'ELMD TT LOGGED ON 06/13/13 7"LNR,26#,L-80 VAM TOP HC,.0383 bpf,D=6.276" —{ 9033' 8874' H7-X 5"BKR FLEX LOCK HGR,D=4.318" 8887' --15"X 4-1/2"LNR XO,D=3.958" 9100' —13 70"DEROY M NI SLEEVE,D=3.00' 3-1/2"LNC,9.2#, 13Cr-80 STL,ID-2.992" H 9133' 9120' —14-1/2"FES X NIP,D-2.813" 1 4-1/2"KB Packer Whipstock —j 9224' 6 3-1/4"LW,6.6#,13Ct-80 I-I 10200' TC11, 0079 bpf,D=2.85"J RENFORATIONSLWARY RB'LOG IAM)GR ON 04/17/13 ANGLE AT TOP FEW 46'itg 9448' Nolo Refer to Rod Ghon LB to/hstorlccel pat dais I SPF 8 'SIZE S41 1/41132VAL DATE SOZ 7/8' 6 9448-9455 0 08/18/13 !-7/8' 6 9485-9495 0 12/30/15 I -718' 6 9500-9540 0 06/12/13 ` BPTD — 9591' I 4-1/2"LNR,12.6#,13CR-85 VAM TOP, —1 9678' .0152 bpf,ID=3.958" ~at*' ♦ 2-7/8",6.4#,130-80 STL,D=2.441" —1 -12208' DATE REV BY COMMENTS DA TE REV BY COMMENTS PRIDHOE BAY UNIT 02/28/80 ? INTIAL COMPLETION 06/14/13 ATO/PJC RAF/ELM)TT LO(6/12-13/13) VNELL: F-13B 12/06/96 ? SIDETRACK(F-13A) 07/16/13 RKT/JND'GLV C/O(07/04/13) REIT No:'2121410 04/23/13 PKR 272 SIDETRACK(F-13B) 09/06/13 SET/JMD ADPERFS(08/18/13) AR No: 50-029-20434-02 04/23/13 PJC DRLG DRAFT CORRECTIONS 01/07/16 LAC/JMD ADPERFS(12130/15) SEC 2,T11 N,R13E, 1988'FNL&2415'EWE 04/30/13 BA/PJC DRLG DRAFT CORRECTIONS 05/16/13 FMUM) FINAL ODE AFFROVAL BP Exploration(Alaska) Well Blank •DR2AC BOP Schematic •Date _ Quick Test Sub to Otis 1 -1.1 ft Top of7"Otis 0.Oft - —CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub Top of Annular 0.0 ft t� ``®� 7-1/16"5k Flange X 7"Otis Box CHydril71/16 Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft s. .'.nri Blind/Shear CL Blind/Shears I 3.3 ft I ► 2-3/8"Pipe/Slips CL 2-318"Combi's 4.1 ft B5 - I B6 " ' " :7I BS Ai AA „ }I!. 7-1/16" AIR ■11 5 5. Deployment Line "� F PAi YI iW. 11k Sk Mud IiW �'"". iYiY Cross iii. al III III 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft 2-3/8"x 3-112"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft --- B1 F B2 B3 B4Choke Line Kill Line 11 _ tOp•�4. sir A Pi Ill III Blind/Shear CL Blind/Shears 10.0 ft ► ' ell 2-3/8"Pipe/Slips i., CI 2-3/8"Combi's 10.7 ft ► '''• • CL of Top Swab 13.3 ft +Swab 2 Test Pump Hose fSwab1 CL of Bottom Swab 14.8 ft • 4 4. T1 if T2 oP CL Flow Tee 16.2 ft _ •�• • • - BOP2 CL of SSV 17.5 ft M t Master 2 } Fusable CL of Master Valve 19.0 ft] BOP1 1,1' Master 1 LDS 20.5 ft ----o.-_, f'+ 11 ❑ II II 11 II ti II n n Gound Level !4 n i ii II II • 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 work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug Stat Tech for Redrill" box, 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. • • A X00 Thousand Cubic Feet of Gas ("MCF") per MonthTc 0 O o O O O O O O N O i O O O O O O p p O O ml O a,i' ani .4 .- ep O i .4 .i !-I sI I pO2 co 44. l"1 c { o it NN r 1I ! N N h f o m .. i i E i >rn INN . 111 3 CO vM IIII010111 G � Ng �� Z gin Jinni . :731 Q J m � lh a w CO o o z vIclo = 0 HI 0 a (HMV 9 a cc i . h �.,c. 1 3 !rIIIIIII m . , j° ; 't1OIIIIllJIIIIl '': 111111110111111 C Q Q J Q 445.Z M Q .0 a Ce O m O 2. O J a a Cl. E V ! o W , loe o O O O O O O• `� °/ ' O O O O O .4 O O O O ,i O O O O .-1 a-4 Lnuow Jed aa4eM;o siaaaee Jo y;uow aad no jo siaaae8 STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMMIS ION . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-141 3. Address: P.O.Box 196612 Anchorage, Development H Exploratory El AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20434-02-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PBU F-13B 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: Total Depth: measured 9680 feet Plugs measured feet RECEIVED true vertical 9202 feet Junk measured feet JAN y ���L Effective Depth: measured 9591 feet Packer measured 8743 feet Jf 1 U true vertical 9140 feet Packer true vertical 8447.63 feet ® CC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"x 30" 47-127 47-127 Surface 2637 13-3/8"72#L-80 46-2683 46-2683 4930 2670 Intermediate 6595 9-5/8"47#L-80 44-6639 44-6517 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9448-9455 feet 9485-9495 feet 9500-9540 feet True vertical depth: 9041 -9046 feet 9066-9073 feet 9077-9104 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr85 45-8864 45-8557 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: CA EV i- LH I ;!:,,q, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 239 21077 426 920 1972 Subsequent to operation: 387 13562 1180 1920 1719 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development H Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil H Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ 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 Cfi.1. C., Phone +1 907 564 4424 Date 1/13/16 Form 10-404 Revised 5/2015 /VVvi_ l/2Z/f , RBDMS JAN 15 2016 Submit Original Only ?$ /.b • • a> Q. 0o 000 caN- (D O N Ln 00 00 U N 0 0 0 0 0 i CO I� N N • O CO N O co ▪ V CO O CA N co I-- N cN r-- co N LO CO LU I- N LO N CO a0 CA 00 i H N V 4 V co in Q� r, MO 00 00 co co O CO N O CO O I- 00 .0 N CO O CA 00 C.) I I I I z Q co co CO LC) in L V (0 CO V C LL W0. LCA (0 O O a0 00 CO 00 0 0 _ J -_J c' co co N N X *k co co N (0 r N co Ln f,_ N N 2 t 0) C▪ 00 CO L() LO co CD N O N °D CO J W C O W 0 • U • ZWUJW O D H Z_ Z_ D U U) Z J J F- • • Packers and SSV's Attachment PBU F-13B SW Name Type MD TVD Depscription F-13B TBG PACKER 8742.52 8447.63 4-1/2" HES TNT Perm Packer F-13B PACKER 8869.31 8562.25 5" Baker ZXP Top Packer . 0 • 0 > a 0 2 o / © * £ L ƒ ®IT) \ _k \ / Z > 0 \ / \ k 0) CO z 0 U) _ / \ k © Z $ © / 0 2 0 n \ CO m il 2 / 0 0 D / $ R E > O P k < / $ a_ n k i 0 / / / a 0 \ o _1 R _ o > � za -Sk o/ / 6 w /® f = t t ± 8 $ zOc ±0 al _ e o » / / ;)-11.1_91 LLI/ p / 2 ± ± _ e 2 2 = 2 2 2 E s- k E \ / 0- / / 0 / / 2 ƒ 7 k --1 % \ a 2 a- c z2m oa C) Z @ / Q / u $ \ ® = C) 0 / / 70 - � / � 003 \_ < _i / 0 a) % J mm@O9 � ,- < pe \ O / w $ _ 7 a 2 cC 0 I = R a.< $ o O c ) O .g •n m G 2 R m 9 r G , a 0 = = m � � / 2 _...u) -•-• E -i / ƒ � $ \ LLi ui -o t 0. t g - o_t I ¢ c < G = < c » ) e c p o m 2 * 6 = G ± o = ,-- I R / ' a R Q C a o - II ' = _I O 9 2 2 f 2 to 2 2 = / a) : w to / k E 4 bcNi -1 0 < ƒ 9 $ _ $ / 6 \ / \ \ S % ƒ / £ 7 / f \ / / 11 f Lii \ I A % - E � E m .= z s c > -12 t E _ a) CIS 121 / O / < ., 001W(-) E / A / (-1 -' \ E / / % / E < O N G ƒ I- I 0 e I A o ¥ _ \ z H c L ± / R p ± / e ± 7 < / ° E q LLI / R + �� O ƒ k / ± - 2m $ 2mOm / �/ / E& / / 2 \ / / D0 \ / / \ / / K 2 / \ \ / 2 o 8 j x A ct - I O -1 - z ^ R Z k© o \ \ \ -1 0 - 6 m E Z / \ / � q / \ / 222 $ / 2 2 / / / ƒ ƒ k \ / 6R « \ / f i % i - \ i < < < 00 �J (t) < * : / ƒ 0 \ / f / \ / \ / / L < to r r n r \ N N N N N m e o I-> / N \ \ \ d ~ = N 6 % // \ \ 0 < TREE= 4-1/16'CM • F-1 3B SAFETY NOTES: VVELLTEADz- McEVOY ACTUATOR- BAKER C FITIALK KB.ELB 63.5' BF.EI_EV= 34.60' KOP= 3400' 2023' -4-1/2"HES X MP,D.3.813" MIX Angle= 47°@ 9485' 20 X 30't4 -110 SULATH3 - <.1 I W..- — Datum PAD= 9231' CONDUCTOR Cetum TVD= 8800'SS 2594' -19-5/8"DV PACKER 13-3/8"CSG,72#,L-80 BTRS,13=12.347" H 2666' l GAS LIFT MA ICRELS ST /44) ND DEV TYPE VLV ,ATC1. PORT DATE 4 3740 3727 17 ka43 DOW RIK 16 07/04/13 Minimum ID = 3.726" ( 8860' 3 5925 5809 12 TVG SO RK 20 07/04/13 4-1/2" HES XN NIPPLE I 2 7406 7240 25 KBG2 DMY BK 0 04/21/13 1 8633 8349 26 KBG2 [WY BK 0 04/21/13 TOP OF 7"LTR - 6462 6462' -9-5/8"X 7"BKR ZXPN LNR,ED=6.19" 9-5/8"Wt-IPSTOCK(03/31/13) - 6638' 6477' -9-5/8'X 7"BKR FLEX LOCK HGR,I)=6.276" 9-5/8"CSG,47#,L-80 BIKS,1)=8.681" - -6638' II FALLOUT AINDOW (F-136) 6638'-6655' I I 8710' -4-1/2"If-,X MP,ID=3.813' 8741' -I r X 4-1/2"HES TNT PKR,ID=3.856" E X I I I 87713' -4-1/2'HES X NP,D=3.813' 8860' -4-1/2"I-ES XN NIP,ID=3.725" TOP OF 4-1/2"LM - -8840' II 8850' -7"X 5"BKR ZXP LTPw/11'PBR,ID=4.340" 4-1/2"TBG,12.6#, 13CR-85 VAN TOP, - 8863' .0152 bpf,13=3.958' 8863' -4-1/2'VVLE-G,1)=3.958' 8858' H6mo 11 LOGGED ON 06/13/13 7'LNR,26#,L-80 VAM TOP I-IC,.0383 bpf,I)=6.276' - 9033' 8874' H ' X 5'BKR FLEX LOCK HGR,10=4.318' \ IL 8887' H5"X 4-1/2'LM X0,1)=3.958' PERFORATION SUMMARY REF LOG:14#14D-GR ON 04/17/13 ANGLE AT TOP PERF:46°@ 9448' Note:Refer to R-oducbon DB for historical perf data SIZE SPF NIERVAL Opn/Sqz DATE SQZ 2-7/8' 6 9448-9455 0 08/18/13 2-7/8" 6 9485-9495 0 12/30/15 2-718' 6 9500-9540 0 06/12/13 BPTD -I 9591' 4-1/2'LNR 12.6#,13CR-85 VAM TOP, - 9678' 1 .0152 bpf,0=3.958" DATE REV BY COMMENTS DATE REV BY MOMENTS PRUCHOE BAY UMT 02/28/80 ? IMT1AL COMPLETION 06/14/13 ATO/PJC FEW/ELM)TT LO(6/12-13/13) VAIL: F-138 12/06/96 ? SIDETRACK(F-13A) 07/16/13 RKT/JkA) GLV 00(07/04/13) PERMT Tib:' 121410 04123113 PKR 272 SIDETRACK(F-138) 09/06/13 SET/AA) ADFERFS(08/18/13) API No: 50-029-20434-02 04/23/13 PJC CIRLG DRAFT CORRECTIONS 01/07/16 LACJAA) ADPERFS(12/30/15) SEC 2,Til N,R13E, 1988'FPL&2415'PM. 04/30/13 BA/PJC DRLG DRAFT CORRECTIONS 05/16/13 RWAR) FINAL OCEAFFROVAL BP Exploration(Alaska) Image Project Well History File Cover Page 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 b direct inspection of the file. IQ - L i+ I Well History F'le Identifier Organizing (done) Two-sided ❑ Rescan Needed R CAN: OVERSIZED: NOTES: olor Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: /BY: Maria Date:'a a.C�� ! q /s/ 1/11 Project Proofing BY: 411012. Date: Ic9-- goD"' 1 /s/ I Scanning Preparation x 30 = 1 O + a = TOTAL PAGES a a.a, pt,(Count does not include cover sheet) a.,o P... BY: AM Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: caVh3(Count does include cover sheet) Page Count Matches Number in Scanning Prepar tion: YES NO BY: cMa-.ria Date: /c94 A l i Lt /s/ (014p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES _010 TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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O L., ,, U a E a OE 0— O a o p g E E owW rnwwLUw3 LL 2 0 Ga _ I ? 0 Cl. 0 1 0 0 0 0 0 N N 94 m O 01 O Tr o Z ea N 0)N _0 T O 5 O O N d 7 O Z F. J I�f'! Z 0 O ' J Cl) 7 y rg CO i co cr) I o Ce a 2 11z63 a o 0 LU 0 J 0. LU w U 0. o Z QN J o 0 co° 2 ' o O N a 0 UM o m Q el a LL Z cc-) = O N /�� Q (h W m V O a) cn o0 Qm a o I— .Q Q ° E 2 0 p E U m Z m 3 N O N O > m -o N d N d N j d 5. re 0 O 1Cl w 0 16CJ a CJ E O ` a 0 a 0 Guhl, Meredith D (DOA) i): 2 2-11-1 From: Mammadov, Famil [famil.mammadov@bp.com] Sent: Monday, March 10, 2014 10:54 AM To: Guhl, Meredith D (DOA) Subject: RE: Clarification: Directional Survey PBU F-13B Meredith, Please ignore the previous email. Both F-13PB1 and F-13B surveys dated 26 April 2013 were final definitive surveys submitted to us by Baker Hughes Regards Famil From: Mammadov, Famil Sent: Monday, March 10, 2014 10:02 AM To: 'Guhl, Meredith D (DOA)' Subject: RE: Clarification: Directional Survey PBU F-13B Hello Meredith, The surveys attached in the PTD form for F-13B PB1 were "Actual Final" surveys, i.e.they were corrected good surveys by Baker Hughes. Unlike Schlumberger, Baker Hughes do not label them as"Definitive"which may cause have caused some confusion. As for F-13B well itself, it was the "Final Planned" directional plan that was submitted. Let me know if you have any further questions Regards Famil From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, March 07, 2014 9:56 AM To: Mammadov, Famil Subject: Clarification: Directional Survey PBU F-13B Dear Mr. Mammadov: I am completing the final compliance review for Prudhoe Bay PBU F-13B, PTD 212-141, API 50-029-20434-02-00, completed on 4/23/2013. In reviewing the files provided, I noted that the Survey Reports,dated 26 April 2013, are not labeled "definitive" for either F-13B or F-13B PB1. Please confirm that the directional survey reports provided are in fact the definitive survey reports. Please confirm by March 14, 2014 so I may complete the compliance review. If you have any questions, please contact me. Thank you, Meredith Guhl 1 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 2 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, March 07, 2014 9:56 AM To: 'famil.mammadov@bp.com' Subject: Clarification: Directional Survey PBU F-13B Dear Mr. Mammadov: I am completing the final compliance review for Prudhoe Bay PBU F-13B, PTD 212-141,API 50-029-20434-02-00, completed on 4/23/2013. In reviewing the files provided, I noted that the Survey Reports, dated 26 April 2013, are not labeled "definitive" for either F-13B or F-13B PB1. Please confirm that the directional survey reports provided are in fact the definitive survey reports. Please confirm by March 14, 2014 so I may complete the compliance review. If you have any questions, please contact me. Thank you, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 • 1 STATE OF ALASKA RECEIVED A. ...KA OIL AND GAS CONSERVATION COMM,_-SON SEP 1 6 201 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U • Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4 Well Class Before Work: 5 Permit to Drill Number: Name BP Exploration(Alaska),Inc Development Exploratory ❑ 212-141-0 3.Address P O Box 196612 Stratigraphit❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20434-02-00 • 7 Property Designation(Lease Number) 8.Well Name and Number: ADL0028280 • PBU F-13B • 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s). PRUDHOE BAY,PRUDHOE OIL , 11 Present Well Condition Summary: Total Depth measured 9680 feet Plugs measured None feet true vertical 9201.71 feet Junk measured None feet Effective Depth measured 9591 feet Packer measured See Attachment feet true vertical 9139 56 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 46-126 46-126 0 0 Surface 2636 13-3/8"72#L-80 46-2682 46-2681 86 4930 2670 Intermediate None None None None None None Production 6592 9-5/8"47#L-80 46-6638 46-6516 14 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9448-9455 feet 9500-9540 feet True Vertical depth 9040.74-9045.62 feet 9076.64-9104.22 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured) Treatment descriptions including volumes used and final pressure. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation. 15 656 0 0 152 Subsequent to operation: 3210 15833 104 0 254 14.Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑Q • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work: Oil Q I Gas U WDSPLJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ D SUSP ❑ SPLUCJ 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 Garry.Catron(a-BP.Com Printed Name Garry Catron Title PDC PE Signature If004,41 67.7 ---- Phone 564-4424 Date 9/13/2013 ILS /€0.479 RBCNS OCT 11 204=�'` i /i.5-/i 3 Form 10-404 Revised 10/2012 Submit Onginal Only Packers and SSV's Attachment ADL0028280 SW Name Type MD TVD Depscription F-13B PACKER 8741 8366 4-1/2" HES TNT Perm Packer F-13B PACKER 8850 8464.49 4-1/2" Baker ZXP Packer a o000.00i000 Ry `,7 LS' FA �=Loo r- r� O;LoLOLO 0 Ln coO r- N'co f� I� U 1) 000r- 0000 '- N CO CO 1� Cr) N M 7 N O cr V CO C)) O d' Cr) CO CO CO c' CA CO CO M CO M M Cr) o M CO M CO Lf) LO LO 0 Co 0 (fl CO CO CO 00 0 s- 00 LO LO LO f- N N N CO LO LO O CO O O CA O N CO CO CO II II I II I I I H LOLO LC) O 44 4 co co co co co O LU LU LL) CO CO CO C a) coco co O O N M M M O M r-- I- co O CO CO CO N oCO CO CO CO CO CO CO CO O (A C) 0) CO N CO CO CO V COCICI }Fi CO N 0 CO (C) CNOO 0 Lf) CO CO co co co 0) N voococovv. 444 C c coaoaoao • Ln L() U) L() U) U) ` Q (000a000aoaoc- _� O COM M -I M CO CO O -� NOM *k *k *k N *k *k *k (i) N X *k (O CO CO N- CO CO CO NO N N N - N N N U N w N N N L° „) N N CI) r r r r .c N CO O O O �O I� co O O (3) M N N N C O N N N O 0 0 0 0 N O O O CO CV 00 0 0 J Z 0 O w ND DU 00 CD cua r cta c p u. Z Z Z O z w w w w O rxm m E O Z_ Z Z_ Z_ c , D J D O J J J J d U) 1- 1- 1- Daily Report of Well Operations ADL0028280 ***WELL S/I ON ARRIVAL*** (adperf) DRIFTED W/3.0" GAUGE RING -S/D @ 7549' SLM B&F w/ LRS RUNNING 2.795" GAUGE RING -TAG BTM @ 9556' SLM DRIFTED TO 9556' SLM w/3.25" GAUGE RING LRS PUMPED 75 BBLS DIESEL TOTAL&TBG LOCKED UP @ 3000# DRIFTED w/3.61" GAUGE RING -TAG BOTTOM @ 9556' SLM TAG XN NIP @ 8815' SLM w/3.80" GAUGE RING DRIFTED w/25' X 2 7/8" DUMMY GUNS -CANNOT PASS 9448' SLM, EVIDENCE OF ASPHALTINES DRIFTED w/3.70" GAUGE RING BARBELL- UNABLE TO PASS 9437' SLM 8/8/2013 ***CONTINUED ON 8/9/13 WSR*** ***JOB CONTINUED FROM 8/8/13 WSR*** (adperf) DRIFTED w/4 1/2" BRUSH & 3.50" GAUGE RING - CANNOT PASS 9439' SLM UNABLE TO REACH TD DUE TO APPARENT ASPHALTINES 8/9/2013 ***CALLED OFF JOB, WELL ELFT S/I, PAD OP NOTIFIED*** ***WELL S/I ON ARRIVAL***(E-LINE PERF) INITIAL T/I/0=2000/1780/50 PSI RIH W/GR/CCL/10'x2-7/8" PJ OMEGA HMX GUNS (7' LOADED) TAG TD AT 9478' PERFORATED INTERVAL 9448'-9455' (see log for gun specs) WELL S/I ON DEPARTURE, DSO NOTIFIED FINAL T/I/0=1950/1780/50 PSI 8/18/2013 ***JOB COMPLETE*** FEAD= McEVOY 41/16'CNV —F-1 3 B SAF-.Y NOTES: ACTUATOR= BAKER C NTALK KB. 63.5' I BF.BEV= 34.60' /I KOP= 3400' / 2023' -14-1/2"FES X NP,D=3.813" Max Angle=. 47" c@ 9485 20'X 30'NSULATEO H -110 u Datum MD= 9231' CONDUCTOR Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80 BTRS,D=12.347' H 2685' -L 2594' -{9 5l8"DV PACKER GAS UFT MANDRELS ST MD ND DEV TYPE VLV ,ATCF PORT DATE 4 3740 3727 17 NW DOME RK 16 07/04/13 Minimum ID = 3.725" @ 8850' 3 5925 5809 12 MMG SO RK 20 07/04/13 4-1/2" HES XN NIPPLE I- 2 7406 7240 25 KBG2 MY BK 0 04/21/13 1 8633 8349 26 KBG2 DMY BK 0 04/21/13 TOP OF 7"LNR - 6462' _ 6462' -9-5/8'X 7"BKR ZXFN LNR,D=619" 6477' -I9-5/8'X 7'BKR FLEX LOCK HGR,D=6.276" ./4 9-518"WHIPSTOCK(03/31!13) -I 6638' 9-5/8'CSG,47#,L-80 BTRS,D=8.681' H -6638' MLLOUT WNDOW (F-13B) 6638'-6655' ' ' 8710' -I4-1/2"FES X NP,D=3.813" Z 8741' -r X 4-1/2'FES TNT PKR,D=3.856' I r"— 8778' -14-1/2"FESS X NP,D=3.813" 8850' -I4-112"FES XN NP,D=3.725' TOP OF 4-1/2"LNR -I -8840' 41 8850' -17"X 5"BKR ZXP LTP w/11'PBR,D=4.340" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, - 8863' .0152 bpf,D=3.958' 8863' -14-12"WLEG,D=3.958" 8858' -I ECMO TT LOGGED ON 06/13/13 7"LNR,26#,L-80 VAM TOP HC,.0383 bpf,D=6.276" -I 9033' I` 8874' -I r X 5"BKR FLEX LOCK HGR,D=4.318' \y , 8887' -15'X 4-1/2"LIR XO,D=3.958' PERFORATION SUMMARY REL LOG:MVVaGR ON 04/17/13 ANGLE AT TOP PEW:460 @ 9448' Note:Refer to Roduction DB for historical pert data 1 SIZE SPF NT RVAL Opn/Sgz DATE civ 2-7/8" 6 9448-9455 0 08/18/13 2-7/8" 6 9500-9540 0 06/12/13 BPTD - 9591' 4-12"LNR,12.6#,13CR-85 VAM TOP, 9678' f106:*L` .0152 bpf,D=3.958" ►,t,+►*�' DATE REV BY COMMENTS DATE REV BY COMuElkITS I PRUDHOE BAY UNIT 02/28/80 ? INITIAL COMPLETION 06/14/13 ATO/PJC PERF/BJut TT LO(6/12-13/13) WELL: F-138 12/06/96 ? SIDETRACK(F-13A) 07/16/13 RKT/JM) GLV C/O(07/04/13) PE KIT No:.2121410 04/23/13 PKR272 SIDETRACK(F-13B) 09/06/13 SET/JWD ADPERFS(08/18/13) AR No: 50-029-20434-02 04/23/13 PJC DRUG DRAFT CORRECTIONS SEC 2,T11 N,R13E 1988'RI_&2415'FWL 04/30/13 BA/PJC_DREG DRAFT CORRECTIONS _ 05/16/13 FMJMD FNAL ODE APPROVAL BP Exploration(Alaska) RECEIVED STATE OF ALASKA JUL 0 9 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: • ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 1 b. Well Class 20AAC 25105 2OAAC 25110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions • One • ®Development 0 Service 2. Operator Name' 5.Date Comp.,Susp.,or Aband.: m. 12. Permit to Drill Number: ' BP Exploration (Alaska) Inc. • C/13/2013 4/Z*,)/Z013 • 212-141 313-160 3. Address' 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 • 3/10/2013 - 50-029-20434-02-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: • 4/17/2013 • PBU F-13B 1988'FNL,2865'FEL, Sec.02,T11N, R13E, UM 8. KB(ft above MSL): 80.26' 15.Field/Pool(s) Top of Productive Horizon: 232' FNL, 3748'FEL, Sec.02,T11N, R13E, UM GL(ft above MSL): 34.6' - Prudhoe Bay/Prudhoe Bay Total Depth. 9.Plug Back Depth(MD+TVD) 136' FNL, 3843'FEL, Sec.02,T11N, R13E, UM 9591' 9140' • 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16 Property Designation: Surface: x- 651958 y- 5974812 Zone- ASP4 9680' 9202' • ADL 028280 TPI. x- 651038 y- 5976549 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit. Total Depth.x- 650940 Y- 5976644 Zone- ASP4 None 18. Directional Survey: ®Yes 0 No • 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD/GR/at-bit-GR/RES, MWD/GR/RES/NEU/DEN • 6638' 6516' • 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20"x 30" _ Insulated Conductor Surface 110' Surface 110' 36" 8.5 cu vds Permafrost concrete 13-3/8" 72# L-80 Surface 2665' Surface 2665' 17-1/2" 3813 cu ft Arcticset II 9-5/8" 47# L-80 Surface 6638' Surface 6516' 12-1/4" 1164 cu ft Class'G', 130 cu ft Arcticset I N 7" _ 26# _ L-80 6462' 9033' 6341' 8711' 8-1/2" 142 sx Class'G' 4-1/2" 12.6# 13Cr85 8850' 9678' 8545' 9200' 6-1/8" 120 sx Class'G' 24. Open to production or injection? 0 Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 2-7/8"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr85 8863' 8741'/8446' 44;O146L614 y, Ifftl 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9500'-9520' 9077'-9090' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No 9520'-9540' 9090'-9104' ' ..11EL DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2200' Freeze Protect w/151 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc June 20,2013 Flowing Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 6/21/2013 6 Test Period ♦ 4 164 0 95 44116 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 160 1870 24-Hour Rate 4 15 656 0 26.7 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes 0 No 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 250.071. None Form 10-407 Revised 10/2012 v L_ /// /7/t CONTINUED ON REVERSE /7 Submit Original Only 29. GEOLOGIC MARKERS(List all formations ani ers encounter 30. FORMATION TESTS NAME MD ND Well Tested? ❑Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Coleville Mudstone 7126' 6986' None HRZ 7405' 7239' Base of HRZ/LCU 7606' 7421' Sag River 9015' 8695' Shublik/Shublik A 9063' 8738' Shublik B 9106' 8777' Shublik C 9124' 8792' Shublik D/Sadlerochit 9147' 8812' CGL/Zone 3 9301' 8934' Base of CGL/Zone 2C 9390' 9000' 23SB/Zone 2B 9491' 9070' 22TS 9565' 9122' 21TS/Zone 2A 9631' 9167' Formation at Total Depth: Zone 2A 9631' 9167' 31.List of Attachment Summary of Daily Drilling Reports,Summary of Post-Rig Work, LOT/FIT Summary,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Famil.Mammadov@bp.com Famil.Mamm ov,564-4135 Printed Na::ture.J0e Title: Drilling Technologist Lastufk0� Phone 564-4091 Date:7/g//.3 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. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation 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 13: 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 28. 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 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. Form 10-407 Revised 10/2012 Submit Original Only Id- BAKER Survey Report-Geographic 0 bp HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay TVD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13B Survey Calculation Method: Minimum Curvature Design: F-13B Database: EDM R5K-Alaska PROD-ANCP1 Casing Points Measured Vertical Casing Hole j Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,676.71 9,199.41 PRODUCTION LINER 1 4.500 6.125 9,031.71 8,709.86 DRILLING LINER 1 7.000 8.500 Formations , Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (1 5,959.81 5,843.26 WS1 6,194.06 6,074.26 CM3 7,020.28 6,888.26 CM2 7,386.53 7,222.26 CM1 7,420.75 7,253.26 Top HRZ 7,631.54 7,444.26 Top Kingak/LCU 7,930.81 7,715.26 TJF 8,105.40 7,873.26 TJE 8,383.98 8,124.26 TJD 8,664.36 8,377.26 TJC 8,828.47 8,525.26 TJB 8,925.49 8,613.26 TJA 9,036.56 8,714.26 TSGR 9,087.53 8,760.26 TSHU 9,155.05 8,818.71 TSAD 9,172.43 8,833.26 TSAD 9,178.47 8,838.26 45SB 9,262.15 8,904.26 42SB 9,329.17 8,955.26 TCGL 9,390.95 9,000.26 PGOC 9,421.81 9,022.26 BCGL 9,461.69 9,050.26 POWC ' 9,502.35 9,078.26 23SB 9,586.25 9,136.26 22TS Design Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 6,616.76 6,494.94 818.05 -124.37 TIP 6,638.00 6,516.14 819.38 -124.39 KOP 6,873.00 6,748.34 849.90 -135.72 End Inc+Trend 6,900.59 6,774.89 856.68 -138.87 Start MWD+IIFR+MS 9,680.00 9,201.71 1,852.31 -980.75 Projection to Bit Depth Checked By: Approved By: Date: 4/26/2013 10.27:05AM Page 5 COMPASS 5000.1 Build 61 TREE= 4-1/16"CAN F WELLHEAD= MEEVOY 1 3 B SAE ,OTES: ACTUATOR= BAKER C INMBE LK.E KB.ELEI 4.60' i BF.ELEV= 34.60' KOP= 3400' 1 I 2023' –4-1/2"HES X NP D=3.813" Max Angie= 47°@ 9485' 20'X 30'NSULATED H "110 I Datum MD= 9231' CONDUCTOR u Datum ND= 8800 SS L j 2594' –19-5/8"DV PACKER 13-3/8'CSG,72#,L-80 BTRS,D=12.347" –1 2665' GAS LIFT MANDRELS ST MD TVD DEV TYPE V LV .ATC- PORT DATE 4 3740 3727 17 MAG DOME RK 16 06/01/13 Minimum ID = 3.725" @ 8850' 3 5925 5809 12 MMG SO FE 20 06/01/13 4-1/2" HES XN NIPPLE I 2 7406 7240 25 KBG2 DMY BK 0 04/21/13 II- 1 8633 8349 26 KBG2 DMY BK 0 04/21/13 TOP OF 7"LNR –{ 6462' —1 ul 6462' –19-5/8"X 7"BKR ZXPN LNR,D=619" 6477' –19-5/8"X 7'BKR FLEX LOCK HGR 0=6.276' 9-5/8"WHPSTOCK(03/31/13) –1 6638' 9-5/8"CSG,47#,L-80 BTRS,D=8.681" – –6638' ML LOUT WNDOW (F-13B) 6638'-6655' ' '- 1 8710' H4-1/2"HE8XKIP,D=3.813" Z.- 8741' –17"X 4-1/2"HES TNT PKR,D=3.856" r—{ 8778' –14-1/2"HES X NP,D=3.813" 8850' H4-1/2"HES XN NP,D=3.725" TOP OF 4-1/2"LNR –i 8840' ' 8850' Hr X 5"BKR ZXP LIP w/11'FIBR,ID=4.340" 4-1/2"TBG,12.6#,13CR-85 VAM TOP, – 8863' 0152 bpf,D=3.958" 8863' –4-1/2'WLEG,D=3.958" 8858' –ELMD TT LOGGED ON 06/13/13 7"LNR,26#,1-80 VAM TOP HC,.0383 bpf,D=6.276" –{ 9033' 1\ 8874' --{7'X 5"BKR FLEX LOCK HGR,D=4.318" 8887' –15"X 4-1/2'LNR XO,D=3.958" PERFORATION SUMMARY REF LOG:MVD-GR ON 04/17/13 ANGLE AT TOP PERF:470 @ 9500' Note:Refer to Production DB for historical pert data _ SIZE SR= NTERVAL Opn/Sqz DATE SQZ 2-7/8" 6 9500-9540 Oo 06/12/13 BPTD --- 9591' 4-1/2"LNR,12.6#,13CR-85 VAM TOP, –1 9678' .0152 bpf,D=3.958" IP # 1 DATE REV BY COMMENTS DATE REV BY COIMENTS PRLDHOE BAY INET 02/28/80 ? IMTIAL COMPLETION 06/10/13 SF/JMD GLV C/O(06/01/13) WELL: F-13B 12/06196 ? SIDETRACK(F-13A) 06/14/13 DIV PJC TREE CIO(05/27/13) PERMIT No:"2121410 04/23/13 PKR 272 SIDETRACK(F-13B) 06/14/13 ATO/PJC FEW/ELM)TT LO(6/12-13/13) AR No: 50-029-20434-02 04/23/13 PJC DRLG DRAFT CORRECTIONS SEC 2,T11 N,R13E, 1988'FIS&2415'FW. 04/30/13 BA/PJC DRLG DRAFT CORRECTIONS 05/16/13 FM/J14.1) ANAL ODE AFIROVAL BP Exploration(Alaska) BP AMERICA LOT / FIT Summary Well Name: F-13B Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 03/31/13 FIT 6,647.00 6,525.03 10.80 324.00 3,984.80 11.76 04/14/13 FIT 9,055.00 8,736.18 8.70 500.00 4,448.31 9.80 Page 1 of 1 BP AMERICA LOT / FIT Summary Well Name: F-13BPB1 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 03/08/13 FIT 7,605.00 7,482.57 11.00 280.00 4,555.76 11.72 03/20/13 FIT 8,960.00 8,671.53 8.50 590.00 4,418.99 9.81 Page 1 of 1 North America-ALASKA-BP Page 1 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/16/2013 00:00 - 02:00 2.00 MOB P PRE BEGIN RON EVENT WITH PARKER 272 DRILLING RIG AT 00:00,COMPLETE SECURE OF MAST ON RACK,PRE-MOVE PLANNING MEETING HELD PRIOR TO DISCONNECTING FOR MOVE JACK MOTOR COMPLEX,SEPARATE FROM SUB WELLWORK TRANSFER PERMIT OPEN WITH DRILLSITE OPERATOR. NO WELLS ON PAD SHUT-IN FOR MOVING RIG BARRIERS FOR MIRU: TUBING: CP,KWF,BPV INNER ANNULUS: CP,KWF,PASSING CMIT-TXIA,MIT-IA,DOUBLE VALVE ON OUTLET OUTER ANNULUS: CSG PACKOFFS,PASSING MIT-OA,DOUBLE VALVE ON OUTLET 02:00 - 05:00 3.00 MOB P PRE PJSM WITH RIG CREW MOB MOTOR COMPLEX FROM CRAZY HORSE PAD BOOSTER AXLES NOT STEERING PROPERLY SET RIG DOWN AND TROUBLESHOOT HYDRAULIC STEERING 05:00 - 06:00 1.00 • MOB P PRE REPAIR STEERING MOB FROM CRAZY HORSE PAD TO SPINE ROAD IN DEADHORSE 06:00 - 18:00 12.00 MOB P PRE MOB FROM SPINE ROAD TO K-PAD ROAD j • 18:00 - 00:00 6.00 MOB P PRE MOB FROM K-PAD ROAD TO F-PAD 2/17/2013 00:00 - 05:00 5.00 MOB P PRE MOB MOTOR COMPLEX FROM K-PAD TO F-PAD SPOT COMPLEX ON NORTH SIDE OF PAD 05:00 - 13:30 8.50 MOB P PRE MOB SUB FROM CRAZY HORSE PAD TO EAST GUARD SHACK 13:30 - 21:00 7.50 MOB N RREP PRE MOVING GENERATOR HOSE CONNECTION ON AFTER COOLER FAILED SPOT RIG AT DS-1 AND WAIT ON CATERPILLAR TECHNICIAN REPAIR HOSE CONNECTION AND MOVE OFF DS-1 21:00 - 00:00 3.00 MOB P PRE MOB SUB TO FS-1 2/18/2013 00:00 - 06:00 6.00 MOB P PRE MOBILIZE SUB FROM FS-1 TO 3 MILES NORTH OF OXBOW INTERSECTION • 06:00 - 11:30 5.50 MOB P PRE MOBILIZE SUB TO K-PAD INTERSECTION Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 2 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 I81.55usft(above Mean Sea Level) Date From-To Hrs Task I Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 15:00 3.50 MOB N WAIT PRE TEMPERATURE DROPPED BELOW SAFE OPERATING LIMIT FOR FORKLIFT,-40 DEGREES F FIELD ENGINEER STOPPED MOVE 15:00 - 00:00 9.00 MOB P PRE MOBILIZE SUB FROM K-PAD INTERSECTION TO E-PAD INTERSECTION 2/19/2013 00:00 - 08:00 8.00 MOB P PRE MOBILIZE SUB FROM E-PAD INTERSECTION TO F-PAD 08:00 - 11:00 3.00 MOB P PRE SPOT SUB OVER WELL. 11:00 - 15:00 4.00 MOB P PRE SPOT MOTOR COMPLEX AND MERRY UP TO SUB. 15:00 18:30 3.50 MOB N WAIT PRE HALON`DISCHARGE AT SKID 50.RIG MOVE ON HOLD FOR SECURITY. 24 HOUR NOTIFICATION FOR INITIAL BOP TEST SENT AT 19:30. 18:30 - 00:00 5.50 MOB P PRE MOBILIZE MOTOR COMPLEX TO F-PAD FROM CRAZY HORSE PAD. -AT THE EAST CHECK POINT AT MIDNIGHT. 2/20/2013 00:00 - 06:00 6.00 MOB P PRE MOBILIZE MUD MODULE FROM EAST CHECK POINT TO AGI INTERSECTION. 06:00 - 11:30 5.50 MOB-" P PRE MOBILIZE MUD MODULE FROM AGI INTERSECTION TO INTERSECTION OF SPINE ROAD AND TWIN TOWER ROAD. 11:30 - 15:00 3.50 MOB P PRE MOBILIZE MUD MODULE DOWN SPINE ROAD TO F-PAD. 15:00 - 18:00 3.00 MOB P PRE SPOT MUD MODULE. 18:00 - 20:30 2.50 MOB P PRE CONNECT MUD MODULE TO DRILL MODULE. -INSTALL CROSS BEAMS. -MAKE UP INTERCONNECT LINES. 20:30 - 21:30 1.00 MOB P PRE RAISE AND PIN THE MAST. -PRE JOB SAFETY MEETING WITH RIG CREW. -MAST CAME OFF STAND AT 563K LBS. -MAX PULL AT 568K LBS. 21:30 - 00:00 2.50 MOB P PRE SKID RIG FLOOR AND MOVE HAUNCH. -PRE JOB SAFETY MEETING WITH RIG CREW. 1-SKID RIG FLOOR INTO POSITION. I-MOVE HAUNCH INTO PLACE. SIMOPS: -SPOT AND BERM CUTTINGS BOX._ 2/21/2013 00:00 - 06:00 6.00 MOB P PRE i RIG UP ON F-13B. j-INSTALL BERM IN MUD MODULE. -BRING MUD PRODUCT INTO PITS. I-INSTALL WIND SOCKS ON MUD MODULE AND UTILITY MODULE. WORK ON STEAM LINES IN MUD MODULE AND RIG FLOOR. 06:00 - 12:00 6.00 MOB P PRE CONTINUE TO RIG UP ON F-13B. -RAISE THE CATWALK -SET AND PIN MANRIDERS IN PLACE. -BRIDAL DOWN AND HANG BRIDAL LINES IN MAST. -UNCHAIN IRON DERRICKMAN. -SET OFFLINE STAND BUILDING MOUSEHOLE. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 3 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 15:00 3.00 MOB P PRE CONTINUE TO RIG UP ON F-13B. -TAKE ON RIG WATER. -BERM THE LINER UNDER THE MUD MODULE. CLEAR THE RIG FLOOR OF ICE. GENERAL HOUSEKEEPING ON RIG ONGOING PRIOR TO RIG ACCEPTANCE. 15:00 - 18:00 3.00 MOB P PRE CONTINUE TO RIG UP ON F-13B. -THAW STEAM TABLE LINES. -RIG UP PRESSURE WASHERS. GENERAL HOUSEKEEPING ON RIG ONGOING PRIOR TO RIG ACCEPTANCE. ***RIG ACCEPTANCE AT 15:00 HOURS. ACTUAL RIG ACCEPTANCE AT 22:00 HOURS. ROLLED BACK 7 HOURS FOR NON-RIG RELATED NPT DURING RIG MOVE.*** 18:00 - 21:00 3.00 MOB P PRE CONTINUE TO RIG UP ON F-13B. -PLUMB CUTTINGS BOX STEAM LINES. -INSTALL SHAKER SCREENS. -RIG UP CHEMICAL PUMP. GENERAL HOUSEKEEPING ON RIG ONGOING PRIOR TO RIG ACCEPTANCE. 21:00 - 22:00 1.00 RIGU P PRE GENERAL HOUSEKEEPING ON RIG PRIOR TO RIG ACCEPTANCE. SIMOPS:SPOT OPEN TOP TANK AND RIG UP HARDLINE. ACCEPT RIG AT 22:00 HRS.ROLLED RIG ACCEPTANCE BACK TO 15:00 HRS TO ACCOUNT FOR NON-RIG RELATED NPT THAT OCCURRED DURING RIG MOVE FROM CRAZY HORSE PAD TO F-PAD. 7 HOURS TOTAL:3.5 HRS ON 2/18/13 WHEN MOVE WAS HALTED DUE TO EXTREME COLD TEMPERATURES,3.5 HRS ON 2/19/13 WHEN MOVE WAS PUT ON HOLD DUE TO HALON DISCHARGE AT SKID 50. 22:00 - 00:00 2.00 RIGU P PRE HELD PRE-SPUD MEETING WITH HENSON'S CREW. HELD RIG EVACUATION DRILL AND AAR WITH RIG CREW AND THIRD PARTY ON LOCATION. -RESPONSE TIME 2 MIN 50 SEC. -RIG EVACUATION ALARM IS NOT VERY LOUD AND NEEDS TO BE TURNED UP. -SUGGESTION TO PUT GIATRONICS SPEAKER OUTSIDE WHERE TRUCK DRIVERS •WILL HEAR IT. REVIEWED THE SCOTT 5MIN ESCAPE PACKS LOCATION AND USAGE. 2/22/2013 00:00 - 01:30 1.50 MOB P PRE HELD PRE-SPUD MEETING WITH WOODS CREW. SIMOPS:PRESSURE TEST HARDLINE TO OPEN TOP TANK 250/4000 PSI FOR 5 MIN. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 4 of 75 Operation Summary Report Common Well Name.F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 02:30 1.00 MOB P PRE RIG UP TO PRESSURE TEST IA AND OA WITH DIESEL. -PRE JOB SAFETY MEETING WITH RIG CREW. 02:30 - 03:00 0.50 MOB P PRE PRE JOB SAFETY MEETING FOR TAKING ON FLUIDS TO PITS WITH RIG CREW AND CH2MHILL TRUCK DRIVERS. -REVIEWED FLUID TRANSFER PERMITS. -REVIEWED RIG UP AND VALVE ALIGNMENT. 03:00 - 07:00 4.00 MOB P PRE TAKE ON 120 DEG F 8.5 PPG SEAWATER TO PITS. SIMOPS:RIG UP TO TEST IA AND OA. -PRE JOB SAFETY MEETING. INSTALL INTEGRAL FLANGE 1502 ON ANNULUS VALVES. -RIG UP LINES TO BLEED TRAILER AND TEST PUMP. 07:00 - 11:00 4.00 MOB P PRE MIT IA AND OA TO VERIFY BARRIERS. -PRE JOB SAFETY MEETING MIT IA: -250 PSI LOW FOR 5 CHARTED MIN. 3500 PSI HIGH FOR 30 CHARTED MIN -INITIAL PRESSURE-3600 PSI. -15 MIN PRESSURE-3580 PSI. -30 MIN PRESSURE-3580 PSI. -TEST MET BPXA TESTING CRITERIA. -PUMPED 6.5 BBLS OF DIESEL TO PRESSURE UP. -BLED BACK 6.5 BBLS OF DIESEL. MIT OA: -250 PSI LOW FOR 5 CHARTED MIN. -2000 PSI HIGH FOR 30 CHARTED MIN -INITIAL PRESSURE-2150 PSI. -15 MIN PRESSURE-2075 PSI. -30 MIN PRESSURE-2060 PSI. -TEST MET BPXA TESTING CRITERIA. -PUMPED 0.6 BBLS OF DIESEL TO PRESSURE UP. -BLED BACK 0.6 BBLS OF DIESEL. BLOW DOWN LINES AND RIG DOWN TEST EQUIPMENT. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 5 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:00 1.00 MOB P PRE HELD RIG EVACUATION DRILL AND AAR WITH RIG CREW AND THIRD PARTY ON LOCATION. -RESPONSE TIME 4 MIN 35 SEC. -PIT WATCHER COMMUNICATED DRILL WITH TRUCK DRIVERS. -SEVERAL PERSONNEL BROUGHT ESCAPE PACKS WITH THEM. -ALL PERSONNEL WERE WEARING THEIR ARCTIC GEAR. AAR POINTS: RIG EVACUATION ALARM IS NOT VERY LOUD AND NEEDS TO BE TURNED UP. -SITE CONTROL NEEDS TO MAINTAIN BETTER COMMUNICATIONS WITH INCOMING TRAFFIC. -GOOD CONVERSATION WITH CREW ON PPE 'AND SCOTT AIR PACKS. 12:00 - 13:30 1.50 MOB P PRE RIG UP LUBRICATOR TO PULL BACK PRESSURE VALVE. -PRE JOB SAFETY MEETING WITH RIG CREW AND DRILL SITE MAINTENANCE. MOBILIZE LUBRICATOR AND HYDRAULIC HOSES TO RIG FLOOR. NIPPLE UP LUBRICATOR ON TREE. 13:30 - 17:30 4.00 MOB P PRE PRESSURE TEST LUBRICATOR TO 250/3500 PSI FOR 5 MIN. -RIG UP TO TEST LUBRICATOR. -ATTEMPT TO TEST LUBRICATOR. -WILL NOT HOLD PRESSURE. NO SURFACE LEAKS. -RIG DOWN LUBRICATOR AND INSPECT. -0-RING ON LUBRICATOR DAMAGED. -RE-DRESS LUBRICATOR AND NIPPLE UP ON TREE. -PRESSURE TEST LUBRICATOR TO 250/3500 PSI FOR 5 MIN. -GOOD TEST. 17:30 - 19:00 1.50 P PRE PULL BACK PRESSURE VALVE AND LAY DOWN LUBRICATOR. 19:00 - 20:00 1.00 P PRE TEST EMERGENCY SHUT DOWN(ESD)ON RIG. -PRE JOB SAFETY MEETING WITH RIG CREW. -ESD WORKED. -RE-STARTED RIG EQUIPMENT. HELD AN AAR WITH THE RIG CREW: -HAD DIFFICULTY STARTING 3516 DUE TO LOWAIR PRESSURE. -DURING TROUBLESHOOTING FOUND AN AIR VALVE LEFT OPEN IN THE SEWER TANK -PASS LESSON ON TO OTHER CREWS AND MAKE A SIGN TO CLOSE AIR VALVE AFTER USE. 20:00 - 22:00 2.00 P PRE RIG UP TO CIRCULATE OUT FREEZE PROTECT FROM WELL. -PRE JOB SAFETY MEETING. -DRILLER,RIG MANAGER AND WSL VERIFIED LINE UP. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 6 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) •22:00 - 00:00 2.00 P PRE CIRCULATE OUT DIESEL FREEZE PROTECT FROM WELL. -PRE JOB SAFETY MEETING WITH RIG CREW AND CH2MHILL. REVERSE CIRCULATE OUT 100 BBL OF DIESEL FROM TUBING TO OPEN TOP TANK -4 BPM AND 800 PSI. SHUT DOWN AND BLOW DOWN LINES TO OPEN TOP TANK. 2/23/2013 00:00 - 01:00 1.00 P PRE LINE UP TO CIRCULATE DOWN THE TUBING AND DISPLACE THE DIESEL FROM THE (ANNULUS. -PRE JOB SAFETY MEETING. -DRILLER,RIG MANAGER AND WSL VERIFY LINE UP. 01:00 - 01:30 0.50 P PRE PUMP 50 BBL BARAKLEAN PILL. LOST PRIME TO THE PUMPS WHEN SWITCHING PITS TO CHASE THE PILL WITH 8.5 SEAWATER. 01:30 - 04:30 3.00 N SFAL PRE TROUBLESHOOT PRIMING MUD PUMPS. -FROZE A LINE IN THE CELLAR WHILE GETTING PUMPS PRIMED. -BLOW AIR THROUGH LINES IN CELLAR AND LOCATE ICE PLUG. STEAM AND THAW LINES IN CELLAR. • 04:30 - 05:00 0.50 P PRE CONTINUE CIRCULATING DIESEL FREEZE PROTECT OUT OF ANNULUS TO THE OPEN TOP TANK. -CHASE SOAP PILL AND PUMP 110 BBLS OF 8.5 PPG SEAWATER. 5 BPM AND 770 PSI. 05:00 - 06:30 1.50 P PRE EMPTY OPEN TOP TANK AND SEND DIESEL FROM WELL TO RECYCLE. -SHUT DOWN AND BLOW DOWN ALL LINES. -SPOT TRUCK AND EMPTY FLUID FROM TRUCK. RECOVERED 175 BBLS OF DIESEL. 0630 - 08.00 1.50 P PRE CIRCULATE WELL WITH CLEAN 8.5 PPG BRINE. -PUMPED 300 BBLS AT 5 BPM WITH 700 PSI. -MONITOR WELL 10 MIN.STATIC. -BLOW DOWN/RIG DOWN CIRCULATING LINES. 08:00 - 09:00 1.00 P PRE MOBILIZE LUBRICATOR TO RIG FLOOR. -PRE JOB SAFETY MEETING WITH RIG CREW AND DRILL SITE MAINTENANCE. -HANG OFF LUBRICATOR. 09:00 - 10:00 1.00 N WAIT PRE LOCATE AND MOBILIZE A LUBRICATOR EXTENSION FOR DRILL SITE MAINTENANCE. -NEED A 2'LUBRICATOR EXTENSION TO RIG UP AND INSTALL TWC. SIMOPS: -CREW INSULATING GAPS UNDER RIG FLOOR. PERFORM SPILL DRILL WITH CREWAND AAR. -CREW RESPONSE TIME=1 MIN.30 SECONDS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 7 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 12:00 2.00 P PRE RIG UP LUBRICATOR AND TEST. -PRE JOB SAFETY MEETING WITH RIG CREW AND DRILL SITE MAINTENANCE. -TEST LUBRICATOR TO 250/3500 PSI FOR 5 CHARTED MIN.EACH. SIMOPS: -CREW INSULATING GAPS UNDER RIG FLOOR. 12:00 - 14:30 2.50 P PRE INSTALL TWC AND RIG UP TO TEST TWC FROM BELOW '-INSTALL TWC. -RIG UP TO TEST TWC FROM BELOW. -PRE JOB SAFETY MEETING WITH RIG 'CREW. -RIG UP TO TEST TWC. SIMOPS: -CREW INSULATING GAPS UNDER RIG FLOOR. 14:30 - 17:00 2.50 P PRE PRESSURE TEST TWC FROM BELOW. -250 PSI FOR 5 CHARTED MIN. -GOOD TEST. '-3500 PSI HIGH FOR 30 CHARTED MIN. -GOOD TEST. -BLEED PRESSURE BACK TO OPEN TOP TANK. -BLOW DOWN HARD LINE TO OPEN TOP TANK. SIMOPS: -CREW INSULATING GAPS UNDER RIG FLOOR. 17:00 - 19:30 2.50 P PRE PRESSURE TEST TWC FROM ABOVE TO 250 PSI/3500 PSI FOR 5 CHARTED MIN EACH. -ATTEMPTED TO TEST TWC FROM ABOVE. -THREE FAILED HIGH PRESSURE TESTS. -FIRST ATTEMPT FAILED DUE TO LEAK ON JIC FITTINGS ON LUBRICATOR. -CHANGED OUT JIC FITTINGS. -SECOND TEST FAILED DUE TO SEEP ON MASTER VALVE STEM CAP. -GREASED MASTER VALVE STEM CAP. -THIRD TEST FAILED DUE TO SEEP ON MASTER VALVE STEM CAP AGAIN. -RE-GREASED MASTER VALVE STEM CAP. -TWC TESTED GOOD ON FOURTH ATTEMPT TO 250/3500 PSI FOR 5 CHARTED MIN EACH. SIMOPS: -CREW INSULATING GAPS UNDER RIG FLOOR. 19:30 - 20:30 1.00 P PRE REMOVE DIESEL FROM LUBRICATOR AND TEST PUMP. -BLOW DOWN ALL LINES. 20:30 - 22:00 1.50 P PRE RIG DOWN LUBRICATOR. -PRE JOB SAFETY MEETING WITH RIG CREW AND DRILL SITE MAINTENANCE. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 8 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) • Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 P PRE RIG UP TO PRESSURE TEST BOP ON TEST STUMP TO 5000 PSI. -PRE JOB SAFETY MEETING WITH RIG CREW. -MAKE UP TEST JOINT WITH PORTED SUB. -RIG UP TEST EQUIPMENT ON RIG FLOOR. -RIG UP TEST PUMP AND CHART RECORDER. 2/24/2013 00:00 - 01:30 1.50 P PRE CONTINUE TO RIG UP TO TEST BOPE TO 5000 PSI ON THE TEST STUMP. -PRE JOB SAFETY MEETING WITH RIG CREW. -FILL STACK AND CHOKE MANIFOLD. 01:30 - 07:00 5.50 P PRE PRESSURE TEST BOPE ON TEST STUMP TO 250/5000 PSI FOR 5 CHARTED MIN. -TEST ANNULAR WITH 5"TEST JOINT TO 250 /2500 PSI. -TEST NC50 FULL OPEN SAFETY VALVE AND DART VALVE TO 250/5000 PSI. -TEST CHOKE MANIFOLD VALVES TO 250/ 5000 PSI. -TEST UPPER AND LOWER RAMS WITH 5" TEST JOINT TO 250/5000 PSI. -TEST BLIND SHEAR RAMS TO 250/5000 PSI. 07:00 - 09:00 2.00 P PRE RIG DOWN TEST EQUIPMENT. -BLOW DOWN CHOKE MANIFOLD -DRAIN STACK AND BLOW DOWN CHOKE AND KILL LINES. BREAK DOWN 5"TEST JOINT. 09:00 - 14:00 5.00 P PRE NIPPLE DOWN TREE. -PRE JOB SAFETY MEETING WITH RIG CREW AND CAMERON WELL HEAD REP. -BLEED OFF AND CAP CONTROL LINES. -CHECK ALL LOCK DOWN SCREWS. -NIPPLE DOWN TREE AND STAND BACK IN CELLAR. -CLEAN THREADS AND MAKE UP HANGER XO -7 FULL TURNS TO MAKE UP. SIMOPS: -NIPPLE UP SPACER SPOOLS AND PREP TO RIG UP RISERS 14:00 - 14:30 0.50 P PRE PERFORM ACCUMULATOR DRAW DOWN TEST. -25 SECONDS TO 200 PSI. -85 SECONDS TO FULL PRESSURE. -14 BACK UP BOTTLES WITH AN AVERAGE PRESSURE OF 2104 PSI. 14:30 - 17:00 2.50 P PRE NIPPLE UP RISER ASSEMBLY. -PRE JOB SAFETY MEETING. 17:00 - 20:00 3.00 P PRE NIPPLE UP BOP STACK ON RISER ASSEMBLY. -PRE JOB SAFETY MEETING. -NIPPLE DOWN BOP STACK FROM TEST STUMP. -NIPPLE UP BOP STACK ON RISER ASSEMBLY. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 9 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 P PRE CHANGE UPPER RAMS TO 7"CASING RAMS. -PRE JOB SAFETY MEETING. -OPEN UPPER RAM DOORS AND REMOVE 2-7/8"X 5"VBR. INSPECT SEALS AND INSTALL 7"CASING RAMS. -CLOSE UPPER RAM DOORS. 22:00 - 23:00 1.00 P PRE 'PERFORM VISUAL INSPECTION OF BOP SEALING ELEMENTS PER HIGH GOR WELL SOP. -OPEN LOWER RAM DOORS,INSPECT AND CLOSE. -DOOR SEAL AND RAMS LOOK NEW. -VERIFY LOWER RAMS ARE 2-7/8"X 5" VARIABLES. -OPEN BLIND/SHEAR RAM DOORS,INSPECT AND CLOSE. -DOOR SEALS AND RAMS LOOK NEW. 23:00 - 00:00 1.00 P PRE INSTALL TURNBUCKLES AND CENTER BOP STACK. PRE JOB SAFETY MEETING. 2/25/2013 00:00 - 04:00 4.00 P PRE CONTINUE TO NIPPLE UP BOP STACK -PRE JOB SAFETY MEETING. -NIPPLE UP RISER AND FLOW LINE. -CHECK AIR BOOTS. -INSTALL MOUSE HOLE. SIMOPS: -GREASE CHOKE MANIFOLD FOR UPCOMING BOP TEST. -CLEAN CELLAR. -CHECK MAKE UP ON ALL STUDS ON BOP STACK AND CHOKE MANIFOLD. 04:00 - 06:30 2.50 P PRE RIG UP TO TEST BOPE TO 250/3500 PSI WITH 4"AND 7"TEST JOINTS. V -PRE JOB SAFETY MEETING. -MOBILIZE TEST EQUIPMENT TO RIG FLOOR. -CLEAN CELLAR AND ACCUMULATOR ROOM. -STORE EXTRA BOP RAMS. 35 GAL FRESH WATER LEAK,33 GAL IN THE RIG AND 2 GAL OUTSIDE THE RIG. COPPER FITTING RUPTURED INSIDE THE WALL IN THE WOMEN'S RESTROOM ON THE UTILITY MODULE.TRACTION REPORT: 2013-I R-4362041. 06:30 - 08:30 2.00 P PRE MAKE UP 7"TEST JOINT. -PRE JOB SAFETY MEETING. SIMOPS: MOP UP FRESH WATER FROM LEAK Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 10 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 09:30 1.00 P PRE RECORD RKB MEASUREMENTS. -PULL MOUSE HOLE. -PRE JOB SAFETY MEETING. -RECORD RKB MEASUREMENTS. -ROTARY TABLE TO ANNULAR=14.09' -ROTARY TABLE TO TOP PIPE RAMS= 17.4' -ROTARY TABLE TO BLIND/SHEAR RAMS= 18.41' -ROTARY TABLE TO BOTTOM PIPE RAMS= 22.69' -ROTARY TABLE TO TUBING SPOOL LOCK DOWNS=43.36' -ROTARY TABLE TO CASING SPOOL LOCK DOWNS=45.66' -ROTARY TABLE TO GROUND LEVEL= 47.79' -RE-INSTALL MOUSE HOLE 09:30 - 14:00 4.50 P PRE CONTINUE RIGGING UP TO TEST BOPE 250/3500 PSI. -CONTINUE MAKING 7"TEST JOINT ASSEMBLY. CHECK KOOMEY OIL LEVELS. • -ADD OIL TO KOOMEY. HOUSEKEEPING AROUND TEST AREAS. FIRE DRILL AND AAR WITH RIG CREW. 14:00 - 18:30 4.50 P PRE TEST BOPE TO 250/3500 PSI. -TEST UPPER RAMS WITH 7"TEST JOINT 250/3500 PSI. -TEST CHOKE MANIFOLD VALVES 250/3500 PSI. AOGCC INSPECTOR JEFF JONES,AND BP WSL LEADER WITNESS TEST. 18:30 - 19:30 1.00 P PRE RIG DOWN 7"TEST JOINT. -PRE JOB SAFETY MEETING. 19:30 - 00:00 4.50 P PRE RIG UP 4"TEST JOINT AND TEST EQUIPMENT. -PRE JOB SAFETY MEETING. -RIG UP 4"TEST EQUIPMENT. -BAD THREAD ON 4"PUMP-IN SUB. -RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES. -MOBILIZE A REPLACEMENT PUMP-IN SUB FROM PARKER 273. SIMOPS: CONTINUE TESTING BOPE EQUIPMENT WITH AOGCC INSPECTOR JEFF JONES. -TEST RETURN FLOW AUDIBLE ALARM. -TEST FAILED. -TROUBLESHOOT AND LOCATE ALARM SETTING IN SOFTWARE. -TEST LELAND H2S ALARMS. -TEST FAILED. VISUAL ALARMS ON RIG FLOOR DID NOT WORK. -TROUBLE SHOOT ALARMS SYSTEM Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 11 of 75 Operation Summary Report Common Well Name.F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/26/2013 00:00 - 01:30 1.50 P PRE CONTINUE RIGGING UP 4"TEST JOINT FOR BOPE TEST. -PRE JOB SAFETY MEETING. -RIG UP 4"TEST JOINT UTILIZING PUMP-IN SUB FROM PARKER 273. 01:30 - 06:00 4.50 N RREP PRE ,TROUBLESHOOT AND CORRECT DEFICIENCIES DISCOVERED DURING BOPE TESTING. -CONTINUE TO TROUBLESHOOT RIG FLOOR VISUAL GAS ALARMS. -CONTINUE TO TROUBLESHOOT KOOMEY AIR PUMP PRESSURE SWITCH. -PASS INFORMATION ON TO PARKER DRILLING AND BP TOWN PERSONNEL. SIMOPS: -HANG CEMENT LINE ON RIG FLOOR. -PRE JOB SAFETY MEETING. -DISCUSS DROPPED OBJECTS AND WORKING AT HEIGHTS. -MOBILIZE MWD TOOLS TO PIPE SHED. -RIG BOILER NUMBER 1 WENT DOWN. -TROUBLESHOOT FEED WATER PUMP. -REPAIR AND BRING BOILER BACK ONLINE. 06:00 - 07:00 1.00 N RREP PRE TROUBLESHOOT AND CORRECT DEFICIENCIES DISCOVERED DURING BOPE TESTING. -CONTINUE TO TROUBLESHOOT RIG FLOOR VISUAL GAS ALARMS. -CONTINUE TO TROUBLESHOOT KOOMEY AIR PUMP PRESSURE SWITCH. SIMOPS: -BREAK DOWN 4"TEST JOINT AND MOBILIZE TO PIPE SHED. -PRE JOB SAFETY MEETING. 07:00 - 08:00 1.00 P PRE SERVICE RIG AND INSPECT DERRICK -PRE JOB SAFETY MEETING PRIOR TO INSPECTING RIG. -SERVICE TOP DRIVE. 08:00 - 08:30 0.50 N RREP PRE TROUBLESHOOT AND CORRECT DEFICIENCIES DISCOVERED DURING BOPE TESTING. -CONTINUE TO TROUBLESHOOT RIG FLOOR VISUAL GAS ALARMS. -MOBILIZING ASSISTANCE FROM FIRE AND GAS VENDOR IN ANCHORAGE TO HELP TROUBLE SHOOT. -CONTINUE TO TROUBLESHOOT KOOMEY AIR PUMP PRESSURE SWITCH. -ADJUST THE CUT OFF POINT ON THE AIR AND ELECTRIC PUMPS ON THE KOOMEY. -PERFORM A DRAW DOWN TEST AND SEND RESULT TO PARKER DRILLING TOWN PERSONNEL. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 12 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 12:00 3.50 C PRE PICK UP 4"HT-38 DRILL PIPE AND MAKE UP STANDS WITH THE OFF-LINE STAND BUILDER. -PRE JOB SAFETY MEETING. -DISCUSS TUBULAR HANDLING IN PIPE SHED. -DISCUSS FORUM CRANE OPERATION SAFETY. -DOPE,TORQUE AND BREAK EACH CONNECTION TWICE. 12:00 - 18:00 6.00 C PRE CONTINUE TO PICK UP 4"HT-38 DRILL PIPE •AND BUILD STANDS WITH THE OFF-LINE STAND BUILDER. -PRE JOB SAFETY MEETING WITH THE NEW CREW. -DISCUSS TUBULAR HANDLING IN PIPE SHED. -DISCUSS FORUM CRANE OPERATION SAFETY. -DOPE,TORQUE AND BREAK EACH CONNECTION TWICE. SIMOPS: INSTALL NEW PUMP PRESSURE GAUGES ON RIG FLOOR. -INSTALL CASING PRESSURE SENSOR SWITCH ON CHOKE MANIFOLD. 18:00 - 19:00 1.00 C PRE SERVICE PIPE CAT,FORUM CRANE AND PRT. 19:00 - 00:00 5.00 C PRE CONTINUE TO PICK UP 4"HT-38 DRILL PIPE AND BUILD STANDS WITH THE OFF-LINE STAND BUILDER. -DOPE,TORQUE AND BREAK EACH CONNECTION TWICE. 2/27/2013 00:00 - 07:30 7.50 C PRE CONTINUE TO PICK UP 4"HT-38 DRILL PIPE AND BUILD STANDS WITH THE OFF-LINE STAND BUILDER. -DOPE,TORQUE AND BREAK EACH CONNECTION TWICE. 07:30 - 08:00 0.50 N RREP PRE FUNCTION TEST FIRE AND GAS ALARMS AND PVT RETURN FLOW ALARM. ALL ALARMS FUNCTION TESTED. 08:00 - 10:00 2.00 P PRE RIG UP 4"TEST JOINT TO TEST LOWER RAMS AND ANNULAR PREVENTER. -FILL STACK AND LINES AND RIG UP TEST EQUIPMENT. 10:00 - 10:30 0.50 N RREP PRE REPAIR RUPTURED HYDRAULIC HOSE ON ST-80 USED FOR OFF-LINE STAND BUILDING. 10:30 - 12:30 2.00 C PRE CONTINUE TO PICK UP 4"HT-38 DRILL PIPE AND BUILD STANDS WITH THE OFF-LINE STAND BUILDER. -DOPE,TORQUE AND BREAK EACH CONNECTION TWICE. 12:30 - 13:30 1.00 C PRE SERVICE PIPE CAT. 13:30 - 15:00 1.50 C PRE CONTINUE TO PICK UP 4"HT-38 DRILL PIPE AND BUILD STANDS WITH THE OFF-LINE STAND BUILDER. -DOPE,TORQUE AND BREAK EACH CONNECTION TWICE. -82 STANDS OF 4"HT-38 BUILT AND STOOD BACK ON OFF-DRILLER'S SIDE OF DERRICK. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 13 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 20:30 5.50 P PRE CONTINUE TESTING BOPE;ALL TESTS TO 250/3500 PSI. PRE JOB SAFETY MEETING. -TEST LOWER RAMS WITH 4"TEST JOINT. TEST ANNULAR WITH 4"TEST JOINT. -TEST BLIND SHEAR RAMS. -TEST TOP DRIVE. '-VERIFY THE FIRE AND GAS VISUAL AND AUDIBLE ALARMS FUNCTION. -VERIFY THE AUDIBLE ALARM ON THE RETURN FLOW FUNCTIONS. -TESTS WITNESSED BYAOGCC INSPECTOR JOHN CRISP. 20:30 - 21:30 1.00 P PRE RIG DOWN AND BLOW DOWN BOPE TEST EQUIPMENT. 21:30 - 00:00 2.50 P PRE INSTALL DUTCH RISER AND RUN IN LOCK DOWN SCREWS. -PRE JOB SAFETY MEETING. -PICK UP DUTCH RISER AND EXTENSION FROM PIPE SHED. -MAKE UP DUTCH RISER ON FLOOR. PULL BUSHINGS AND INSTALL DUTCH RISER. -RUN IN LOCK DOWN SCREWS ON DUTCH RISER. 2/28/2013 00:00 - 01:30 1.50 P PRE NIPPLE UP LUBRICATOR ON DUTCH RISER. -PRE JOB SAFETY MEETING. -MOBILIZE LUBRICATOR TO RIG FLOOR. -FILL STACK AND DUTCH RISER. -CLOSE ANNULAR ON DUTCH RISER. NIPPLE UP LUBRICATOR ON DUTCH RISER. 01:30 - 02:30 1.00 P PRE PRESSURE TEST LUBRICATOR TO 250/3500 PSI. -PRE JOB SAFETY MEETING. -XO ON LUBRICATOR FROM 7"ACME TO 7" OTIS LEAKED. -INSPECT 0-RING AND RETEST. GOOD TEST 250/3500 PSI FOR 5 MIN EACH. 02:30 - 03:30 1.00 P PRE PULL TWC AND NIPPLE DOWN LUBRICATOR. -PULL TWC. -PRE JOB SAFETY MEETING PRIOR TO NIPPLE DOWN OF LUBRICATOR. -NIPPLE DOWN AND LAY DOWN LUBRICATOR. 03:30 - 04:30 1.00 WHSUR P DECOMP LAY DOWN DUTCH RISER. -PRE JOB SAFETY MEETING. -OPEN ANNULAR PREVENTER. -SUCK OUT RISER AND BOP STACK -BACK OUT LOCK DOWN SCREWS ON DUTCH RISER. -PULL DUTCH RISER AND LAY DOWN ON PIPE CAT. 04:30 - 06:00 1.50 WHSUR P DECOMP RIG UP TO PULL 7"TUBING HANGER. -PRE JOB SAFETY MEETING. -MAKE UP SINGLE JOINT OF 4"HT-38 DRILL PIPE ANDA 15'PUP. -MAKE UP XO TO 7"IJ4S ON BOTTOM AND FULL OPEN SAFETY VALVE ON TOP. -RUN IN THE HOLE AND MAKE UP TO 7" TUBING HANGER WITH 7 FULL TURNS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 14 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 09:30 3.50 WHSUR P DECOMP CONTINUE TO RIG UP TO PULL 7"26 LB/FT TUBING STRING. -CHANGE ELEVATORS TO 4"BOTTLENECK -RIG UP CASING TONGS ON RIG FLOOR. MOBILIZE SPOOLER TO RIG FLOOR AND RIG UP FOR CONTROL LINE. PREP PIPE SHED AND INSPECT PIPE CAT. 09:30 - 13:30 4.00 WHSUR N RREP DECOMP TROUBLESHOOT AND REPAIR MONKEY BOARD COLLISION WARNING SYSTEM (MCWS). 13.30 - 14:00 0.50 WHSUR P DECOMP MAKE UP TOP DRIVE TO 4"LANDING JOINT ASSEMBLY AND RE-ENGAGE 7"TUBING HANGER. 14:00 - 14:30 0.50 WHSUR P DECOMP BACK OUT LOCK DOWN SCREWS ON 7" TUBING SPOOL. -CAMERON WELLHEAD REPRESENTATIVE BACKED OUT SCREWS. 14:30 - 15:30 1.00 WHSUR P DECOMP UNSEAT 7"TUBING HANGER. -HANGER PULLED FREE AT 220K LBS -CONTINUED TO PICK UP TO 235K LBS TO FREE STRING. • -PICK UP WEIGHT DROPPED BACK TO 220K LBS AFTER STRING PULLED FREE. MONITOR THE WELL FOR 10 MIN. -NO FLOW;WELL IS STATIC. -PICK UP WEIGHT=220K LBS;DOWN WEIGHT=190K LBS. 15:30 - 17:30 2.00 PULL P DECOMP PERFORM A D-2,KICK WHILE DRILLING DRILL,AND CIRCULATE A BOTTOMS UP THROUGH THE CHOKE AND MUD/GAS SEPARATOR. -D-2 DRILL INITIATED. -ANNULAR CLOSED AND WELL SECURED IN 30 SECONDS. -TOTAL CREW RESPONSE TIME 1 MIN 30 SEC. -LINED UP TO CIRCULATE THROUGH THE CHOKE TO THE MUD GAS SEPARATOR. -CIRCULATED 240 BBLS THROUGH THE CHOKE. -3 BPM AND 250 PSI. 17:30 - 19:30 2.00 PULL P DECOMP PULL 7"TUBING HANGER TO FLOOR. -15K LB OVERPULL NOTED AS HANGER ENTERED BOP STACK. -HANGER HUNG UP IN LOWER RAM CAVITY. -DRAIN THE STACK AND REMOVE TURNBUCKLES. -ALIGN THE STACK TO FACILITATE PULLING THE HANGER. -PULL HANGER TO FLOOR. -UP WEIGHT=220K LBS;DOWN WEIGHT =190K LBS. -RECOVERED 1 CAP SCREW FROM THE TOP OF THE TUBING HANGER. -5 ADDITIONAL CAPS SCREWS MISSING FROM TOP OF HANGER. Printed 6/24/2013 1:20:07PM North America-ALASKA BP, Page 15 of 75 r Operation Summary Report" r Common Well Name.F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12'00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum.F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 21:30 2.00 PULL P DECOMP RIG DOWN 4"LANDING JOINT ASSEMBLY AND RIG UP TO PULL 7"TUBING. j-PRE JOB SAFETY MEETING. TERMINATE CONTROL LINES. -LAY DOWN TUBING HANGER AND LANDING JOINT ASSEMBLY. -BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD. -RIG UP SIDE-DOOR ELEVATORS FOR PULLING 7"26 LB/FT TUBING. 21:30 - 00:00 2.50 PULL P DECOMP PULL AND LAY DOWN 7"26 LB/FT TUBING. PRE JOB SAFETY MEETING. -PULL AND LAY DOWN 7"TUBING FROM 7737' TO 6320'MD. -PICK UP WEIGHT=175K LBS;DOWN WEIGHT=160K LBS. 3/1/2013 00:00 - 02:00 ' 2.00 PULL P DECOMP CONTINUE TO PULL AND LAY DOWN 7" TUBING. -FROM 6320'TO 5640'MD. -LAY DOWN OTIS SSSV AND 20'TUBING PUP BELOW IT. -RECOVERED 4 STAINLESS STEEL BANDS;25 CLAMPS AND 25 PINS. 02 00 - 02:30 0.50 _ PULL P I DECOMP SERVICE PIPE CAT. SIMOPS: -RIG DOWN SCHLUMBERGER SPOOLING UNIT. 02.30 - 03:00 0.50 PULL ' P DECOMP HELD D-1,KICK WHILE TRIPPING DRILL. -DRILLER IMMEDIATELY RECOGNIZED ALARMS AND ANNOUNCED THE DRILL. CREW MADE UP FULL OPEN SAFETY VALVE AND DRILLER SIMULATED CLOSING THE ANNULAR. -WELL SECURED IN 2 MIN AND 10 SECONDS. 03:00 - 08:00 5.00 PULL P DECOMP CONTINUE TO PULL AND LAY DOWN 7" TUBING. -FROM 5640'TO 3106'MD. I-PICK UP WEIGHT=97K LBS:DOWN WEIGHT =97K LBS. 08:00 - 09:00 1.00 PULL P DECOMP MONITOR WELLAND CLEAR RIG FLOOR. -MONITOR WELL FOR 10 MIN. -STATIC. -CLEAR RIG FLOOR OF BANDS AND CLAMPS. -INSPECT PIPE CAT AND RIG FLOOR EQUIPMENT. SIMOPS: 1-INSTALL PATCH ON MD TOTCO SOFTWARE SYSTEM. 09.00 - 12:00 3.00 PULL P DECOMP CONTINUE TO PULL AND LAY DOWN 7" TUBING. -FROM 3106'TO 1300'MD. I-PICK UP WEIGHT=60K LBS;DOWN WEIGHT =63K LBS. Printed 6/24/2013 1:20.07PM North America-ALASKA-BP Page 16 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 16:00 4.00 PULL P DECOMP CONTINUE TO PULL AND LAY DOWN 7" TUBING. -FROM 1300'MD. -RECOVERED THE FOLLOWING FROM THE WELL: -186 FULL JOINTS -1 20'PUP JOINT -1 OTIS SSSV NIPPLE -1 CUT JOINT=3.8'LONG WITH A 8.75"OD FLARE -2097'OF CONTROL LINE -4 STAINLESS STEEL BANDS -25 CLAMPS WITH 25 PINS. 16:00 - 17:00 1.00 PULL P DECOMP RIG DOWN DOYON CASING EQUIPMENT. '-PRE JOB SAFETY MEETING. 17:00 - 19:00 2.00 BOPSUR P DECOMP RIG UP BX ELEVATORS AND RIG UP TO CHANGE RAMS. -PRE JOB SAFETY MEETING. -DRAIN RISER AND BOP STACK. -FUNCTION ALL RAMS TO CLEAR RAM CAVITIES. 19:00 - 21:00 2.00 BOPSUR P DECOMP CHANGE UPPER RAMS FROM 7"TO 2-7/8"X 5-1/2"VARIABLE RAMS. PRE JOB SAFETY MEETING. -OPEN DOORS AND REMOVE 7"RAMS. -INSPECT AND INSTALL 2-7/8"X 5-1/2" VARIABLE RAMS. CLOSE DOORS. 21:00 - 22:30 1.50 BOPSUR P DECOMP RIG UP 4"TEST JOINT TO TEST UPPER RAMS. -MAKE UP PORTED SUB,4"PUP JOINT AND FULL JOINT OF 4". 22:30 - 23:30 1.00 WHSUR P DECOMP INSTALL TEST PLUG AND FILL RISER AND BOP STACK. -FLUID LEAKING BY TEST PLUG. -ATTEMPT TO RE-SEAT TEST PLUG TWO TIMES. -FLUID STILL LEAKING BY. -PULL TEST PLUG. -CALL WELLHEAD REPRESENTATIVES OUT WITH ANOTHER TEST PLUG. 23:30 - 00:00 0.50 WHSUR N SFAL DECOMP RE-DRESS SECOND TEST PLUG WITH NEW SEAL. -SECOND TEST PLUG BROUGHT OUT HAD A GROOVE THAT RAN THE WIDTH OF THE SEAL. -WELLHEAD REPRESENTATIVES RE-DRESSED THE PLUG WITH A NEW SEAL ON THE RIG FLOOR. 3/2/2013 00:00 - 02:00 2.00 BOPSUR P DECOMP INSTALL TEST PLUG AND TEST UPPER RAMS. -INSTALL RE-DRESSED TEST PLUG AND VERIFY SEATED. -FILL RISER AND BOP STACK. -RIG UP TEST EQUIPMENT. -PRESSURE TEST UPPER 2-7/8"X 5-1/2" VARIABLE RAMS. -250/3500 PSI FOR 5 CHARTED MIN EACH. -GOOD TEST. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 17 of 7 Operation Summary Report Common Well Name.F-13 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date.2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 02:30 0.50 WHSUR P DECOMP INSTALL WEAR BUSHING. -PRE JOB SAFETY MEETING WITH RIG CREW AND WELLHEAD REP. -INSTALL WEAR BUSHING 11-9/16"ID. -RUN IN LOCK DOWN SCREWS. 02:30 - 03:30 1.00 BOPSUR P DECOMP RIG DOWN AND BLOW DOWN. 03:30 - 04:00 0.50 FISH P DECOMP MOBILIZE 9-5/8"CLEAN-OUT ASSEMBLY TOOLS TO RIG FLOOR. "*9.25 BBL FRESH WATER SPILL IN DRILL MODULE HPU MOVING SYSTEM ROOM. ALL IN CONTAINMENT. TRACTION REPORT: 2013-IR-4366649.*** 04:00 - 10:00 6.00 FISH P DECOMP MAKE UP 9-5/8"CLEAN-OUT ASSEMBLY. PRE JOB SAFETY MEETING WITH RIG CREW AND BAKER FISHING REP. -MAKE UP FISHING TOOLS PER BAKER FISHING REP. -TOTAL BHA LENGTH INCLUDING DRILL COLLARS AND HEAVY WEIGHT DRILL PIPE= 812.97'. 10:00 - 13:00 3.00 FISH P DECOMP RUN IN THE HOLE WITH THE 9-5/8" CLEAN-OUT ASSEMBLY ON 4"HT-38 DRILL PIPE. -PRE JOB SAFETY MEETING. -RUN IN THE HOLE,PICKING UP SINGLE JOINTS OF 4"DRILL PIPE FROM THE PIPE SHED. -FROM 812'TO 1600'MD. -PICK UP WEIGHT=89K LBS.;DOWN WEIGHT=83K LBS. 13:00 - 13:30 0.50 FISH P - DECOMP INSTALL PS-21 SLIPS IN ROTARY TABLE. -PRE JOB SAFETY MEETING. -REMOVE MASTER BUSHINGS FROM TABLE. -INSTALL PS-21 SLIPS WITH CORRECT INSERTS. -CANNOT GET PS-21 SLIPS TO FUNCTION. 13:30 - 14:00 0.50 FISH N RREP 1,300.00 DECOMP TROUBLESHOOT AND REPAIR PS-21 SLIPS. -TABLE LOCK INDICATOR NOT WORKING. -REMOVE PS-21 SLIPS AND RE-INSTALL MASTER BUSHINGS. 14.00 - 16:30 2.50 FISH P i DECOMP CONTINUE TO RUN IN THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY,PICKING UP 4" i HT-38 DRILL PIPE FROM THE SHED. -FROM 1300'TO 2009'MD. -PICK UP WEIGHT=91K LBS;DOWN WEIGHT =85K LBS. 16 30 - 20:30 4.00 FISH N RREP 2,009.00 DECOMP TROUBLESHOOT FALSE ALARMS AND INCORRECT READINGS ON PVT SYSTEM. -AMPHION AND TOTCO SYSTEMS NOT COMMUNICATING CORRECTLY. -REPLACE 2 BOARDS IN AMPHION SYSTEM. -TEST AND CALIBRATE SYSTEM. Printed 6/24/2013 1:20'07PM North America-ALASKA-BP Page 18 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 00:00 3.50 FISH P DECOMP CONTINUE TO RUN IN THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY,PICKING UP 4" HT-38 DRILL PIPE FROM THE SHED. -FROM 2009'TO 2515'MD. 1-PICK UP WEIGHT=99K LBS;DOWN WEIGHT =90K LBS. HAD 2 JOINTS NOT DRIFT TO 2.438". CULLED THE TWO JOINTS FROM THE TALLY AND PIPE SHED. DRIFT HUNG UP WHERE THE PIN END IS WELDED TO THE TUBE. JOINTS WILL BE SENT TO BE REPAIRED. 3/3/2013 00:00 - 03:00 3.00 FISH P DECOMP CONTINUE TO RUN IN THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY,PICKING UP 4" HT-38 DRILL PIPE FROM THE SHED. —FROM 2515 TO 3269'MD. -PICK UP WEIGHT=103K LBS;DOWN WEIGHT=112K LBS. -FILLING PIPE EVERY 25 STANDS. 03:00 - 06:00 3.00 FISH P DECOMP RUN IN THE HOLE WITH THE 9-5/8" CLEAN-OUT ASSEMBLY ON 4"HT-38 DRILL PIPE STANDS OUT OF THE DERRICK -FROM 3269'TO 5200'MD. PICK UP WEIGHT=103K LBS;DOWN WEIGHT=112K LBS. -FILLING PIPE EVERY 25 STANDS. 06:00 - 10:00 4.00 FISH P DECOMP CONTINUE TO RUN IN THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY ON 4"HT-38 DRILL PIPE STANDS OUT OF THE DERRICK -FROM 5200'TO 7760'MD. -WORK MILLS FROM 7535'TO 7610'3 TIMES. -TAG TOP OF 7"TUBING STUB AT 7760'MD. ORIGINAL RKB=63.5'. -PARKER 272 RKB=45.66';FOR A DIFFERENCE OF 17.8'. -PICK UP WEIGHT=175K LBS;DOWN WEIGHT=165K LBS. -FILLING PIPE EVERY 25 STANDS. 10:00 - 12:00 2.00 FISH P DECOMP CIRCULATE WELL CLEAN. -CIRCULATE 1.5 TIMES BOTTOMS UP;740 BBLS. -650 GPM AND 2970 PSI. 12:00 - 12:30 0.50 FISH P DECOMP MONITOR THE WELL FOR 10 MIN. -WELL IS STATIC. SIMOPS: BLOW DOWN TOP DRIVE. 12:30 - 14:30 2.00 FISH P DECOMP PULL OUT OF THE HOLE WITH THE 9-5/8" CLEAN-OUT ASSEMBLY,STANDING BACK 4" HT-38 DRILL PIPE IN THE DERRICK. -FROM 7760'TO 4121'MD. -PICK UP WEIGHT=125K LBS;DOWN WEIGHT=120K LBS. STRAPPING 4"DRILL PIPE IN THE DERRICK. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 19 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor PARKER DRILLING CO. UW: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 18:00 3.50 FISH P DECOMP PERFORMED A STRIPPING DRILL(D-6) FOLLOWED BY A WELL KILL DRILL(D-5)WITH HENSON'S CREW. -FROM 4121'TO 4215'MD. -MAINTAINED 200 PSI ON WELLBORE WHILE STRIPPING THROUGH THE ANNULAR. -ROLLED STRIPPING DRILL INTO A WELL KILL DRILL. 18.00 - 19:00 1.00 FISH P DECOMP BLOW DOWN TOP DRIVE AND RIG DOWN WELL CONTROL EQUIPMENT. • 19:00 - 23:00 4.00 FISH P DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY,STANDING BACK 4"HT-38 DRILL PIPE IN THE DERRICK. -FROM 4121'TO 812'MD. -PICK UP WEIGHT=73K LBS;DOWN WEIGHT =80K LBS. -STRAPPING 4"DRILL PIPE IN THE DERRICK. -MONITOR WELL FOR 10 MIN AT THE TOP OF THE BHA. WELL IS STATIC. 23:00 - 00:00 1.00 FISH P DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY,STANDING BACK 4"HEAVY WEIGHT DRILL PIPE. -PRE JOB SAFETY MEETING. -STRAP 4"HEAVY WEIGHT DRILL PIPE IN DERRICK. • 3/4/2013 00:00 - 03:30 3.50 FISH P DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH THE 9-5/8"CLEAN-OUT ASSEMBLY,STANDING BACK 6-1/2"DRILL COLLARS. -PRE JOB SAFETY MEETING. LAY DOWN 9-5/8"CLEAN-OUT ASSEMBLY. 03:30 - 04:30 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. -PRE JOB SAFETY MEETING. -CLEAN STRING MAGNET AND EMPTY BOOT BASKETS. -RECOVER 1 GALLON METAL SHAVINGS. -RECOVER SEVERAL SMALL PIECES OF CONTROL LINE ENCAPSULATION. -LAY DOWN AND REMOVE OIL JARS AND BUMPER SUB FROM PIPE SHED. 04:30 - 05:00 0.50 FISH P DECOMP SERVICE TOP DRIVE AND RIG. 05:00 - 06:00 1.00 FISH P DECOMP MOBILIZE WHIPSTOCK BOTTOM HOLE TOOLS TO RIG FLOOR. St -PRE JOB SAFETY MEETING. )/1/"-P p -BRING WHIPSTOCK BOTTOM HOLE TOOLS S/7�/ TO RIG FLOOR UTILIZING THE TOOL CRANE. 06:00 - 08:00 2.00 FISH P DECOMP CLEAN RIG AND RIG UP STEAM LOOP IN CUTTINGS BOX. SPILL DRILL AND AFTER ACTION REVIEW WITH CREW. 08:00 - 09:30 1.50 FISH P DECOMP RIG UP E-LINE TO RUN GR/CCL LOG. -PRE JOB SAFETY MEETING. -MOBILIZE E-LINE TOOLS TO RIG FLOOR. -RIG UP SHEAVES ON FLOOR. 09:30 - 14:00 4.50 FISH P DECOMP RUN IN THE HOLE WITH GR/CCL,GAUGE RING AND JUNK BASKET ON E-LINE. -MAKE TWO RUNS AND LOG UP FROM 7780' TO 7000'. -8.01"GAUGE RING. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP ��"� Page 20 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 14:30 0.50 FISH P DECOMP RIG DOWN LOGGING TOOLS. 14:30 - 15:00 0.50 FISH P DECOMP RIG UP TO RUN 9-5/8"EZSV ON E-LINE. -PRE JOB SAFETY MEETING. 15:00 - 17:30 2.50 FISH P DECOMP RUN IN THE HOLE AND SET 9-5/8"EZSV ON E-LINE. -SET EZSV AT 7597'. PULL OUT OF THE HOLE WITH E-LINE. 17:30 - 18:30 1.00 FISH P DECOMP RIG DOWN SCHLUMBERGER E-LINE. PRE JOB SAFETY MEETING. RIG DOWN E-LINE EQUIPMENT FROM RIG FLOOR. 18:30 - 20:30 2.00 FISH P DECOMP PRESSURE TEST 9-5/9"EZSV AND CASING TO 250/3500 PSI. '-RIG UP TEST EQUIPMENT. -PRE JOB SAFETY MEETING -WORKING WITH PRESSURE. PRESSURE TEST TO 250 PSI FOR 5 CHARTED MIN. -GOOD TEST. PRESSURE UP TO 3500 PSI FOR 30 CHARTED MIN. -EXPERIENCED PUMP ISSUES AT 2900 PSI AND BLED OFF. -RE-TEST:3765 PSI INITIAL/3660 PSI @ 15 MIN/3690 PSI @30 MIN. -EMAILED COPY OF TEST AND WELLBORE TESTING CRITERIA CALCULATOR TO WTL. -CALLED WtLAND RECEIVED AUTHORIZATION TO PROCEED. -RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES. 20:30 - 00:00 3.50 STWHIP P WEXIT MAKE UP 9-5/8"WHIPSTOCK ASSEMBLY. -PRE JOB SAFETY MEETING WITH RIG CREW AND BAKER FISHING REP. -MAKE UP MILLING ASSEMBLY AND UBHO/FLOAT SUB. -SCRIBE ASSEMBLY TO ORIENT FOR GYRO. -BRING WHIPSTOCK ASSEMBLY UP PIPE CAT. -PREP WHIPSTOCK AND RUN IN HOLE. -BAKER FISHING REP REMOVED SHIPPING BOLT FROM BOTTOM TRIP ANCHOR. -WELLSITE LEADER AND RIG MANAGER WITNESSED. -VERIFIED THE SHEAR BOLTS WHERE IN THE SHEAR PLANE. -VERIFIED THREE(3)SHEAR SCREWS IN ANCHOR. -SET TO SHEAR AT 18K LBS. -MAKE UP WHIPSTOCK SLIDE TO MILLING ASSEMBLY. -48K LB SHEAR BOLT. -VERIFIED BY WELLSITE LEADER AND RIG MANAGER. -CHECKED SHEAR BOLT WITH SHEAR PLANE. -RUN IN THE HOLE WITH WHIPSTOCK ASSEMBLY PER BAKER FISHING REPRESENTATIVE. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 21 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/5/2013 00:00 - 02:00 2.00 STWHIP P WEXIT CONTINUE TO PICK UP AND RUN IN THE HOLE WITH THE WHIPSTOCK/WINDOW MILLING ASSEMBLY. -PRE JOB SAFETY MEETING. -TO 832'MD. -PICK UP WEIGHT=75K LBS;DOWN WEIGHT =80K LBS. -RUN IN HOLE WITH 3 STANDS OF 6-1/2" SPIRAL COLLARS AND 5 STANDS OF 4" HEAVY WEIGHT DRILL PIPE. 02:00 - 02:30 0.50 STWHIP P WEXIT SERVICE THE TOP DRIVE AND RIG FLOOR 'EQUIPMENT. 02:30 - 13:00 10.50 STWHIP P WEXIT RUN IN THE HOLE WITH THE WHIPSTOCK/ WINDOW MILLING ASSEMBLY ON 4"HT-38 DRILL PIPE STANDS OUT OF THE DERRICK FROM 832'TO 7541'MD. -PICK UP WEIGHT=174K LBS;DOWN WEIGHT=165K LBS. -RUNNING IN THE HOLE NO FASTER THAN 90'PER MINUTE. FILLING PIPE EVERY 20 STANDS. 13:00 - 13:30 0.50 STWHIP P WEXIT R/U HALLIBURTON WIRE E-LINE AND GYRO 13:30 - 15:00 1.50 STWHIP P WEXIT •RIH W/E-LINE,GYRO 15:00 - 17:30 2.50 STWHIP P WEXIT ORIENT WHIPSTOCK TO 3.3 DEGREES POOH W/E-LINE R/D HALLIBURTON E-LINE 17:30 - 18:00 0.50 STWHIP P WEXIT SET WHIPSTOCK ANCHOR @ 7597'W/15K DN WT P/U 190K(25K OVER UP WT)TO VERIFY ANCHOR SET •SHEAR WHIPSTOCK W/120K DN WT,(44K UNDER SOW) TOP OF WHIPSTOCK @ 7576' 18:00 - 20:00 2.00 STWHIP P WEXIT POOH F/7576'T/7145' 20:00 - 23:00 3.00 STWHIP P WEXIT M/U RTTS,RIH F/7145'T/7355',UP WT 170K, DN WT 160K RTTS SET @ 194' POOH F/194' TEST RTTS,250 PSI LOW,5 MIN,2000 PSI HIGH,5 MIN 23:00 - 00:00 1.00 STWHIP P WEXIT B/D,DRAIN STACK 3/6/2013 00:00 - 03:30 3.50 BOPSUR P WEXIT NIPPLE DOWN BOP STACK,PULL WEAR RING,LAY DOWN MOUSE HOLE FOLD WALKWAYS IN WELL HOUSE LIFT AND MOVE STACK OFF WELL CENTER 03:30 - 04:30 1.00 BOPSUR P WEXIT NIPPLE DOWN TUBING SPOOL AND REMOVE FROM WELL HOUSE. 04:30 - 09:30 5.00 BOPSUR P WEXIT CHANGE OUT 9-5/8"PACK OFF AND NIPPLE UP NEW TUBING SPOOL. -INSTALL SECONDARY ANNULUS VALVE ON NEW TUBING SPOOL 09:30 - 12:30 3.00 BOPSUR P WEXIT TEST PACK OFF TO 250 PSI LOW FOR 15 MINUTES/3500 PSI HIGH FOR 30 MINUTES. 12:30 - 15:30 3.00 BOPSUR P WEXIT N/U BOPE 15:30 - 17:00 1.50 BOPSUR P WEXIT R/U 4"TEST EQUIPMENT Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 22 of 75 Operation Summary Report Common Well Name F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. WWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 19:00 2.00 BOPSUR P WEXIT TEST BOPE AOGCC LOU GRIMALDI WAIVED TEST,20:34 HRS,03-05-2013 TEST BAG UPPER VBR CHOKE MANIFOLD VALVES 1,2,3,4,5,6, 7,9,K1,K2,K3,FOSV,DART 250 PSI LOW-5 MIN,3500 PSI HIGH-5 MIN 19:00 - 20:30 1.50 BOPSUR N SFAL 7,576.00 WEXIT TEST PLUG LEAKING,REMOVE TEST PLUG, SEVERAL AREAS OF SEAL WITH DAMAGED RUBBER CALL FOR CAMERON REP R/U TO TEST TD VALVES WHILE WAITING ON REP 20:30 - 21:30 1.00 BOPSUR P WEXIT TEST TD UPPER IBOP AND LOWER IBOP 250 PSI LOW-5 MIN,3500 PSI HIGH-5 MIN 21:30 - 23:30 2.00 BOPSUR N SFAL 7,576.00 WEXIT CAMERON REP INSPECT TEST PLUG ATTEMPT TO CHANGE OUT SEAL, REPLACEMENT SEAL DID NOT FIT PROPERLY RE-INSTALL OLD SEAL ON TEST PLUG, TIGHTEN TOP PLATE TO EXTRUDE SEAL FURTHER TEST PLUG WOULD NOT FIT THROUGH DUTCH RISER FLANGE ON TOP OF ANNULAR PULL TEST PLUG AND REMOVE OLD SEAL ATTEMPT TO INSTALLA SECOND REPLACEMENT SEAL,SUCCESSFUL RUN TEST PLUG BACK IN,R/U TO TEST 23:30 - 00:00 0.50 BOPSUR P WEXIT TEST CHOKE MANIFOLD VALVES 10,11,12,13 250 PSI LOW-5 MIN,3500 PSI HIGH-5 MIN 3/7/2013 00:00 - 02:30 2.50 BOPSUR P WEXIT CONTINUE BOPE TEST VALVE#14 SUPER CHOKE MANUAL CHOKE HCR CHOKE VALVE HCR KILL LINE VALVE MANUAL KILL VALVE MANUALCHOKE VALVES 250 PSI LOW-5 MINUTES,3500 PSI HIGH - 5 MINUTES 02:30 - 04:00 1.50 BOPSUR N RREP 7,355.00 WEXIT FAILED TEST WHILE TESTING MANUAL VALVES ON MUD CROSS ISOLATE MANUAL VALVES TO FIND LEAK CHOKE SIDE MANUAL VALVE ON MUD CROSS FOUND TO BE LEAKING 04:00 - 05:30 1.50 BOPSUR P WEXIT CONTINUE BOP TEST BLIND RAMS 250 PSI LOW-5 MINUTES,3500 PSI HIGH -5 MINUTES PERFORM KOOMEY DRAW DOWN TEST TIME TO ATTAIN 200 PSI-19 SEC TIME TO ATTAIN FULL PRESSURE-82 SEC 05:30 - 11:30 6.00 BOPSUR N RREP 7,355.00 WEXIT REPAIR MANUAL CHOKE VALVE ON BOP STACK Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 23 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-138 plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 14:00 2.50 BOPSUR P WEXIT FILL STACK CONTINUE BOPE TEST MANUAL ADJUSTABLE CHOKE 250 PSI LOW-5 MINUTES,3500 PSI HIGH-5 MINUTES BLOW DOWN AND R/D TEST EQUIPMENT INSTALL WEAR RING 14:00 - 16:30 2.50 BOPSUR P WEXIT P/U RTTS RUNNING TOOL RIH TO 194' P/U 5'PUP AND TIW VALVE.CLOSE TIW M/U TO RTTS AND RELEASE MONITOR WELL 10 MIN POOH F/7355'-T/7145' UD RTTS 16:30 - 17:00 0.50 BOPSUR P WEXIT RIH F/7145'-T/7572' UP WT 175K,DN WT 165K 17:00 - 20:30 3.50 STWHIP P WEXIT PJSM WITH CREWAND MUD ENGINEER MUD PUMP#1 SPR,20 SPM@ 286 PSI,30 SPM@ 380 PSI MUD PUMP#2 SPR,20 SPM@ 284 PSI,30 SPM@ 380 PSI DISPLACE WELL FROM 8.5 PPG BRINE TO 11.0 PPG LSND MILLING FLUID CIRC 420 GPM,1530 PSI 20:30 - 00:00 3.50 STWHIP P WEXIT WELL EXIT 03-07-2013 AT 20:30 HRS MILL WINDOW F/7575'T/7585' CIRC 450 GPM,1630 PSI,TQ ON 9K,TQ OFF 4K,WOB 6K UP WT 164K,DN WT 156K,ROT WT 160K 3/8/2013 00:00 - 03:00 3.00 STWHIP P WEXIT MILLING WINDOW F/7585'T/7593' PUMP HI-VIS SWEEP,NO INCREASE IN RETURNS CIRC 450 GPM,1630 PSI,TQ ON 6K,TQ OFF 4K,WOB 6K UP WT 164K,DN WT 156K,ROT WT 160K 03:00 - 05:30 2.50 STWHIP P WEXIT DRILL NEW FORMATION FOR FIT F/7593'T/ 7605' CIRC 450 GPM,1630 PSI,TQ ON 6K,TQ OFF 4K,WOB 6K UP WT 164K,DN Wr 156K,ROT WT 160K 05:30 - 07:30 2.00 STWHIP P WEXIT PULL SUCTION SCREEN ON PUMP#2 PUMP BARALIFT SUPER SWEEP AND CIRCULATE OUT OF HOLE 650 GPM,2670 PSI Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 24 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-138 plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 09:00 1.50 STWHIP P WEXIT PERFORM FIT LINE UP TO PUMP DOWN DP AND KILL LINE CLOSE ANNULAR TEST MW-11.0 PPG DEPTH-7605 TVD BBLS PUMPED-1.0 BBLS RETURNED-2.0 FIT PSI-280 PSI EMW-11.7 PPG LEAK OFF PRESSURE-262 PSI AFTER MONITORING 10 MINUTES 09:00 - 11:00 2.00 STWHIP P WEXIT DRILL NEW FORMATION F/7605'T/7615 CIRC 450 GPM,1630 PSI,TQ ON 6K,TQ OFF 4K,WOB 6K UP WT 164K,DN WT 156K,ROT WT 160K 11:00 - 14:00 3.00 STWHIP P WEXIT POH TO WINDOW WORK STRING MILLS THROUGH WINDOW TO DRESS FOR 8-1/2 INTERMEDIATE BHA CIRCULATE HI-VIS SWEEP SURFACE TO SURFACE,NO INCREASE IN RETURNS 635 GPM,2620 PSI INSTALL POWER SLIPS,PUMP DRY JOB,B/D TD 14:00 - 20:00 6.00 STWHIP P WEXIT POOH F/7593'T/811' UP WT 72K,DN WT 68K R/D POWER SLIPS,INSTALL BUSHINGS 20:00 - 00:00 4.00 STWHIP P WEXIT STAND BACK HWDP L/D DC,L/D MILLS,CLEAR AND CLEAN RIG FLOOR 3/9/2013 00:00 - 01:00 1.00 STWHIP P WEXIT L/D MILLING BHA CLEAR FLOOR 01:00 - 03:00 2.00 STMILL P WEXIT P/U WEAR BUSHING PULLER,BACK OUT LDS AND PULL BUSHING P/U STACK FLUSHING TOOL AND FLUSH STACK WITH MUD PUMPS RE-RUN WEAR BUSHING,RUN IN 4 EACH LDS 03:00 - 04:00 1.00 DRILL P WEXIT B/D KILL LINE AND SURFACE EQUIPMENT CHANGE OUT HANDLING EQUIPMENT 04:00 - 10:00 6.00 DRILL P WEXIT PJSM P/U BHA P/U 8-1/2"INTERMEDIATE BHA 10:00 - 12:00 2.00 DRILL P WEXIT RIH F/1035'T/2925'FILLING PIPE EVERY 20 STANDS. UP WT 144K,DN WT 85K 12:00 - 12:30 0.50 DRILL P WEXIT SERVICE RIG Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 25 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 19:00 6.50 DRILL P WEXIT RIH F/2925'T/7558'FILLING PIPE EVERY 20 STANDS UP WT 172K,DN WT 135K 19:00 - 19:30 0.50 DRILL P WEXIT PJSM W/HALLIBURTON E-LINE,GYRODATA 19:30 - 21:00 1.50 DRILL P WEXIT •M/U X-O'S,GYRO HEAD,AND SIDE ENTRY SUB IN DRILL STRING 21:00 - 23:00 2.00 DRILL P WEXIT RIH WITH GYRO AND ORIENT TO 0 DEGREES (TRUE NORTH)F/7558'T/7593' 23:00 - 00:00 1.00 i DRILL P WEXIT RIH W/PUMPS F/7593'T/7609' CIRC 450 GPM,2550 PSI,TQ ON OK,TQ OFF OK,WOB 4K UP WT 175K,DN WT 145K,ROT WT OK SPR'S AT 7,595'MD(7,472'TVD),TIME 2300, 'MW11.0PPG #1 MP-20/30 SPM=407/542 PSI #2 MP-20/30 SPM=401/536 PSI 3/10/2013 00:00 - 01:00 1.00 DRILL P WEXIT REAM F/7609'T/7615' CIRC 450 GPM,2550 PSI,TQ ON OK,TQ OFF •OK,WOB 4K UP WT 175K,DN WT 145K,ROT WT OK 01:00 - 14:00 13.00 DRILL P INTI DRILL 8-1/2 INTERMEDIATE HOLE F/7615'T/ 7882'(7703'TVD) SLIDING WITH GYRO AND SIDE ENTRY SUB 500 GPM,3150 PSI ON,3050 PSI OFF MW 11.0 IN/10.9 OUT ECD 11.35 0 RPM,TQ ON OK,TQ OFF OK WOB 3-5K AST=7.0 HRS,ART=0 HRS,ADT=7.0 HRS, ACT=4.1 HRS,JARS HRS=7.0 HRS UP WT 175K,DN WT 140K,ROT WT OK CONFIRM BAKER SURVEYS WITH GYRO RECORDED 2 REIABLE SURVEYS WITH MWD TOOL 14:00 - 15:30 1.50 DRILL P INTI POOH F/7882'T/7558' UNWRAP E-LINE AROUND DRILL PIPE 15:30 - 16:30 1.00 DRILL P INTI POOH F/7,476'T/674'W/HES WIRELINE PULLED TIGHT,WORK E-LINE,UNABLE TO PULL FURTHER Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 26 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 20:00 3.50 DRILL N DPRB 7,558.00 INTI HES INVESTIGATE EQUIPMENT 'DEVELOP REMEDIAL PLAN FORWARD, VERIFY PLAN FOR WELL CONTROL WAIT ON WIRE LINE CLAMPS TO FROM HES BREAK CONNECTION BELOW SIDE ENTRY SUB AND LIFT OFF STUMP TO EXPOSE E-LINE INSTALL WIRE LINE CLAMP,REMOVE KNOT IN E-LINE,CONTINUE POOH WITH E-LINE STRAIGHTENING KINKS AS NECESSARY 20:00 - 21:00 1.00 DRILL P INTI R/D HES E-LINE AND GYRODATA 21:00 - 21:30 0.50 DRILL P INTI SERVICE RIG 21:30 - 22:00 0.50 DRILL P INTI RIH F/7558'T/7882' WASH LAST STAND TO BOTTOM 22:00 - 22:30 0.50 DRILL P INTI CIRCULATE BOTTOMS UP FOR BASELINE IECD PWD 11.38/CALCULATED 11.375 SPR'S:7,882'MD(7,756'TVD)-TIME=22:00, MW=11.0 PPG #1 MP-20/30 SPM=284/400 PSI #2 MP-20/30 SPM=280/375 PSI 22:30 - 00:00 1.50 DRILL P INTI DRILL 8-1/2 INTERMEDIATE HOLE F/7882'T/ 7932'(7805'TVD) 500 GPM,2930 PSI ON,2750 PSI OFF MW 11.0 IN/11.0 OUT ECD 11.4 60 RPM,TQ ON 7K,TQ OFF 5K WOB 3-5K !AST=0.0 HRS,ART=.7 HRS,ADT=0.7 HRS, !ACT=.4 HRS,JARS HRS=7.7 HRS UP WT 187K,DN WT 150K,ROT WT 162K Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 27 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/11/2013 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2 INTERMEDIATE HOLE F/7932'T/ 8314'(8159'TVD) 550 GPM,2930 PSI ON,2750 PSI OFF MW 11.0 IN/11.0 OUT ECD 11.4 60 RPM,TQ ON 6K,TQ OFF 5-6K WOB 3-12K AST=5.0 HRS,ART=2.5 HRS,ADT=7.5 HRS, JARS HRS=15.2 HRS UP WT 197K,DN WT 148K,ROT WT 166K SPR'S:8,510'MD(8,330'TVD)-TIME=22:30, MW=11.3 PPG #1 MP-20/30 SPM=257/373 PSI #2 MP-20/30 SPM=261/375 PSI WITNESSED SPLINTERED SHALE AT SHAKERS -CUTTINGS SIZE VARIED FROM 3/4"TO 2-1/2" 'LONG -VOLUME OF CUTTINGS FLUCTUATING+/- '10-15"/ CONTACT ODE,REQUEST OPERATIONS CHANGE TO APPROVED WELL PLAN -APPROVED WELL PLAN CALLED FOR 11.0 MW -REQUESTED CHANGE,INCREASE TO 11.3 PPG REQUESTED CHANGE APPROVED©17:46 HRS -START WEIGHTING SYSTEM TO 11.3 PPG Printed 6/24/2013 1.20:07PM North America-ALASKA-BP Page 28 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date • From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P INTI DRILL 8-1/2 INTERMEDIATE HOLE F/8314'T/ 8524'(8343'TVD) CONTINUE WEIGHTING DRILLING FLUID TO 11.3 PPG 520 GPM,3600 PSI ON,3410 PSI OFF MW 11.3 IN/11.3OUT ECD 11.5 60 RPM,TQ ON 4-7K,TQ OFF 3-6K WOB 5-7K AST=4.9 HRS,ART=1.4 HRS,ADT=6.3 HRS, JARS HRS=21.5 HRS UP WT 197K,DN WT 151K,ROT WT 167K STARTING AT 20:00 HRS EXPERIENCE DIFFICULTY SLIDING, LUBRICANTS AT 0.25%BY VOLUME -CREW STILL WEIGHTING UP,11.3 PPG AT 23:30 HRS -DIFFERENTIAL PRESSURE FUNCTION NOT •OPERATING CORRECTLY ON AUTO DRILLER AS AUTO DRILLER REACHED DIFFERENTIAL PRESSURE SETTING -DRAWWORKS WOULD LIFT STRING AND SET BRAKE -TOP DRIVE WOULD SHUT DOWN - PUMPS WOULD SHUT DOWN AFTER HITTING MAX PRESSURE SETTING STARTING AT 24:00 HRS BEGIN INCREASING LUBRICANTS TO 0.5%BY VOLUME,ADDING NXS-LUBE -STILL EXPERIENCING DIFFICULTY SLIDING -TEST MOTOR BY ROTATING,ABLE TO DRILL AHEAD W/400 PSI DIFF,150 FT/HR ROP -STRING HANGING UP,AUTO DRILLER STILL NOT WORKING PROPERLY -VARY PUMP OUTPUT FROM 500 GPM TO 600 GPM ATTEMPTING TO OPTIMIZE MOTOR -ABLE TO SLIDE 10 TO 12 FT/HR STARTING AT 02:00 HRS BEGIN INCREASING LUBRICANTS TO 1.0%BY VOLUME,ADDING DRILL&SLIDE,EZ GLIDE -SHUT AUTO DRILLER OFF -DRILL MANUALLY USING DIFFERENTIAL PRESSURE -SLIDE RATE INCREASE TO 40 TO 60 FT/HR OA PRESSURE 1000 PSI,BLED OFF TO 500 PSI Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 29 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/12/2013 00:00 - 12:00 12.00 DRILL P INTI DRILL 8-1/2 INTERMEDIATE HOLE F/8524'T/ 8622'(8426'TVD) 550 GPM,3550 PSI ON,3540 PSI OFF MW 11.3 IN/11.3OUT ECD 11.6 0 RPM,TQ ON OK,TQ OFF OK WOB 3-12K AST=6.0 HRS,ART=0.0 HRS,ADT=6.0 HRS, JARS HRS=27.5 HRS UP WT 180K,DN WT 151K,ROT WT OK SPR'S:8,590'MD(8,399'TVD)-TIME=08:00, MW=11.3 PPG #1 MP-20/30 SPM=257/373 PSI #2 MP-20/30 SPM=261/375 PSI OA-900 PSI 12:00 - 18:00 6.00 DRILL P INTI DRILL 8-1/2 INTERMEDIATE HOLE F/8622' T/8675'(8471'TVD) 550 GPM,3850 PSI ON,3750 PSI OFF MW 11.3 IN/11.3OUT •ECD 11.6 0 RPM,TQ ON OK,TQ OFF OK WOB 5-10K AST=2.7 HRS,ART=0.0 HRS,ADT=2,7 HRS, JARS HRS=30.2 HRS UP WT 175K,DN WT 151 K,ROT WT OK SPR'S:8,675'MD(8,471'TVD)-TIME=19:00, MW=11.3 PPG #1 MP-20/30 SPM=230/335 PSI #2 MP-20/30 SPM=228/338 PSI OA-400 PSI SLIDING STILL DIFFICULT,DRILL STRING HANGING UP NOT ACHIEVING REQUIRED BUILD RATES TO STAY ON TARGET -4-DLS REQUIRED,ACTUAL DLS VARIED FROM 1 TO 3.2 INCLINATION 4 DEGREES BEHIND WELL PLAN CONFERENCE WITH BAKER,BP ANCHORAGE -DECIDE TO CIRC1X BUS,POOH TO WINDOW,SPOT 30 BBL PILL W/10%EP MUD LUBE 18:00 - 19:00 1.00 DRILL N DPRB 8,675.00 INTI CIRCULATE AND RECIPROCATE 1X BUS 550 GPM,3850 PSI,60 RPM,TQ OFF 7K PUMPS ON,UP WT 170K,DN WT 160K,RT WT 157K PUMPS OFF,UP WT 175K,DN WT 165K,ROT WT 167K Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 30 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-138 plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 21:00 2.00 DRILL N DPRB 7,593.00 INTI POOH F/8675'T/7593' ROLL PUMPS @ 1BPM,290 PSI UP WT 170K,DN WT 146K 21:00 - 21:30 0.50 DRILL P INTI SERVICE RIG 21:30 - 00:00 2.50 DRILL N DPRB 7,593.00 INTI MIX PILL 30 BBL W/10%BY VOLUME EP MUD LUBE PILL 3/13/2013 00:00 - 02:00 2.00 DRILL N DPRB 7,675.00 INTI PLACE BIT OUT OF WINDOW AT 7598' SPOT 30 BBL PILL W/10%BY VOLUME EP MUD LUBE RIH T/7675' CIRCULATE EP MUD LUBE PILL TO SURFACE 550 GPM,3600 PSI,40 RPM BEFORE PUMPING EP MUD LUBE PILL-UP Wr 175K,DN WT 165K,ROT WT 167K AFTER PUMPING EP MUD LUBE PILL-UP WT 162K,DN WT 153K,ROT WT 159K 02:00 - 04:00 2.00 DRILL N DPRB 8,675.00 INTI RIH F/7675'T/8675' UP WT 174K,DN WT 156K,ROT WT 160K PUMPS ON UP WT 178K,DN WT 158K-PUMPS OFF MONITOR HOLE FILL ON TRIP TANK 04:00 - 10:30 6.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE F/8675'Ti 8788'(8553'TVD) 550 GPM,4050 PSI ON,3900 PSI OFF MW 11.3 IN/11.3 OUT ECD 11.67 60 RPM,TQ ON 5K,TQ OFF 7K WOB 5-10K AST=2.9 HRS,ART=0.5 HRS,ADT=3.4 HRS, JARS HRS=33.6 HRS UP WT 174 K,DN WT 162K,ROT WT 159K OA-90 PSI 10:30 - 14:00 3.50 DRILL N RREP 7,563.00 INTI HIGH PRESSURE HAMMER UNION WASHED OUT ON MUD PUMP#1 -UNION WAS LOCATED BETWEEN ISOLATION VALVES ON MUD PUMP DISCHARGE LINE MONITOR WELL FOR 10 MINUTES POOH W/PUMPS ON F/8788'T/7563' -250 GPM,1150 PSI -UP WT 170K,DN WT 146K 14:00 - 15:30 1.50 DRILL N RREP 7,563.00 INTI B/D TD,CIRCULATE OVER TOP OF HOLE REPAIR MUD PUMP#1,AND PRESSURE TEST T/4300 PSI NO LOSSES Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 31 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 18:00 2.50 DRILL N RREP 8,788.00 INTI RIH F/7563'T/8788'WASH LAST STD TO BOTTOM UP WT 180K,DN WT 175K 18:00 - 00:00 6.00 DRILL P INTI 'DRILL 8-1/2"INTERMEDIATE HOLE F/8788'T/' 8942'(8661'TVD) 550 GPM,4150 PSI ON,4000 PSI OFF MW 11.3 IN/11.3OUT ECD 11.8 60 RPM,TQ ON 6K,TQ OFF 4K WOB 5-7K AST=3.5 HRS,ART=0.7 HRS,ADT=4.2 HRS, JARS HRS=37.8 HRS UP WT 180 K,DN WT158K,ROT WT170K SPR'S:8,900'MD(8,633'TVD)-TIME=20:00, MW=11.3 PPG #1 MP-20/30 SPM=234/335 PSI #2 MP-20/30 SPM=238/337 PSI OA-450 PSI 3/14/2013 00:00 - 01:00 1.00 DRILL P INTI -DRILL 8-1/2"INTERMEDIATE HOLE F/8942'T/' 8960'(8675'TVD) 550 GPM,4150 PSI ON,4000 PSI OFF MW11.3IN/11.3OUT ECD 11.8 60 RPM,TQ ON 5K,TQ OFF 4K WOB 5-7K AST=0.0 HRS,ART=0.3 HRS,ADT=.3 HRS, JARS HRS=38.1 HRS UP WT 180 K,DN WT 158K,ROT WT 170K WITNESSED REVERSE DRILLING BREAK AT 8955',DRILLED 5'TO 8960' -CIRCULATE BOTTOMS UP TO VERIFY FORMATION SPR'S:8,900'MD(8,633'TVD)-TIME=20:00, MW=11.3 PPG #1 MP-20/30 SPM=234/335 PSI #2 MP-20/30 SPM=238/337 PSI OA-450 PSI 01:00 - 04:30 3.50 DRILL P INTI CONDITION AND CIRCULATE -3X'S BUS -450 GPM,3650 PSI, UP WT 180K,DN WT 164K TAKE SAMPLES TO VERIFY FORMATION CUTTINGS 100%SAND-GLAUCONITE GEOLOGISTS CALL TD 8960'AT 02:45 HRS SPR'S:8,960'MD(8,675'TVD)-TIME=04:30, MW=11.3 PPG #1 MP-20/30 SPM=255/368 PSI #2 MP-20/30 SPM=260/365 PSI LOSSES-7BBLS Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 32 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay • Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) ' 04:30 - 10:30 6.00 DRILL P • INTI 1POOH W/PUMPS ON F/8960'T/7593'(7470' TVD) I -250 GPM,1150 PSI I -UP WT 180K,DN WT 164K,ROT WT 160K 10:30 - 12:00 1.50 DRILL P INTI MONITOR WELL CLEAR FLOOR,P/U RTTS 12:00 - 13:00 1.00 DRILL P INTI POOH F/7463'T/7369'(1 STD) HOLD PJSM WITH HES 13:00 - 14:00 1.00 DRILL P INTI M/U RTTS RIH F/7369'T/7486' SET RTTS AT 101' -RELEASE AND POOH WITH STD 1 1 . UP WT 160K,DN WT'150K 14:00 - 15:00 1.00 DRILL P INTI R/U TO P-TEST RTTS -TEST SAME TO 1000 PSI FOR 5 MIN ON CHART Printed 6/24/2013 1 20:07PM North America-ALASKA-BP Page 33 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release 4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 00:00 9.00 BOPSUR P INTI BOLDS AND PULL WEAR RING • M/U 4"TEST JOINT,INSTALL TEST PLUG,FILL STACK AOGCC WAIVED ORIGINAL TEST NOTIFICATION AT 21:46 HRS 03/13/2013,JOHN •CRISP TEST CHOKE MANIFOLD VALVES 250 PSI LOW,3500 PSI HIGH -1,2,3,4,5,6,7,8,9,10, 11,12,13,14,15 TEST MUD CROSS VALVES 250 PSI LOW,3500 PSI HIGH -MANUAL CHOKE,HCR CHOKE,MANUAL KILL,HCR KILL TEST FLOOR VALVES 250 PSI LOW,3500 PSI HIGH FOSV 1 AND 2,DART VALVE,UPPER IBOP, LOWER IBOP TEST BOP STACK 250 PSI LOW,3500 PSI •HIGH • -ANNULAR,UPPER 2-2/8"X 5"VBR,LOWER 2-2/8"X 5"VBR,BLIND SHEAR TEST MANUAL CHOKE AND REMOTE OPERATED CHOKE TO 1500 PSI FUNCTION ALL BOP COMPONENTS FROM BOTH REMOTE PANELS PERFORM ACCUMULATOR DRAW DOWN TEST -2950 SYSTEM PRESSURE BEFORE TEST 1800 PSI AFTER COMPONENT CLOSURE 200 PSI ATTAINED IN 19 SEC -3000 PSI ATTAINED IN 89 SEC -NITROGEN AVERAGE PSI-2050 PSI ACCUMULATOR CHARGING PUMP TEST -ELECTRIC PUMPS ON AT 2600 PSI -ELECTRIC PUMPS OFF AT 3000 PSI -AIR PUMPS ON AT 2200 PSI AIR PUMPS OFF AT 2850 PSI Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 34 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. - IUWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 3/15/2013 00:00 - 04:00 4.00 BOPSUR P INTI RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES MAKE UP WEAR RING TOOL AND INSTALL WEAR RING PICK UP STAND AND MAKE UP RUNNING •TOOL AND RUN IN THE HOLE TO THE RTTS AND ENGAGE - INSTALL TIW VALVE ON TOP OF STUMP -CLOSE ANNULAR AND CHECK FOR PRESSURE,WELL DEAD -RIG DOWN TIW VALVE AND PULL OUT OF THE HOLE WITH RTTS,LAY DOWN SAME MONITOR WELL ON TRIP TANK. 04:00 - 07:00 3.00 DRILL P INTI RUN IN THE HOLE FROM 7,458'TO 8,960'. -MONITOR TRIP TANK,TOTAL DISPLACEMENT=7.1 BBLS. UP WT=180K,DN WT=164K. -WASH LAST STAND DOWN GPM=475,RPM =60. 07:00 - 10:00 3.00 DRILL P INTI CIRCULATE 3 BOTTOMS UP. -GPM=500 -PUMP PRESSURE 3,670 PSI SPR'S:8,960'MD(8,633'TVD)-TIME=10:00, MW=11.3 PPG #1 MP-20/30 SPM=225/368 PSI #2 MP-20/30 SPM=260/365 PSI 10:00 - 10:30 0.50 DRILL P INTI SPOT LCM PILL ON BOTTOM AT 8,960'.PULL • OUT OF THE HOLE TO 8,860'AND CIRCULATE BOTTOMS UP. 10:30 - 12:00 1.50 DRILL P INTI MONITOR HOLE FOR 10 MINUTES. PULL STAND OUT OF THE HOLE TO 8,788'. DROP SLICK LINE RABBIT DOWN HOLE. 12:00 - 15:00 3.00 DRILL P INTI PUMP OUT OF HOLE F/8788'T/7558' -250 GPM -1150 PSI UP WT 160,DN WT 150, -CALC.DISPLACEMENT 7.8 BBLS,ACTUAL DISPLACEMENT 12.4 BBLS,4.6 BBL LOSS 15:00 - 15:30 0.50 DRILL P INTI MONITOR WELL 15 MIN I WELL STATIC PUMP DRY JOB,B/D TD LINE UP ON TRIP TANK 15:30 - 21:00 5.50 DRILL P INTI POOH F/7558'T/1035' -UP WT 70K,DN WT 70K MONITOR WELL 15 MIN -WELL STATIC Printed 6/24/2013 1.20:07PM North America-ALASKA-BP Page 35 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W C:DRILL(7.206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272(g81.55usft(above Mean Sea Level) Date From-To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 121:00 - 00:00 3.00 DRILL , P INTI L/D BHA -R/B8STD,4"HWDP -L/D 1STD 5"HWDP L/D 1 STD FLEX COLLARS DOWNLOAD MWD(17 MINUTES FOR FULL DOWNLOAD) TOTAL CALCULATED DISPLACEMENT 48 BBLS TOTAL ACTUAL DISPLACEMENT 54.3 BBLS • TOTAL LOSS FOR POOH 6.3 BBLS 3/16/2013 00:00 - 03:30 3.50 I DRILL P INTI L/D BHA I-BREAK BIT DULL BIT GRADE 0-1-CT-G-1-NO-TD -ORIENTING SUB AND FILTERING SUB -TOP STOP SUB,BCPM,MWD STAB,ON TRACK MWD,BOTTOM STOP SUB -MOTOR I' -CALC.DISPLACEMENT 1.8 BBLS,ACTUAL DISPLACEMENT 2.8 BBLS,1.0 BBL LOSS 03:30 - 04:30 1.00 DRILL P INTI MONITOR WELL i -WELL STATIC P/U WEAR RING PULLER,PULL WEAR RING 04:30 - 08:30 4.00 DRILL P INTI CHANGE OUT RAMS FROM 2-7/8"X 5-1/2"VBR TO 7". RIG UP TO TEST RAMS,DRAIN STACK AND SET TEST PLUG 08:30 - 09:30 1.00 DRILL i P INTI PRESSURE TEST 7"TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH.GOOD TEST, SEE ATTACHED CHART. -RIG DOWN TEST EQUIPMENT. 09:30 - 12:00 2.50 CASING P. INTI PJSM ON RIG UP OF CASING EQUIPMENT. -DOYON CASING REPRESENTATIVE I CONDUCTED PJSM WITH RIG CREW ON RUNNING CASING EQUIPMENT RIG UP LOW PRESSURE PIPE FILL LINE -SHUT IN#1 MUD PUMP -LOCK OUT/TAG OUT#2 MUD PUMP -FILL PIPE WITH#2 CHARGE PUMP -REMOVE BX ELEVATORS AND INSTALL SIDE DOOR ELEVATORS. 12:00 - 12:30 0.50 CASING P INTI -PJSM WITH NEW CREW AND DOYON CASING 12:30 - 17:00 4.50 CASING P INTI RUN 7",26#,L-80,VAM TOP LINER MAKE UP SHOE TRACK,BAKER LOK BOTTOM 3 JTS. -FILL SHOE TRACK CHECK FLOAT,FLOAT GOOD -RIH W/37 JTS OF 7"FROM:SURFACE TO: 1532' -UP WT- 68K DN WT- 65K 17:00 - 18:30 1.50 CASING P INTI CHANGE HANDLING TOOLS TO RUN IN ON DRILL PIPE -SWAP 7"150 TON SIDE DOOR ELEVATORS TO DP ELEVATORS -MAKE UP BAKER LINER HANGER -FILL TOP OR HANGER W/PAL MIX Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 36 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:00 0.50 CASING P INTI RIH -F/1532'T/1661' -PU WT=70K,DN WT=70K RIG DN DOYON CASEING 19:00 - 00:00 5.00 CASING P INTI CONT TO RIH W/LINER ASSEMBLY ON 4"DP -F/1661'T/5348' -FILL PIPE EVERY 10 STANDS -UP WT=122K DN WT=117K -CALC.DISP=29 BBL,ACT.DISP=27.7 BBL, 1.3 BBL LOSS -MONITER WELL=STATIC HOT WATER PLANT DOWN -HEAT RIG WATER TO 80 DEGREES F FOR SLB CEMENTERS 3/17/2013 00:00 - 03:30 3.50 CASING P INTI RIH W/7"LINER -F/ 5348'T/7492' -UPWT-137K,DN WT-129K VAC TRUCKS ON LOCATION FOR CEMENT JOB 02:00 HRS 03:30 - 05:00 1.50 CASING P INTI CIRCULATE BUS 210 GPM,650 PSI SLB NOTIFIED RIG AT 0400 HRS THAT SAMPLES OF HEATED RIG WATER REQUIRED 05:00 - 07:00 2.00 CASING N CEMT 7,942.00 , INTI CIRCULATE AND CONDITION MUD -SLB RECEIVED RIG WATER SAMPLE AT 0420 HRS NOTIFIED BY CH2 DISPATCH THAT HOT WATER PLANT BACK UP AND RUNNING -WILL NOT HAVE HOT WATER UNTIL 0600 HRS -MOVE AHEAD WITH RIG WATER SAMPLES -DISPATCH VAC TRUCK TO HOT WATER PLANT FOR CEMENT JOB,0430 HRS -REQUESTED TO BE MOVED TO FRONT OF LINE 07:00 - 09:30 2.50 CASING P INTI PJSM WITH CREW -RIH WITH 7"LINER ON 4"DRILL PIPE F/ 7,942'T/8,930' -UPWT-147K,DN WT-129K 09:30 - 11:00 1.50 CASING P INTI PICKUP 10'AND 15'PJTS,RIH F/8,930'T/ 8,955' -PICK UP CEMENT HEAD -R/U VALVE AND CEMENT HOSE MAKE UP TO 4"JOINT IN MOUSEHOLE, TORQUE UP WITH TOP DRIVE,BREAK CIRCULATION 11:00 - 15:00 4.00 CASING P INTI CIRCULATE AND CONDITION MUD -2.5X BUS, -STAGE PUMPS F/2BPM T/6BPM,1000 PSI -8 BBL LOSS TOTAL CIRCULATION HOLD PJSM W/RIG CREW,SLB,BPXA Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 37 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date 4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:OO:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-138 plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 17:30 2.50 CEMT P INTI CEMENT 7"LINER AS FOLLOWS: SET LINER ON DEPTH 8958' PTEST CEMENT LINE -PUMP 6.1 BBLS H2O AND TEST TO 240 PSI, TEST GOOD -PRESSURE UP TO 4470 PSI,NO LEAKS -BLEED OFF H2O TO FLOW LINE NO LEAKS IN CEMENT LINE PROCEED W/ JOB -PUMP 34.5 BBLS 12.0 PPG MUD PUSH AT 4 BPM LEAD -PUMP 46.5 BBLS,12.0 PPG LITECRETE CEMENT AT 5.0 BPM, -YIELD 1.63 CU FT/SX(160 SX) TAIL -PUMP 18 BBLS,15.8 PPG CLASS G CEMENT I, AT5.OBPM YIELD 1.17 CU FT/SX(62 SX) '-DROP DP WIPER POSITIVE INDICATION DART LEFT CEMENT HEAD DISPLACE -DISPLACE WITH CEMENTERS WITH 11.3 PPG LSND MUD -5 BPM,600 PSI -SLOW TO 3 BPM -LATCH DP WIPER INTO LINER WIPER PLUG, 75.5 BBL DISPLACED -INCREASE RATE T/5 BPM,PSI STEADILY INCREASE TO 720 PSI -SLOW PUMP TO 2 BPM,125.7 BBL DISPLACED -BUMP PLUG,132.4 BBL DISPLACED,400 PSI, 4 BBL LESS CALC. DID NOT RECIPROCATE PIPE AFTER STARTED PUMPING CEMENT INCREASE PRESSURE TO 3000 PSI TO SET HANGER -SET 50K DN WT ON HANGER TO CONFIRM SET INCREASE PRESSURE TO 4200 PSI TO RELEASE RUNNING TOOL -P/U 5,EXPOSE DOGS -SET 75K DN WT,SET PACKER -P/U 5'AND SET DN TO CONFIRM -P/U 5',ROTATE 15 RPM,SET DN 80K,FINAL CONFIRMATION BLEED OFF,CHECK FLOATS,GOOD CEMENT IN PLACE AT 17:20 HRS -4 BBL TOTAL LOSS DURING CEMENT JOB Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 38 of 75. Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 19:00 1.50 CEMT P INTI PRESSURE UP TO 500 PSI -P/U STRING TO UNSEAT PACKOFF, PRESSURE BLED TO 0 CIRCULATE W/MUD PUMPS -440 GPM,1800 PSI,1.25X BUS -DID NOT WITNESS STRONG CEMENT SHOW AT SURFACE -PH PEAKED AT 11.9 19:00 21:30 2.50 CEMT P INTI BREAK TD OUT OF CEMENT HEAD CLEAN AND UD SAME -UD SINGLE `• BLOW DOWN 21:30 - 00:00 2.50 CEMT P INTI L/D PUP JOINTS PUMP DRY JOB POOH F/737T.TT4452' -UPWT-90K,DNWT-90K 3/18/2013 00:00 - 05:00 5.00 CASING P INTI POOH FROM 4452'TO SURFACE -PJSM PRIOR TO LAYING DOWN LINER RUNNING TOOL -L/D RUNNING TOOL -UP WT 90K,DN WT 90K 05:00 - 06:00 1.00 BOPSUR P INTI MONITOR WELL FOR 10 MINUTES,STATIC -PULL WEAR RING AND DRAIN STACK 06:00 - 09:00 3.00 BOPSUR P INTI CIO TOP RAMS F/T T/ 2-7/8"X 5-1/2"VBR -M/U TEST JOINT ASSEMBLY AND TEST PLUG -RUN IN AND SET TEST PLUG 09:00 - 09:30 0.50 BOPSUR •P INTI TEST VBR'S TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH -GOOD TEST 09:30 - 11:00 1.50 BOPSUR P INTI ,BREAK DOWN TEST JOINT ASSEMBLY AND DRAIN STACK. -PULL TEST PLUG -INSTALL WEAR RING -UD TEST JOINT 11:00 - 14:00 3.00 BOPSUR P INTI CASING PRESSURE TEST -250/3500 PSI LOW 5 MINUTES,HIGH FOR 30 MINUTES -TEST GOOD 14:00 - 17:30 3.50 DRILL P INTI MAKE UP BHA -6.125 BIT,MTR,MWD,FLEX COLLAR -PU WT=50K SO WT=50K 17:30 - 18:00 0.50 DRILL P INTI PLUG IN DOWN LOAD MWD '18:00 - 19:00 1.00 DRILL P INTI PJSM W/BAKER,LOAD SOURCE. 19:00 - 20:00 1.00 DRILL P INTI CONT.PU/BHA -F/160'T/720' _ -PU WT=60K SO WT=60K 20:00 - 20:30 0.50 } DRILL P INTI SHALLOW HOLE MWD TEST -PUMP 300 GPM,1560PSI -TEST GOOD 20:30 23:00 2.50 DRILL P INTI CONT BHA -LD 1 SINGLE HWDP -RIH HOLE F/720'T/1887' -PU WI=65K SO WT=65K -INSTALL PS-21 SLIPS Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 39 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. UWI: Active datum:F-13B plan P272#2181.55usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 DRILL P INTI RIG EVAC DRILL -SIMULATED H2S ALARM -DONNED AIR PACKS -INSTALLED TIW -SHUT PIPE RAMS 3/19/2013 00:00 - 05:30 5.50 DRILL P INTI RUN IN THE HOLE WITH THE 6-1/8"DRILLING BHA -FROM 1887'TO 6420'. -FILLING PIPE EVERY 20 STANDS -UP WEIGHT=131K LBS;DOWN WEIGHT= 124K LBS. 05:30 - 06:00 0.50 DRILL P INTI SERVICE TOP DRIVE&IRON DERRICK MAN 06:00 - 08:00 2.00 DRILL P INTI PERFORM DERRICK INSPECTION AND INSPECT RIG FLOQR EQUIPMENT -ROUSTABOUTS WORKING FLOOR POSITIONS -LEARNING ROLES AND RESPONSIBILITIES OF FLOOR HANDS. 08:00 - 08:30 0.50 DRILL P INTI QHANGE OUT BX ELEVATORS AND TEST. 08:30 - 12:00 3.50 DRILL P INTI RUN IN THE HOLE WITH THE 6-1/8"DRILLING }BHA -FROM 6428'TO 8843' 1-UPWEIGHT=176K LBS;DOWN WEIGHT= 145K LBS 12:00 - 12:30 0.50 DRILL P !NM j WASH DOWN AND TAG CEMENT ' -FROM 8843'10 8855' -PUMPING AT 100GPM AND 600PSI -UP WEIGHT=172K LBS;DOWN WEIGHT= 150K LBS. -TAG CMT AT 8855'. 12:30 - 14:30 2.00 DRILL P I INTI DISPLACE THE WELL TO 8.5 PPG QUIKDRIL-N -PUMP 30 BBLS HI-VIS SPACER. -20 BBLS EP MUD LUBE PILL. -PUMP 770 BBLS OF 8.5 QUIKDRIL-N MUD -OVER DISPLACED BY 100 BBLS TO ENSURE CLEAN FLUID. -325GPMAT2100PSI. 14:30 - 15:30 1.00 DRILL P INTI MONITOR WELLAND PERFORM NEGATIVE PRESSURE TEST. -PERFORM NEGATIVE PRESSURE TEST ON 7' LINER TOP. -MONITOR WELL FOR 30 MIN.ON CONTINUOUS HOLE FILL. -NO GAINS OR LOSSES TO TRIP TANK -SHUT DOWN HOLE FILL AND MONITOR WELL FOR 30 MIN. -WELL IS STATIC. -DISCUSS RESULTS WITH WTL BEFORE PROCEEDING. 15:30 - 20:00 4.50 DRILL P INTI DRILL OUT SHOE TRACK AND RAT HOLE. •-FROM 8855'TO 8960'. -310 GPM;1550 PSI ON BOTTOM,1430 PSI OFF BOTTOM. -35 RPM;4.5K FT-LBS TORQUE ON BOTTOM, 3K FT-LBS OFF BOTTOM. -UP WEIGHT=180K LBS;DOWN WEIGHT= 157K LBS -ROTATING WEIGHT=170K LBS. -WEIGHT ON BIT=9K LBS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 40 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 DRILL P INTI DRILL 20'OF NEW 6-1/8"PRODUCTION HOLE. -FROM 8960'TO 8980'. -310 GPM;1550 PSI ON BOTTOM,1430 PSI OFF BOTTOM. 35 RPM;4.5K FT-LBS TORQUE ON BOTTOM, 3K FT-LBS OFF BOTTOM. -UP WEIGHT=180K LBS;DOWN WEIGHT= 157K LBS -ROTATING WEIGHT=170K LBS. WEIGHT ON BIT=10K LBS. ART=0.08 HR;AST=0.0 HR;ADT=0.08 HR 22:00 - 00:00 2.00 DRILL P INTI CIRCULATE TO CLEAN WELL FOR FIT. -CIRCULATE 455 BLS;315 GPM AND 1550 PSI. REAM SHOE 3 TIMES TO CLEAN UP. -35 RPM;4K FT-LBS TORQUE. -UP WEIGHT=180K LBS;DOWN WEIGHT =160K LBS -ROTATING WEIGHT=160K LBS. **OBSERVED SHALE AT SHAKERS. GEO SAMPLES INDICATED KINGAK SHALE, CEMENT,AND SHOE TRACK MATERIALS** 3/20/2013 00:00 - 01:00 1.00 DRILL P INTI DRILL 5'ADDITIONAL OF NEW 6-1/8" PRODUCTION HOLE. -FROM 8980'TO 8985'. -315 GPM;1550 PSI ON BOTTOM,1430 PSI OFF BOTTOM. -35 RPM;4.5K FT-LBS TORQUE ON BOTTOM, 3K FT-LBS OFF BOTTOM. -UP WEIGHT=180K LBS;DOWN WEIGHT= 157K LBS -ROTATING WEIGHT=170K LBS. -WEIGHT ON BIT=10K LBS. 01:00 - 02:30 1.50 DRILL P INTI CIRCULATE THE WELL CLEAN. -315 GPM AND 1550 PSI. **GEO SAMPLES AT BOTTOMS UP INDICATE KINGAK SHALE AND CEMENT RETURNS. ** 02:30 - 04:00 1.50 DRILL P INTI PERFORM A FIT TO 9.8 PPG EMW. -PICK UP INSIDE SHOE AND SHUT DOWN PUMPS. -MONITOR WELL FOR 10 MIN. -RIG UP CHART RECORDER AND STRAP PITS. -FLUSH KILL LINE AND CLOSE UPPER PIPE RAMS. -PRE JOB SAFETY MEETING WITH RIG CREW. -PERFORM A FIT TO 9.8 PPG EMW. -590 PSI WITH 8.5 PPG MUD. -12 STROKES TO PRESSURE UP AT 0.1004 BBL/STK. -HELD FOR 10 MIN. -GOOD TEST:CONFIRMED WITH ODE. -PUMPED 1.2 BBLS AND BLED BACK 1.2 BBLS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 41 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud DaterTime:2/5/1980 12:00:00AM ,Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWN: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date : From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:00 2.00 DRILL P PROD1 'CONTINUE DRILLING 6-1/8"PRODUCTION HOLE. -FROM 8985'TO 9027'. -313 GPM;1650 PSI ON BOTTOM,1520 PSI OFF BOTTOM. -60 RPM;2.5K FT-LBS TORQUE ON BOTTOM, 1.8K FT-LBS OFF BOTTOM. -UP WEIGHT=181K LBS;DOWN WEIGHT= 158K LBS -ROTATING WEIGHT=170K LBS. -WEIGHT ON BIT=12K LBS. -ECD=9.OPPG AST=1.4 HR;ART=0.5 HR;ADT=1.9 HR. "DISCUSS PLAN FORWARD WITH WTL,N.S. SUPERINTENDENT AND ODE.** 06:00 - 08:00 2.00 DRILL P PROD1 CONTINUE DRILLING 6-18"PRODUCTION HOLE. -FROM 9027'TO 9071'. -313 GPM;1650 PSI ON BOTTOM,1520 PSI OFF BOTTOM. -60 RPM;2.5K FT-LBS TORQUE ON BOTTOM, 1.8K FT-LBS OFF BOTTOM. -UP WEIGHT=181K LBS;DOWN WEIGHT= 156K LBS -ROTATING WEIGHT=170K LBS. -WEIGHT ON BIT=10K LBS. I-ECD=9.0 PPG FROM 06:00 TO 08:00: - -AST=1.7 HR;ART=0.3 HR;ADT=2.0 HR. DRILLING HOURS FOR THE DAY: -AST=3.1 HR;ART=0.8HR;ADT=3.9HR. 08:00 - 10:30 2.50 DRILL N DPRB 9,071.00 PROD1 PULL OUT OF HOLE,RACK BACK ONE STAND AND PULL INTO SHOE. -MONITOR WELL FOR 10 MIN. -WELL STATIC. -CIRCULATE AND WAIT ON ORDERS. -DECISION MADE TO PULL OUT OF THE HOLE AND RUN A SHORT LINER. 10:30 - 18:30 8.00 DRILL N DPRB 9,071.00 PROD1 PULL OUT OF THE HOLE STANDING BACK 4" HT-38 DRILL PIPE. -FROM 9071'TO 942'. -UP WEIGHT=60K LBS;DOWN WEIGHT= 60K LBS -MONITOR WELL FOR 10 MIN -WELL STATIC. 18:30 - 19:00 0.50 DRILL N DPRB 9,071.00 PROD1 RIG UP TO LAY DOWN BHA. -PRE JOB SAFETY MEETING. -MONITOR WELL 10 MIN. -WELL STATIC. -RIG DOWN PS-21 SLIPS. 19:00 - 21:00 2.00 DRILL N DPRB 9,071.00 PROD1 LAY DOWN 6-1/8"DRILLING BHA. -FROM 942'TO 160'. -LAY DOWN 4"HEAVY WEIGHT DRILL PIPE -LAY DOWN JARS AND DRILL COLLARS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 42 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 I Spud DateTme:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. I UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) _ Date From-To Hrs Task Code NPT NPT Depth !, Phase Description of Operations 1_. (hr) (usft) 21:00 - 23:00 2.00 DRILL N DPRB 9,071.00 PROD1 HANDLE RADIOACTIVE SOURCE IN BHA. -PRE JOB SAFETY MEETING. -REMOVE AND SECURE SOURCE. -LAY DOWN DRILL COLLAR. -DOWN LOAD INFORMATION FROM MWD TOOLS. -PREP PIPE SHED FOR LINER. 23:00 - 00:00 1.00 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO LAY DOWN 6-1/8"DRILLING BHA. -FROM160'TO73'. -BREAK BIT AND LAY DOWN MWD TOOLS. 3/21/2013 100:00 - 01:30 1.50 DRILL N DPRB 9,071.00, 1- PROD1 CONTINUE TO LAY DOWN 6-1/8"DRILLING BHA. -PRE JOB SAFETY MEETING. -LAY DOWN MUD MOTOR. -CLEAR RIG FLOOR. -MONITOR WELL FOR 10 MIN. -WELL STATIC. 01:30 - 03:00 1.50 BOPSUR N DPRB '9,071.00 PROD1 RIG UP TO TEST BOPE. -PRE JOB SAFETY MEETING. -RIG UP TO TEST WITH 4"TEST JOINT. -GREASE CHOKE MANIFOLD VALVES. -PULL WEAR RING AND INSTALL TEST PLUG. 03:00 - 11:30 8.50-- BOPSUR N DPRB 9,071.00 PROD1 TEST BOPE 250/3500 PSI FOR 5 CHARTED MIN. -PRE JOB SAFETY MEETING ON PRESSURE TESTING. -TEST UPPER AND LOWER VBRS WITH 4" AND 4-1/2"TEST JOINTS. -TEST CHOKE MANIFOLD VALVES,MANUAL AND HCR VALVES. -TEST SUPER CHOKE"A"AND MANUAL"B". -TEST FOSV AND DART VALVE. -TEST UPPER AND LOWER IBOP VALVES. -TEST ANNULAR PREVENTER WITH 4"TEST JOINT. -TEST BLIND/SHEAR RAMS. -FUNCTION TEST ALL BOP COMPONENTS FROM BOTH CONTROL PANELS. -PERFORM ACCUMULATOR DRAW DOWN TEST; -ELECTRIC PUMP ON=2600 PSI, OFF=3000 PSI. -AIR PUMPS ON=2200 PSI;OFF=2850 IPS!. -19 SECONDS TO 200 PSI;82 SECONDS TO FULL PRESSURE. -14 NITROGEN BOTTLES AT 2100 PSI AVERAGE. •"AOGCC INSPECTOR,CHUCK SCHEVE, WAIVED TEST WITNESS;17:15 HRS ON 3-20-13.** 11:30 - 12:30 1.00 BOPSUR N DPRB 9,071.00 PROD1 RIG DOWN BOPE TEST EQUIMENT. -PULL TEST PLUG. -CLEAN AND CLEAR RIG FLOOR. 12:30 - 13:30 1.00 WHSUR N DPRB 9,071.00 PROD1 INSTALL WEAR RING. -PRE JOB SAFETY MEETING. -MAKE UP RUNNING TOOL AND INSTALL WEAR RING. -LAY DOWN RUNNING TOOL. Printed 6/24/2013 1.20:07PM North America-ALASKA-BP Page 43 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. UVN: Active datum:F-13B plan P272 I81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 1 (hr) i (usft) 13:30 - 15:00 1.50 CASING N DPRB 9,071.00 PROD1 j RIG UP TO RUN 4-1/2",12.6 LB/FT,HYDRIL 521 LINER. -FILL HOLE AND MONITOR WELL. -PRE JOB SAFETY MEETING WITH DOYON CASING CREW. -MOBILIZE LINER HANDLING TOOLS TO RIG FLOOR. -RIG UP FILL UP LINE ON RIG FLOOR. 15:00 - 16:00 1.00 CASING N DPRB 9,071.00 PROD1 MAKE UP AND CHECK 4-1/2",12.6 LB/FT, HYDRIL 521 LINER FLOAT EQUIPMENT. -BAKER LOCK FIRST 4 CONNECTIONS ON FLOAT EQUIPMENT -FILL AND CHECK FLOAT EQUIPMENT. GOOD. 16:00 - 17:30 1.50 CASING N DPRB 9,071.00 PROD1 RUN 4-1/2",12.6 LB/FT,HYDRIL 521 LINER IN HOLE -TO 446'. UP WEIGHT=45K DOWN WEIGHT=45K. -TORQUE ALL CONNECTIONS TO 6800 FT-LBS. **CONFERENCE CALL WTH ANCHORAGE PERSONNEL TO DISCUSS CONTINGENCY PLANS FOR RUNNING AND CEMENTING 4-1/2" LINER 16:00 TO 18:00** 17:30 - 18:00 0.50 CASING N DPRB 9,071.00 PROD1 CHANGE TOP DRIVE ELEVATORS. -REMOVE 4"ELEVATORS -INSTALL 4"BX ELEVATORS 18:00 - 21:00 3.00 CASING N DPRB 9,071.00 • PROD1 MAKE UP AND RUN IN LINER HANGER -FROM 446'10 494'. -TORQUE 4-1/2",12.6 LB/FT,HYDRIL 521HANGER CONNECTIONS TO 6800 FT-LBS. -VERIFIED 7 SHEAR SCREWS ON LINER HANGER:2650 PSI SHEAR. -VERIFIED 5 SHEAR SCREWS ON LINER TOP PACKER:24,500 LBS TO SET. -FILL TOP OF TIE BACK EXTENSION WITH PALMIX GEL. -CIRCULATE LINER VOLUME -147 GPM AND 100 PSI. 21:00 - 00:00 3.00 CASING N DPRB 9,071.00 PROD1 RUN 4-1/2",12.6 LB/FT,HYDRIL 521 LINER IN THE HOLE ON HT-38 DRILL PIPE. -FROM 494'TO 2762' UP WEIGHT 75K,DOWN WEIGHT 75K. -FILL PIPE EVERY 10 STANDS. • 3/22/2013 00:00 - 08:00 8.00 CASING N DPRB 9,071.00 PROD1 CONTINUE TO RUN 4-1/2",12.6 LB/FT,HYDRIL j 521 LINER IN THE HOLE ON 4"HT-38 DRILL PIPE. FROM 2762'TO 8834'. -FILLING PIPE EVERY 10 STANDS. -2 BBLS PER HOUR LOSSES. -UP WEIGHT=164K,DOWN WEIGHT=153K 08:00 - 09:00 1.00 CASING N DPRB 9,071.00 PROD1 DRILL PIPE SPACE OUT FOR LANDING LINER -LAY DOWN 2 JOINTS HT-38 DP. '-PICK UP 10'PUP JOINT. -CIRCULATE 1.5X LINER AND DRILL PIPE VOLUME Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 44 of 75 r Operation$ummo Repot Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release.4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum.F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 17:30 ' 8.50 CASING N DPRB 9,071.00 PROD1 REAM 4"HT-38 DRILL PIPE WITH 4-1/2",12.6 LB/FT,HYDRIL 521 LINER ASSEMBLY -ATTEMPT TO RUN IN HOLE WITH NO ROTATION OR PUMPS AND TOOK WEIGHT AT 8964'. -REAM DOWN WITH UP TO 10K WOB. -211 GPM;550 PSI ON BOTTOM,450 PSI OFF BOTTOM. -30 RPM;TORQUE ON BOTTOM 2000, TORQUE OFF BOTTOM 1500. UP WEIGHT 160K LBS,DOWN WEIGHT 152K LBS. -ROTATING WEIGHT 148K. VARIED PARAMETERS -FROM 2K WOB TO 10K WOB. -FROM 84 GPM TO 252 GPM. -FROM 20 RPM TO 30 RPM. 17:30 - 18:00 0.50 CASING N DPRB 9,071.00 PROD1 PULL INTO SHOE AT 8958'AND MONITOR WELL,STATIC. PUMP DRY JOB. 18:00 - 00:00 6.00 CASING N DPRB 9,071.00 PROD1 TRIP OUT OF THE HOLE WITH 4"HT-38 DRILL PIPE WITH 4-1/2",12.6 LB/FT,HYDRIL 521 LINER ASSEMBLY -FROM 8958'TO 1763'. -UP WEIGHT 75K LBS,DOWN WEIGHT 75K LBS D-1 DRILL -AFTER ACTION REVIEW WITH CREW -WELL SECURE 2 MIN 20 SEC. 3/23/2013 00:00 - 01:00 1.00 CASING N DPRB 9,071.00 PROD1 CONTINUE TRIP OUT OF HOLE WITH 4"HT-38 DRILL PIPE WITH 4-1/2",12.6 LB/FT,HYDRIL 1 521 LINER ASSEMBLY -FROM 1763'TO 1344'. -UP WEIGHT 65K LBS,DOWN WEIGHT 65K LBS 01:00 - 01:30 0.50 CASING N DPRB 9,071.00 PROD1 D-1 DRILL. -CREW RESPONSE TIME 3 MIN 15 SEC. -AFTER ACTION REVIEW WITH CREW. 01:30 - 02:30 1.00 CASING N DPRB 9,071.00 PROD1 CONTINUE TRIP OUT OF HOLE WITH 4"HT-38 DRILL PIPE WITH 4-1/2",12.6 LB/FT,HYDRIL 521 LINER ASSEMBLY -FROM 1344'TO LINER RUNNING TOOL. 02:30 - 03:30 1.00 CASING N DPRB 9,071.00 PROD1 LAY DOWN LINER RUNNING TOOL. -INSPECT LINER RUNNING TOOL. -LAY DOWN LINER RUNNING TOOL. 03.30 - 04.00 0.50 FISH N DPRB 9,071.00 PROD1 SERVICE RIG -SERVICE TOP DRIVE AND TRAVELING BLOCKS,CROWN SECTION,AND DRAWWORKS. 04:00 - 11:30 7.50 FISH N DPRB 9,071.00 PROD1 WAITING ON ORDERS FROM TOWN. MAINTENANCE DRAW WORKS LUBE OIL PUMP. -CLEAR SNOW AROUND RIG AND PREP FOR UPCOMING RIG MOVE. -MOBILIZE BAKER OIL TOOLS FISHING D-1 DRILL -CREW RESPONSE TIME 3 MIN 29 SEC. -AFTER ACTION REVIEW WITH CREW Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 45 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 15:00 3.50 FISH N DPRB 9,071.00 PROD1 MAKE UP BAKER OIL TOOLS FISHING ASSEMBLY -PRE-JOB SAFETY MEETING -MAKE UP SPEAR ASSEMBLY AND COLLARS -TO 326'. 15:00 - 00:00 9.00 FISH N DPRB 9,071.00 PROD1 TRIP IN 4"HT-38 DRILL PIPE WITH BOT FISHING ASSEMBLY -FROM 326'TO 7500'. -UP WEIGHT 146K,DOWN WEIGHT 142K. •-FILL PIPE EVERY 20 STANDS. 3/24/2013 00:00 - 00:30 0.50 FISH N DPRB 9,071.00 PROD1 RUN IN THE HOLE WITH LINER FISHING ASSEMBLY ON 4"HT-38 DRILL PIPE OUT OF THE DERRICK. -FROM 7700'TO 7890'. -UP WEIGHT 157K;DOWN WEIGHT 148K. -FILL PIPE EVERY 20 STANDS. 00:30 - 01:00 0.50 FISH N DPRB 9,071.00 PROD1 D-1 WELL CONTROL DRILL(KICK WHILE TRIPPING) -AFTER ACTION REVIEW WITH CREW. -DISCUSSED ROLES AND RESPONSIBILITIES. -DISCUSSION ON PROPER RESONSE WHEN DRILL PIPE IS HANGING IN IDL. GOOD RESPONSE/FEEDBACK FROM CREW. 01:00 - 02:00 1.00 FISH N DPRB ' 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH LINER FISHING ASSEMBLY. -FROM 7890'TO 8454'. UP WEIGHT 162K;DOWN WEIGHT 151K. FILL PIPE EVERY 20 STANDS. FILL PIPE AT 8454' -PRESSURE UP TO 600 PSI AND SHUT DOWN. -HELD PRESSURE UNTIL BLEED OF AT MUD MANIFOLD. -SPEAR ASSEMBLY APPEARS TO BE PLUGGED OFF. 02:00 - 04:00 2.00 FISH N DPRB 9,071.00 PROD1 ATTEMPT TO CLEAR BLOCKAGE AND BREAK CIRCULATION AT 8454'. -ATTEMPT TO CLEAR BLOCKAGE. -UTILIZE PRESSURE AND BLEED CYCLES WITH PIPE MOVEMENT. -WORK PRESSURES UP TO 1500 PSI. -STAND BACK 1 STAND TO GAIN ROOM TO WORK PIPE. -CONTINUE WITH PRESSURE AND BLEED CYCLES WITH PIPE MOVEMENT. -NO CHANGE. -CALL SUPERINTENDENT AND WTL. -CONTINUE WITH PRESSURE AND BLEED CYCLES WITH PIPE MOVEMENT. -WORK PRESSURE UP TO MAXIMUM OF 2000 PSI. -NO CHANGE Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 46 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 IX3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 i 81.55usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 05:00 1.00 FISH N DPRB 9,071.00 I PROD1 PREPARE TO PULL OUT OF THE HOLE WITH LINER FISHING ASSEMBLY. -MONITOR WELL FOR 10 MIN. -WELL STATIC. -DROP PUMP-OUT SUB DART. -PULL ONE STAND WET AND RACK BACK IN DERRICK. -PRESSURE UP TO 3700 PSI AND HOLD TO OPEN PUMP-OUT SUB. -PUMP-OUT SUB PINNED TO OPEN AT 2500 PSI. -PUMP-OUT OPENED AFTER 20 SEC. • -SUSPECT PRESSURE BLEW OBSTRUCTION CLEAR FROM SPEAR WHEN CIRCULATING SUB OPENED AT 3700 PSI. -VERIFY CIRCULATION. -PULL 3 STANDS WHILE BUILDING DRY JOB. -PUMP DRY JOB. 05:00 - 13:30 8.50 FISH N DPRB 9,071.00 PROD1 PULL OUT OF THE HOLE WITH LINER FISHING ASSEMBLY. FROM 8454'TO 326'. MONITOR WELL FOR 10 MIN. -WELL STATIC. 13:30 - 15:00 1.50 FISH N DPRB 9,071.00 PROD1 STAND BACK DRILL COLLARS AND INSPECT LINER FISHING ASSEMBLY. -NO VISIBLE SIGNS OF BLOCKAGE IN SPEAR ASSEMBLY. -REDRESS PUMP-OUT SUB. 15:00 - 15:30 0.50 FISH N - DPRB 9,071.00 PROD1 !MAKE UP AND RUN IN THE HOLE WITH LINER i FISHING ASSEMBLY. 15:30 - 16:00 0.50 FISH 'N DPRB 9,071.00 PROD1 D-1 WELL CONTROL DRILL(KICK WHILE TRIPPING) -CREW RESPONSE TIME=2 MIN 35 SEC. -AFTER ACTION REVIEW WITH CREW. I -DISCUSSED ROLES AND •RESPONSIBILITIES. 16:00 - 18:30 2.50 FISH N DPRB 9,071.00 PROD1 RUN IN THE HOLE VITH LINER FISHING ASSEMBLY ON 4"HT-38 DRILL PIPE. -INSTALL PS-21 SLIPS. -FROM 326'TO 2195'. -FILLING PIPE EVERY 10 STANDS. 18:30 19:00 0.50 FISH N DPRB 9,071.00 PROD1 FIRE DRILL ON THE BOP DECK WITH A D-1 WELL CONTROL DRILL(KICK WHILE TRIPPING) -CREW RESPONSE TIME=1 MIN 35 SEC. -AFTER ACTION REVIEW WITH CREW. -DISCUSSED ROLES AND RESPONSIBILITIES. -DRILLER SIMULATED CLOSING ANNULAR PREVENTER. -DISCUSSED USING UPPER PIPE RAMS AS OPPOSED TO ANNULAR PREVENTER. 19:00 - 22:00 3.00 FISH N DPRB 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH LINER FISHING ASSEMBLY. -FROM 2195'TO 5146'. '-UP WEIGHT=115K LBS;DOWN WEIGHT= 115K LBS. -FILL PIPE AND BREAK CIRCULATION EVERY 10 STANDS. -STAGE UP TO 252 GPM AND 730 PSI. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 47 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. !UWI: Active datum:F-138 plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 FISH N DPRB 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH LINER FISHING ASSEMBLY. -FROM 5146'TO 6471'. -UP WEIGHT=133K LBS;DOWN WEIGHT= 133K LBS. -FILL PIPE AND BREAK CIRCULATION EVERY 10 STANDS. -STAGE UP TO 378 GPM AND 1570 PSI. 3/25/2013 00:00 - 02:00 2.00 FISH N DPRB 9,071.00:: PROD1 CONTINUE TO RUN IN THE HOLE WITH LINER FISHING ASSEMBLY. -FROM 6471'TO 7319'. -UP WEIGHT=145K LBS;DOWN WEIGHT= 144K LBS. -FILL PIPE AND BREAK CIRCULATION EVERY 10 STANDS. -STAGE UP TO 284 GPM 1050 PSI. D-1 WELL CONTROL DRILL(KICK WHILE TRIPPING) -AFTER ACTION REVIEW WITH CREW. -DISCUSSED ROLES AND RESPONSIBILITIES. -DISCUSSION ON PROPER RESPONSE WHEN DRILL PIPE IS HANGING IN IDL. _ -DISCUSSION ON PVT ALARM SETTINGS. 02:00 - 02:30 0.51 + FISH N DPRB 9,071.00 -PROD1 SERVICE TOP DRIVE,DRAWWORKS,AND 1 ST-80. 02:30 - 04:00 1.50 FISH N I RREP 7,319.00 i PROD1 VFD ON TOP DRIVE DISENGAGED. -TROUBLE SHOOT TOP DRIVE. -CALL OUT RIG ELECTRICIAN. -REPAIR BROKEN ENCODER WIRE. 04:00 - 05:00 1.00 FISH N DPRB 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH LINER FISHING ASSEMBLY. I -FROM 7319'TO 7875'. 05:00 - 06:30 1.50 FISH N DPRB 9,071.00 PROD1 WASH DOWN WITH LINER FISHING ASSEMBLY. -FROM 7875'TO 8427'. -230 GPM,880 PSI. -UPWT168K,DNWT157K. 06:30 - 07:00 0.50 FISH N DPRB 9,071.00 • PROD1 CIRCULATE TO CLEAN UP TOP OF FISH. -CIRCULATE DOWN TO 8481'. -336 GPM,1480 PSI. 07:00 - 09:30 2.50 FISH N DPRB 9,071.00 PROW ENTER TOP OF FISH AT 8507'AT 2 BPM, FULLY ENGAGE FISH AT 8516'. -ATTEMPT TO PULL FREE,STAGE UP IN 5K INCREMENTS. -WORK PIPE UP AND DOWN TO 235K,65K 'OVERPULL TO START MOVING THE FISH UP HOLE. -PULLED TIGHT AT 8486',CIRCULATE TO CLEAN HOLE. -STAGE PUMPS UP TO 5 BPM,820 PSI. - 09:30 - 12:00 2.50 FISH N DPRB 9,071.00 PROD1 PUMP OUT OF THE HOLE FROM 8486'TO 7966'. -6 BPM,1090 PSI. 12:00 - 13:00 1.00 I FISH N DPRB 9,071.00 PROD1 TRIP OUT OF THE HOLE WITH FISH -FROM 7966'TO 6559'. -UP WEIGHT=155K,DOWN WEIGHT=155K. MONITOR WELL. STATIC. -PUMP 15 BBL DRY JOB. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP 48 of 75 Operation Summary'Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI. Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 18:00 5.00 FISH N DPRB 9,071.00 PROD1 TRIP OUT OF THE HOLE WITH FISH -FROM 6559'TO 326'. -UP WEIGHT=52K,DOWN WEIGHT=52K. CONTINUOUS IMPROVEMENT MEETING HELD WITH RIG LEADERSHIP TEAM. 18:00 - 19:30 1.50 FISH N DPRB 9,071.00 PROD1 PULL LINER FISHING ASSEMBLY OUT OF THE HOLE -MONITOR WELL. STATIC. -FROM 326'TO FISH. 19:30 - 21:00 1.50 FISH N DPRB 9,071.00 PROD1 RIG UP LINER HANDLING EQUIPMENT. -RIG UP POWER TONGS. -BREAK OUT AND LAY DOWN HANGER ASSEMBLY -RIG UP LINER ELEVATORS. RIG UP WELDERS EQUIPMENT. 21:00 - 23:30 2.50 FISH N DPRB 9,071.00 PROD1 LAY DOWN 4-1/2",12.6 LB/FT,HYDRIL 521 LINER -LAY DOWN 7 JOINTS OF LINER. -STAND BACK 4 JOINTS,PUP JOINTS, AND SHOE TRACK IN DERRICK -HEAT BAKER LOCK CONNECTIONS TO BREAK. 23:30 - 00:00 0.50 FISH N DPRB 9,071.00 PROD1 RIG DOWN LINER HANDLING EQUIPMENT. -RIG DOWN POWER TONGS. -CHANGE OUT TO DRILL PIPE ELEVATORS. -RIG DOWN WELDERS EQUIPMENT. 3/26/2013 00:00 - 00:30 0.50 DRILL N DPRB 9,071.00 PROD1 CONTINUE RIGGING DOWN LINER HANDLING EQUIPMENT. RIG DOWN POWER TONGS. -CHANGE OUT TO DRILL PIPE ELEVATORS. -RIG DOWN WELDERS EQUIPMENT. 00:30 - 01.00 0.50 DRILL N DPRB I 9,071.00 PROD1 MOBILIZE BHA COMPONENTS TO RIG FLOOR FOR MAKING UP CLEANOUT ASSEMBLY. 01.00 - 05:00 4.00 DRILL N DPRB 9,071.00 PROD1 PICK UP AND MAKE UP CLEANOUT ASSEMBLY -PRE-JOB SAFETY MEETING. -MAKE UP 6 1/8"INSERT BIT. REMOVED NOZZLES. -FROM SURFACE TO 578'. 05:00 - 12:00 7.00 DRILL N DPRB 9,071.00 PROD1 RUN IN THE HOLE WITH CLEAN-OUT ASSEMBLY ON 4"HT-38 DRILL PIPE. -FROM 578'TO 6250'. -UP WEIGHT=130K LBS,DOWN WEIGHT= 124K LBS. 12:00 - 14:30 2.50 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH CLEAN-OUT ASSEMBLY ON 4"HT-38 DRILL PIPE. -FROM 6250'TO 8890'. -UP WEIGHT=173K LBS,DOWN WEIGHT= 155K LBS. 14:30 - 15:00 0.50 DRILL N DPRB 9,071.00 PROD1 WASH DOWN WITH CLEAN-OUT ASSEMBLY. -FROM 8890'TO 8958'. -PUMPS OFF: -UP WEIGHT=179K LBS;DOWN WEIGHT =156K LBS. -PUMPS ON: -UP WEIGHT=173K LBS;DOWN WEIGHT =155K LBS. -250 GPM AND 460 PSI. -80 RPM;ROTATING WEIGHT=166K LBS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 49 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 19:30 4.50 DRILL N DPRB 9,071.00 PROD1 DISPLACE THE WELL FROM 8.5 PPG QUIKDRIL-N FLUID TO 11.0 PPG LSND. -MONITOR WELL FOR 10 MIN. -WELL STATIC. PUMP 20 BBL HIGH VIS SPACER AHEAD OF 11.0 PPG LSND. -DISPLACED WELL AT 240 GPM AND 866 PSI. -SHUT DOWN EVERY 250 BBLS TO OFF LOAD FLUID TO TRUCKS AND VERIFY BBL IN/BBL OUT. -LOST 10 BBLS 11.0 PPG LSND TO HOLE DURING DISPLACEMENT. **LOWER END OF CUTTINGS CHUTE FROZE UP. LEAKED 1 GALLON LSND TO PAD. REPORTED TO#5700. TRACTION REPORT: 2013-IR-4384563** 19:30 - 22:00 2.50 DRILL N DPRB 9,071.00 PROD1 WASH AND REAM TO CLEAN OUT 6-1/8" HOLE. -FROM 8958'TO 8990'. -WASH AND REAM 5'-10'INCREMENTS. -300 GPM AND 1065 PSI ON BOTTOM,1008 PSI OFF BOTTOM. -UP WEIGHT=182K LBS;DOWN WEIGHT= •148K LBS. -80 RPM;ROTATING WEIGHT=162K LBS. -TORQUE ON BOTTOM=5.6K FT-LBS;OFF BOTTOM=4K FT-LBS. -PACKED OFF AT 8974'. -WORKED PIPE WITH 400 PSI TRAPPED PRESSURE. -PULLED 30K OVER. -RE-GAINED CIRCULATION. -CONTINUE TO WORK PIPE FREE WITH 35K LBS OVER. -PACKED OFF AT 8990'. -RE-GAINED CIRCULATION. 22:00 - 23:30 1.50 DRILL N DPRB 9,071.00 PROD1 WORK PIPE FREE IN TIGHT HOLE. -WORK FREE FROM 8990'BACK TO 7"SHOE AT 8958'. -WORKED PIPE WITH AND WITHOUT TRAPPED TORQUE. -UP TO 7.3K FT-LBS. -WORKED PIPE WITH AND WITHOUT PUMPS. -STAGED UP TO 142 GPM AND 555 PSI. -PULLED UP TO 50K LBS OVER. -FIRED JARS 4 TIMES WITH UP TO 40 K LBS OVER. 23:30 - 00:00 0.50 DRILL N DPRB 9,071.00 PROD1 CLEAN UP WELLBORE. -CIRCULATE WELL WITH RECIPROCATION AND ROTATION. -30'STROKES;FROM 8958'TO 8928'. -300 GPM AND 972 PSI. 3/27/2013 00:00 - 00:30 0.50 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO CLEAN UP WELLBORE. CIRCULATE WELL WITH RECIPROCATION AND ROTATION. -30'STROKES;FROM 8958'TO 8928'. -300 GPM AND 972 PSI. -PERFORM PRE-TOUR CHECKS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 50 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 02:30 2.00 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO WASH AND REAM TO CLEAN OUT 6-1/8"HOLE. -FROM 8958'TO 8990'. -WASH AND REAM 5'-10'INCREMENTS. -300 GPM AND 1065 PSI ON BOTTOM,1008 PSI OFF BOTTOM. -UP WEIGHT=182K LBS;DOWN WEIGHT= 148K LBS. -80 RPM;ROTATING WEIGHT=162K LBS. -TORQUE ON BOTTOM=5.6K FT-LBS;OFF BOTTOM=4K FT-LBS. 02:30 - 08:30 6.00 DRILL N DPRB 9,071.00 PROD1 •ENCOUNTERED HARD SPOT AT 8990'. VARY PARAMETERS TO TRY AND WORK THROUGH. -0 TO 100 RPM. 0 TO 30K LBS WEIGHT ON BIT. -200 TO 300 GPM AND 1094 PSI ON BOTTOM. 5.0K TO 6.5K FT-LBS TORQUE ON BOTTOM. -PUMP 35 BBL MEDIUM NUT PLUG SWEEP. -300 GPM AND 1100 PSI. NO CHANGE. DISCUSS OPTIONS WITH ANCHORAGE TEAM. 08:30 - 09:30 1.00 DRILL N DPRB 9,071.00 PROD1 PICK UP INSIDE 7"SHOE AT 8958'AND CHECK DRILL PIPE FLOAT. • -LINE UP TO REVERSE CIRCULATE. -FILL KILL LINE. -CLOSE ANNULAR PREVENTER. -PUMP 2.5 BBLS AND PRESSURE UP ON ANNULUS TO 250 PSI. -PRESSURE BLEEDING OFF SLOWLY -PORTED FLOAT RESTRICTING FLOW. -BLOW DOWN CHOKE MANIFOLD. 09:30 - 12:00 2.50 DRILL N DPRB 9,071.00 PROD1 PUMP 35 BBL DISPERSANT/LUBE/NUT PLUG SWEEP. -450 GPM AND 2000 PSI. -2 LB/BBL DESCO;6%DRIL-N-SLIDE;10 LB/BBL MEDIUM WALNUT. -UP WEIGHT=179K LB;DOWN WEIGHT= 165K LB. 12:00 - 13:00 1.00 DRILL N DPRB 9,071.00 PROD1 PUMP DRY JOB AND RIG UP TO PULL OUT OF THE HOLE WITH 6-1/8"CLEAN OUT ASSEMBLY. -MONITOR WELL FOR 10 MIN. -WELL STATIC. -PUMP 20 BBL 13 PPG DRY JOB. -BLOW DOWN TOP DRIVE AND RIG UP TO PULL OUT OF THE HOLE. -UP WEIGHT=178K LBS;DOWN WEIGHT- 145KLBS. 13:00 - 18:30 5.50 DRILL N DPRB 9,071.00 PROD1 PULL OUT OF THE HOLE WITH 6-1/8"CLEAN OUT ASSEMBLY,STANDING BACK 4"HT-38 DRILL PIPE. -FROM 8958'TO 578'. -UP WEIGHT=55K LBS;DOWN WEIGHT= 55K LBS. -PULL PS-21 SLIPS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 51 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 20:00 1.50 DRILL N DPRB 9,071.00 PROD1 PULL AND LAY DOWN 6-1/8"CLEAN OUT ASSEMBLY. -STAND BACK 3 STANDS OF 4"HWDP AND JARS. STAND BACK 2 STANDS OF DRILL COLLARS. **BIT AND BIT SUB LEFT IN HOLE. OAL= 2.94'. PIN END OF FLOAT SUB TWISTED OFF (PHOTOS ATTACHED)FLOAT FROM INSIDE FLOAT SUB MISSING. ** -CALL ANCHORAGE TEAM AND DISCUSS PLAN FORWARD. 20:00 - 20:30 0.50 DRILL N DPRB 9,071.00 PROD1 SERVICE TOP DRIVE,DRAWWORKSAND CROWN. 20:30 - 21:30 1.00 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO LAY DOWN 6-1/8"CLEAN OUT ASSEMBLY. -LAY DOWN FLOAT SUB,XO,AND CIRCULATING SUB. -LAY DOWN 2 DRILL COLLARS. 21:30 - 00-00 2.50 BOPSUR N DPRB 9,071.00 PROD1 RIG UP TO TEST BOPE 250/3500 PSI. ,-DRAIN BOP STACK. -RIG UP TEST EQUIPMENT. PULL WEAR RING AND INSTALL TEST PLUG. -GREASE CHOKE MANIFOLD. -MAKE UP 4"TEST JOINT. -FILL LINES AND CHECK SYSTEM FOR LEAKS. "24 HOUR NOTICE PROVIDED AT 16:20 HRS ON 3/26/2013** "AOGCC INSPECTOR,LOU GRIMALDI, WAIVED WITNESS AT 17:50 HRS ON 3/27/2013 Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 52 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor PARKER DRILLING CO. UWI: Active datum:F-138 plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/28/2013 00:00 - 05:30 5.50 BOPSUR N DPRB 9,071.00 PROD1 TEST BOPE 250/3500 PSI FOR 5 CHARTED MIN. -PRE JOB SAFETY MEETING ON PRESSURE TESTING. TEST UPPER AND LOWER VBRS WITH 4" TEST JOINT. -TEST CHOKE MANIFOLD VALVES,MANUAL AND HCR VALVES. -TEST SUPER CHOKE"A"AND MANUAL"B". -TEST FOSV AND DART VALVE. -TEST UPPER AND LOWER IBOP VALVES. -TEST ANNULAR PREVENTER WITH 4"TEST JOINT. -TEST BLIND/SHEAR RAMS. FUNCTION TEST ALL BOP COMPONENTS FROM BOTH CONTROL PANELS. -PERFORM ACCUMULATOR DRAW DOWN TEST; -ELECTRIC PUMP ON=2600 PSI, OFF=3000 PSI. -AIR PUMPS ON=2200 PSI;OFF=2850 PSI. -29 SECONDS TO 200 PSI;110 SECONDS TO FULL PRESSURE. '-14 NITROGEN BOTTLES AT 2052 PSI AVERAGE. 24 HOUR NOTICE FOR BOP TEST GIVEN AT 18:20 ON 3/26/2013. AOGCC INSPECTOR,LOU GRIMALDI,WAIVED WITNESS AT 17:50 ON 3/27/2013. 05:30 - 06:30 1.00 BOPSUR N DPRB 9,071.00 PROD1 RIG DOWN BOPE TEST EQUIPMENT. -LAY DOWN 4"TEST JOINT. -RIG DOWN TEST EQUIPMENT. -BLOW DOWN CHOKE MANIFOLD. 06:30 - 07:30 1.00 WHSUR N DPRB 9,071.00 PROD1 INSTALL WEAR RING. -SUCK OUT BOP STACK. -PULL TEST PLUG. -INSTALL WEAR RING AND RUN IN LOCK DOWN SCREWS. 07:30 - 10:00 2.50 DRILL N DPRB 9,071.00 PROD1 SERVICE RIG. -SLIP AND CUT 70'OF DRILLING LINE. -INSPECT AND SERVICE DRAWWORKS. -SERVICE TOP DRIVE. 10:00 - 12:00 2.00 DRILL N DPRB 9,071.00 PROD1 PICK UP AND RUN IN THE HOLE WITH 7" MECHANICAL SET EZSV ON 4"HT-38 DRILL PIPE. -PRE JOB SAFETY MEETING WITH RIG CREW AND HALLIBURTON REPRESENTATIVE. -PICK UP AND MAKE UP EZSV BRIDGE PLUG. -RUN IN THE HOLE ON 4"DRILL PIPE TO 580'. UP WEIGHT=55K LBS;DOWN WEIGHT= 55K LBS. 12:00 - 13:30 1.50 DRILL N DPRB 9,071.00 PROD1 RE-SPOOL DRAWWORKS. -HUMPS IN DRILL LINE ON DRAWWORKS DISCOVERED. PRE JOB SAFETY MEETING. -RE-SPOOL DRAWWORKS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 53 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 19:30 6.00 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH 7" MECHANICAL SET EZSV ON 4"HT-38 DRILL PIPE. -FROM 580'TO 6804'. -UP WEIGHT=130K LBS;DOWN WEIGHT= 122K LBS. -INSTALL PS-21 SLIPS. -FILL PIPE EVERY 20 STANDS. '19:30 - 21:00 1.50 DRILL N DPRB 9,071.00 PROD1 WELL UNDER BALANCED,CIRCULATE 222 BBLS OF 11.0 PPG LSND. -105 GPM AND 238 PSI. -RATE RESTRICTED TO 105 GPM BY EZSV. 21:00 - 22:00 1.00 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH 7" MECHANICAL SET EZSV ON 4"HT-38 DRILL PIPE. -FROM 6804'TO 7465'. -UP WEIGHT=144K LBS;DOWN WEIGHT= 128K LBS. 22:00 - 23:30 1.50 DRILL N , DPRB 9,071.00 PROD1 WELL UNDER BALANCED,CIRCULATE 250 i BBLS OF 11.0PPG LSND. -105 GPM AND 250 PSI. -RATE RESTRICTED TO 105 GPM BY EZSV. 23:30 - 00:00 0.50 DRILL N DPRB 9,071-.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH 7" - MECHANICAL SET EZSV ON 4"HT-38 DRILL PIPE. -FROM 7465'TO 7951'. -UP WEIGHT=147K LBS;DOWN WEIGHT= _ I 131K LBS. 3/29/2013 00:00 - 01:30 1.50 DRILL N 'DPRB" --: 9,071.00 PROD1 CONTINUE TO RUN IN THE HOLE WITH 7" MECHANICAL SET EZSV ON 4"HT-38 DRILL PIPE. -FROM 7951'TO 8639'. -UP WEIGHT=163K LBS;DOWN WEIGHT= 142K LB. -WASH DOWN THE LAST 2 STANDS. -105 GPM AND 320 PSI. 01:30 - 02:00 0.50 DRILL N DPRB 9,071.00 PROD1 SET 7"EZSV AT 8639' -SET EZSV PER HALLIBURTON REPRESENTATIVE. -35 TURNS TO THE RIGHT. -PULL IN 10K LB INCREMENTS TO 50K LBS OVER AND SHEAR TO SET. -PICK UP 5'AND TURN 30 TURNS TO THE RIGHT TO SHIFT SLEEVE. -SET DOWN ON EZSV WITH 20K LBS TO CONFIRM SET. Printed 6/24/2013 1 20:07PM North America-ALASKA-BP Page 54 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 07:00 5.00 DRILL N DPRB 9,071.00 PROD1 CIRCULATE AND CONDITION THE MUD PRIOR TO PUMPING CEMENT. -CIRCULATE MUD TO AN EVEN 11.0 PPG IN AND OUT. -MUD WEIGHTS OUT VARIED BETWEEN 10.8+PPG AND 11.2-. -300 GPM AND 915 PSI. BUILD SODIUM BICARBONATE/CITRIC PILL. -OFFLOAD 11.0 PPG MUD TO VAC TRUCK FOR DISPLACEMENT. SIMOPS: -RIG UP SCHLUMBERGER CEMENTERS ON UTILITY MODULE SIDE. BATCH UP 30 BBL 12.5 PPG MUDPUSH. -RIG UP CEMENT HEAD ON RIG FLOOR. 07:00 - 09:00 2.00 CEMT N DPRB 9,071.00 PROD1 PUMP 500'CEMENT PLUG IN 7"LINER. -BLOW AIR THROUGH LINES TO CEMENTERS. PUMP 10 BBLS 12.5 PPG MUDPUSH. -PRESSURE TEST CEMENT LINE AND CHECK TRIPS. -250/4500 PSI. -PUMP 20 BBLS OF 12.5 PPG MUDPUSH. -4 BPM AND 350 PSI. -PUMP 19.2 BBLS,15.8 PPG CLASS G CEMENT AT4BPM -YIELD 1.16 CU FT/SX(88 SX) -PUMP 10 BBLS OF 12.5 PPG MUDPUSH. -4 BPM AND 53 PSI. UNDER DISPLACE BY 2 BBLS USING CEMENTERS -PUMP 70 BBLS 11.0 PPG LSND MUD. -4 BPM,43 PSI DID NOT RECIPROCATE PIPE DURING CEMENT JOB. CEMENT IN PLACE AT 10:00 HRS 09:00 - 10:00 1.00 CEMT N DPRB 9,071.00 PROD1 PULL UP OUT OF CEMENT AND LAY PLUG ON 7"EZSV. -BREAK OUT SINGLE WITH HEAD PIN. -PULL OUT OF THE HOLE FROM 8613'TO 7856'. -UP WEIGHT=162K LBS. -NO DOWNWARD TRAVEL WHILE LAYING PLUG. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 55 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 14:30 4.50 CEMT N DPRB 9,071.00 PROD1 CIRCULATE AND PUMP SWEEP TO CLEAN OUT DRILL PIPE. -DROP DRILL PIPE WIPER BALL. -PUMP 30 BBL CITRIC/BICARBONATE PILL. -210 GPM AND 900 PSI. -DROP SECOND DRILL PIPE WIPER BALL. -CHASE WITH 11.0 PPG LSND MUD -600 GPM AND 2600 PSI. -ROTATE AND RECIPROCATE WHILE PUMPING. PUMP A 30 BBL NUT PLUG SWEEP. -300 GPM AND 800 PSI. -UP WEIGHT=152K LBS;DOWN WEIGHT= 130K LBS. 14:30 - 16:00 1.50 DRILL N DPRB 9,071.00 PROD1 PULL OUT OF THE HOLE WITH THE EZSV SETTING TOOL,STANDING BACK 4"HT-38 DRILL PIPE. -FROM 7856'TO 6700'. -UP WEIGHT=145K LBS;DOWN WEIGHT= 122K LBS. 16:00 - 19:30 3.50 DRILL N DPRB 9,071.00 PROD1 CIRCULATE AND CONDITION MUD TO LOWER THE MUD WEIGHT TO 10.8 PPG PER NEW MUD PROGRAM FOR UPCOMING SIDETRACK. '-REDUCE MUD WEIGHT FROM 11.0 PPG TO 10.8 PPG. -350 GPM AND 945 PSI. -MONITOR WELL FOR 10 MIN. -WELL STATIC. 19:30 - 00:00 4.50 ' DRILL N DPRB 9,071.00 PROD1 CONTINUE TO PULL OUT OF THE HOLE WITH THE EZSV SETTING TOOL,STANDING BACK 4"HT-38 DRILL PIPE. -FROM 6700'TO 1100'. -UP WEIGHT=40K LBS;DOWN WEIGHT= 40K LBS. -REMOVE PS-21 SLIPS. 3/30/2013 00:00 - 01:30 1.50 DRILL N DPRB 9,071.00 PROD1 CONTINUE TO PULL OUT OF THE HOLE AND LAY DOWN EZSV SETTING TOOL,STANDING BACK 4"HT-38 DRILL PIPE. -FROM 1100'. -MONITOR WELL FOR 10 MIN. -WELL STATIC. 01:30 - 03:00 1.50 DRILL N DPRB 9,071.00 PROD1 PRESSURE TEST CEMENT PLUG IN 7"LINER. -250 PSI LOW FOR 5 CHARTED MIN. -GOOD TEST. -2500 PSI HIGH FOR 45 CHARTED MIN. -LOST 25 PSI IN THE FIRST 15 MIN. -LOST 25 PSI IN THE SECOND 15 MIN. -FAILED TO PASS BP TESTING CRITERIA. -CONTINUED TEST FOR AN ADDITIONAL 15 MIN PER CRT-AK-10-45. -LOST 10 PSI IN THE THIRD 15 MIN. -TEST PASSED CRITERIA AS OUTLINED IN CRT-AK-10-45. -RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 56 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 11:30 8.50 STWHIP N DPRB 9,071.00 WEXIT RIG UP E-LINE AND RUN IN THE HOLE WITH GAUGE RING AND LOGGING TOOLS. -PRE JOB SAFETY MEETING. -RIG UP SCHLUMBERGER E-LINE. PICK UP 8.28 GAUGE RING AND GR/CCL AND RUN IN THE HOLE. LOG UP FOR TIE-IN FROM 6900'. MAKE UP 9-5/8"EZSV AND RUN IN ON E-LINE. -SET EZSV AT 6658' -CASING COLLARS AT 6612'AND 6650'. PULL OUT OF THE HOLE AND RIG DOWN SCHLUMBERGER E-LINE. 11:30 - 13:00 1.50 STWHIP N DPRB 9,071.00 WEXIT PRESSURE TEST 9-5/8"CASING AND 9-5/8" EZSV TO 250/3500. RIG UP TO PRESSURE TEST AND CLOSE BLIND/SHEAR RAMS. -PRESSURE TEST TO 250 PSI FOR 5 CHARTED MIN. -GOOD TEST. PRESSURE TEST TO 3500 PSI FOR 30 •CHARTED MIN. -10 PSI LOST IN THE FIRST 15 MIN. -5 PSI LOST IN THE SECOND 15 MIN. -PRESSURE TEST MEETS CRT-AK-10-45 CRITERIA. 13:00 - 18:00 5.00 STWHIP N DPRB 9,071.00 WEXIT LAY DOWN 4-3/4"DRILL COLLARS. -PRE JOB SAFETY MEETING. -LAY DOWN 2 STANDS OF 4-3/4"DRILL COLLARS FROM DERRICK. -CHANGE INSERTS IN BX ELEVATORS FOR 6-1/4"COLLARS. PICK UP 6-1/4"DRILL COLLARS AND STAND BACK IN DERRICK -PRE JOB SAFETY MEETING. -MAKE UP 3 STANDS OF 6-1/4"DRILL COLLARS. BREAK AND LAY DOWN BAKER-LOC'D 4-1/2" SHOE TRACK THAT WAS STOOD BACK IN DERRICK. 18:00 - 21:00 3.00 STWHIP N DPRB 9,071.00 WEXIT MOBILIZE WHIPSTOCK AND MILLING ASSEMBLY COMPONENTS TO RIG FLOOR. -PRE JOB SAFETY MEETING. -MOBILIZE SUBS AND CROSS OVERS TO RIG FLOOR. -MAKE UP AND STAND BACK 5 STANDS OF 4" HEAVY WEIGHT DRILL PIPE. 21:00 - 00:00 3.00 STWHIP N DPRB 9,071.00 WEXIT MAKE UP AND RUN IN THE HOLE 9-5/8" WHIPSTOCK AND WINDOW MILLING ASSEMBLY. -PRE JOB SAFETY MEETING. -MAKE UP WINDOW MILLING ASSEMBLY. -CHECK TORQUE ON MILL CONNECTIONS. -MAKE UP BAKER'ONETRAK'MWD. -SCRIBE MWD. PLUG IN AND CHECK MWD TOOLS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 57 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/31/2013 00:00 - 03:30 3.50 STWHIP N DPRB 9,071.00 WEXIT MAKE UP AND RUN IN THE HOLE 9-5/8" WHIPSTOCK AND WINDOW MILLING ASSEMBLY. -FROM 111'TO 870'. -UP WEIGHT=80K LBS;DOWN WEIGHT= 80K LBS. -FILL PIPE AND SHALLOW TEST MWD. 03:30 - 10:00 6.50 STWHIP N DPRB 9,071.00 WEXIT 'RUN IN THE HOLE WITH THE 9-5/8" WHIPSTOCK AND WINDOW MILLING ASSEMBLY ON 4"HT-38 DRILL PIPE OUT OF THE DERRICK. -FROM 870'TO 6640'. -FILLING PIPE EVERY 20 STANDS. -UP WEIGHT=163K LBS;DOWN WEIGHT= 142K LBS. 10:00 - 11:30 1.50 STWHIP N DPRB 9,071.00 WEXIT ORIENT AND SET WHIPSTOCK. -ORIENT WHIPSTOCK UTILIZING BAKER ONTRAK MWD. -45 DEGREES LEFT. -SET DOWN 20K LBS AND SET TRIP ANCHOR. -PICK UP AND VERIFY TRIP ANCHOR SET. -UP WEIGHT=180K LBS;20K LBS OVER STRING WEIGHT. '-SET DOWN AND SHEAR WHIPSTOCK -SET DOWN 45K LBS TO SHEAR. 11:30 - 12'00 0.50 STWHIP N DPRB 9,071.00 WEXIT MILL WINDOW IN 9-5/8",47 LB/FT CASING. -ESTABLISH MILLING PARAMETERS. -UP WEIGHT 162K LBS;DOWN WEIGHT= 142K LBS. -ROTATING WEIGHT=152K LBS. -TORQUE;6K-7K FT-LBS ON BOTTOM,5K FT-LBS OFF BOTTOM. -425 GPM AND 1700 PSI. MILL WINDOW IN 9-5/8"CASING WITH 8-1/2" WINDOW MILLING ASSEMBLY. FROM 6638'TO 6640'. 12:00 - 21:00 9.00 STWHIP N DPRB 9,071.00 WEXIT MILL WINDOW IN 9-5/8"CASING WITH 8-1/2" WINDOW MILLING ASSEMBLY. -UP WEIGHT 166K LBS;DOWN WEIGHT= 138K LBS. -ROTATING WEIGHT=152K LBS. -TORQUE;8K-9K FT-LBS ON BOTTOM,5K FT-LBS OFF BOTTOM. -593 GPM AND 2770 PSI. -WEIGHT ON BIT=20K LBS. -MILL WINDOW IN 9-5/8"CASING. -TOP OF WINDOW AT 6638'. -BOTTOM OF WINDOW AT 6655'. -MIDDLE OF WINDOW AT 6647'. -MILL/DRILL TO 6679'IN THE CM3. -32'OF NEW FORMATION FROM MIDDLE OF WINDOW. -3'OF GAUGE HOLE IN NEW FORMATION. -NO SIGNS OF CEMENT OBSERVED DURING MILLING OPERATIONS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 58 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 21:30 0.50 STWHIP N DPRB 9,071.00 INTI REAM MILLS THROUGH WINDOW IN 9-5/8" CASING. -WORK MILLS THROUGH WINDOW 3 TIMES. -UP WEIGHT 166K LBS;DOWN WEIGHT= 138K LBS. -ROTATING WEIGHT=152K LBS AT 90 RPM -TORQUE=5K FT-LBS. -593 GPM AND 2770 PSI. 21:30 - 23:00 1.50 STWHIP N DPRB 9,071.00 INTI CIRCULATE TO CLEAN UP WELLBORE. -CIRCULATE 1.5 BOTTOMS UP;550 BBLS. -PUMP 30 BBL EP MUD LUBE SWEEP. -DUMP AT SURFACE. -593 GPM AND 2770 PSI. ' -ROTATING AT 40 RPM WITH 5K FT-LBS TORQUE. 23:00 - 00:00 1.00 STWHIP N DPRB 9,071.00 INTI PERFORM A FIT TO 11.7 PPG EMW. -SHUT DOWN PUMPS AND WORK MILLS THROUGH WINDOW. -NO DRAG NOTED. -MONITOR WELL FOR 10 MIN. PRE JOB SAFETY MEETING WITH RIG CREW. -RIG UP CHART RECORDER AND STRAP PITS. -FLUSH KILL LINE AND CLOSE UPPER PIPE RAMS. -PERFORM A FIT TO 11.7 PPG EMW. -324 PSI WITH 10.8 PPG MUD. -12 STROKES TO PRESSURE UP AT 0.1004 BBL/STK. -HELD FOR 10 MIN. -GOOD TEST:CONFIRMED WITH ODE. 4/1/2013 00:00 - 00:30 0.50 STWHIP N DPRB 9,071.00 WEXIT CONTINUE FIT TO 11.7 PPG EMW. -PUMPED 1.2 BBLS,BLED BACK 1.0 BBLS. -MONITOR WELL FOR 10 MIN. -WELL STATIC. -RIG DOWN TEST EQUIPMENT. BLOW DOWN KILL LINE. 00:30 - 01 30 1.00 STWHIP N DPRB 9,071.00 WEXIT PULL OUT OF THE HOLE WITH 8-1/2"WINDOW MILLING ASSEMBLY AND STAND BACK 4" HT-38 DRILL PIPE. -FROM 6638'TO 6440'. -PUMP DRY JOB. -BLOW DOWN TOP DRIVE. 01:30 - 05:30 4.00 STWHIP N DPRB 9,071.00 WEXIT CONTINUE PULL OUT OF THE HOLE WITH 8-1/2"WINDOW MILLING ASSEMBLY AND STAND BACK 4"HT-38 DRILL PIPE. FROM 6440'TO 870'. 05:30 - 09:00 3.50 STWHIP N DPRB 9,071.00 WEXIT PULL OUT OF THE HOLE FROM 870'. -STAND BACK HWDP. -LAY DOWN COLLARS,MWD AND MILLS. -MONITOR WELL FOR 10 MINUTES PRIOR TO CLOSING RAMS,NO FLOW. -GAUGE MILLS WITH 8-%"GAUGE RING UPPER MILL IN FULL GAUGE. -CLEAN AND CLEAR RIG FLOOR Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 59 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7.206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 aj81.55usft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 11:00 2.00 STWHIP N DPRB 9,071.00 WEXIT PULL WEAR RING AND FLUSH STACK -PICK UP STACK WASHER AND FLUSH I STACK,FUNCTION RAMS. '-BLOW DOWN SURFACE LINES AND EQUIPMENT. -INSTALL WEAR RING AND LAY DOWN STACK WASHER. 11:00 - 12:00 1.00 STWHIP N DPRB 9,071.00 WEXIT MAKE UP SAFETY JOINT AND LAY DOWN IN SHED. -MOBILIZE SUBS AND DRILL BIT TO THE RIG FLOOR. 12:00 - 13:00 1.00 STWHIP N DPRB 9,071.00 WEXIT INSPECT AND SET UP MWD IN PIPE SHED. SIMOPS: -CHECK COMMS _ -CHECKZONALMANAGEMENTSYSTEM ON RIG FLOOR. 13:00 - 14:00 1.00 STWHIP N DPRB 9,071.00 .WEXIT LAY DOWN MWD. -MEMORY ISSUES WITH MWD TOOL. -COULD NOT PROGRAM TOOL. 14:00 - 16:00 2.00 STWHIP N DPRB 9,071.00 WEXIT j PICKUP AND MAKE UP SPARE MWD TOOL IN PIPE SHED. PRE JOB SAFETY MEETING. _-CHANGE OUT SUBS ON MWD. -NEW SUBS DID NOT HAVE INSPECTION CERTS. 16:00 - 16:30 0.50 STWHIP N DPRB 9,071.00 WEXIT DOWNLOAD TO AND CHECK MWD. -VERIFY MWD IS FUNCTIONING CORRECTLY. 18:30 - 20:00 3.50 STWHIP N 'DPRB 9,071.00 ' WEXIT MAKE UP AND RUN IN THE HOLE WITH THE 8-%"DRILLING ASSEMBLY. -TO 1002'. !-UP WEIGHT=75K LBS;DOWN WEIGHT= 71K LBS. 20:00 - 20:30 0.50 STWHIP N DPRB 9,071.00 WEXIT SHALLOW HOLE TEST MWD. -455 GPM AND 1336 PSI. -GOOD TEST. 20:30 - 00:00 3.50 STWHIP N DPRB 9,071.00 WEXIT RUN IN THE HOLE WITH THE 8.44"DRILLING ASSEMBLY ON 4"HT-38 DRILL PIPE OUT OF THE DERRICK -FROM 1002'TO 4499'. -UP WEIGHT=114K LBS;DOWN WEIGHT= 109K LBS. -FILLING PIPE EVERY 20 STANDS. 4/2/2013 00:00 - 02:00 2.00 STWHIP N DPRB 9,071.00 WEXIT CONTINUE TO RUN IN THE HOLE WITH THE 8-1/2"DRILLING ASSEMBLY ON 4"HT-38 DRILL PIPE OUT OF THE DERRICK -FROM 4499'TO 6390'. -UP WEIGHT=153K LBS;DOWN WEIGHT= 130K LBS. -FILLING PIPE EVERY 20 STANDS. Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 60 of 7 Operation Summary Report Common Well Name.F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 1X3-0128W-C:DRILL(7,206,000.00) i l Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 02:00 - 02:30 0.50 STWHIP N DPRB 9,071.00 WEXIT WASH DOWN TO THE TOP OF THE WINDOW AND ORIENT DRILLING ASSEMBLY. -FROM 6390'TO TOP OF THE WINDOW AT 6638'. -UP WEIGHT=153K LBS;DOWN WEIGHT= 130K LBS. -TAKE SLOW PUMP RATES. SPR'S:6,670'MD(6,618'TVD)-TIME=13:30, M W=10.8 PPG #1 MP-20/30 SPM=320/415 PSI #2 MP-20/30 SPM=315/405 PSI 280 GPM AND 550 PSI. 02:30 - 05:00 2.50 DRILL N DPRB 9,071.00 INTI DRILL e'/z'INTERMEDIATE HOLE -FROM 6679'TO 6741'(TVD 6619') -450 GPM,2370 PSI ON BOTTOM,2240 PSI OFF BOTTOM. -0 RPM;OK TQ ON,OK TQ OFF -UP WT 153K,DOWN WT 130K,RT WT OK -WOB 2-7K -ECD=11.13 PPG -AST=1.1 HR;ART=0.0 HR;ADT=1.1 HR. 05:00 - 05:30 0.50 DRILL N DPRB 9,071.00 I INTI POOH F/6741'T/6569' UP WT153K,ONWT130K 05 30 - 12:00 6.50 DRILL N WAIT 9,071.00 ' INTI SAFETY STAND DOWN FOR DROPPED OBJECT -CIRCULATE ACROSS TOP OF HOLE -0 BBL GAIN,0 BBL LOSS 12:00 - 16:30 4.50 DRILL N WAIT 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED OBJECT -CIRCULATE ACROSS TOP OF HOLE -0 BBL GAIN,0 BBL LOSS 16:30 - 18:00 1.50 DRILL N WAIT 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED OBJECT CBU 1.5 X -350 GPM,1490 PSI UP WT 152K,DN WT 130K 18:00 - 00:00 6.00 DRILL N WAIT 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED OBJECT -CIRCULATE ACROSS TOP OF HOLE -0 BBL GAIN,0 BBL LOSS 4/3/2013 00:00 - 12:00 12.00 DRILL N WAIT 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED OBJECT -CBU 1.5X 450 GPM,2100 PSI -CIRCULATE ACROSS TOP OF HOLE -0 BBL GAIN,0 BBL LOSS Printed 6/24/2013 1:20 07PM North America-ALASKA-BP Page 61 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7.206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-138 plan P272 181.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL N WAIT 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED OBJECT -CBU 1.5X 350 GPM,1500 PSI -UPWT153KDNWT131K -CIRCULATE ACROSS TOP OF HOLE -b BBL GAIN,0 BBL LOSS 4/4/2013 00:00 - 12:00 12.00 DRILL N DPRB 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED OBJECT -F/05:00 T/07:30 VIDEO CONFERENCE CALL W/RIG CREWS 272/273 -F/07:30 T/09:00 CBU 1.5X 350 GPM,1500 PSI -BLOW DOWN TOP DRIVE -CIRCULATE ACROSS TOP OF HOLE 0'BBL GAIN,--d BBL LOSS 12:00 - 16:30 4.50 DRILL N WAIT 9,071.00 INTI SAFETY STAND DOWN FOR DROPPED i OBJECT F/12:00 T/12:30 SAFETY MEETING W/ {OPERATIONS MANAGER,FIELD SUPERINTENDENT,RIG MANAGER,AND BOTH CREWS ABOUT IFO AND START UP I-F/12:30 T/14:00 SAFETY MEETING HELD ON EXPECTATION OF NEW SPILL CHAMPION W/ WALK THROUGH OF RIG W/RIG PERSONAL, WALK THROUGH OF RIG CHECKING CIRCUIT - BREAKERS,PROPER VALVE ALIGNMENT, LINES EXPOSED TO COLD TEMP. -ENSURE ALL SYSTEMS ARE READY TO RESUME DRILLING -F/14:00 T/16:30 SAFETY MEETING HELD ON JSA'S AND THE RESPONSIBILITIES OF TASK LEADERS AND PLAN OF WORK -CIRCULATE ACROSS TOP OF HOLE -0 BBL GAIN,0 BBL LOSS 16:30 - 18:30 2.00 DRILL N DPRB 9,071.00 INTI WASH DOWN TO BOTTOM AND ORIENT 81/2" DRILLING ASSEMBLY -F/ 6569'T/ BOTTOM AT 6741' -UP WT=152K LBS,DN WT=135K LBS -CIRCULATE AT 420 GPM AT 1850 PSI. 18:30 - 21:30 3.00 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE HOLE -F/ 6741'T/ 6861'(TVD 6738') -450 GPM,2350 PSI ON BTM,2220 PSI OFF BTM. -60 RPM;6K TQ ON,5K TQ OFF -AST 2.0 HRS,ART 0.1 HRS,ADT 2.1 HRS, JARS HRS=45.1 HRS -UP WT 160K,DOWN WT 135K,RT Wr 145K -WOB 2-5K -ECD=11.05 PPG 21:30 - 22:30 1.00 DRILL N DPRB 9,071.00 INTI TRIP OUT OF THE HOLE WITH 8 1/2"DRILL ASSEMBLY -FROM 6861'TO 6741' -UP WT 170K,DN WT 1351( Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 62 of 75.: Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) ! Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:30 1.00 DRILL N DPRB 9,071.00 INTI CBU 1X 450 GPM,2220 PSI 23:30 - 00:00 0.50 BOPSUR N DPRB 9,071.00 INTI R/U TEST BOPE -WITNESS WAIVED BY JEFFJONES©16:14 HRS 4/5/2013 00:00 - 04:00 4.00 BOPSUR N DPRB 9,071.00 INTI RIH W/RTTS -TEST SAME 250 PSI/1000 PSI,5 MIN/SMIN -DRAIN STACK PULL WEAR RIING INSTALL TEST PLUG 04:00 - 10:00 6.00 BOPSUR N DPRB 9,071.00 INTI TESTING BOPE -TIW#1,DART VALVE @ 250 PSI LOW/3500 PSI HIGH,5 MIN/5 MIN -MANUAL CHOKE,SUPER CHOKE©250PSI LOW/1500 PSI HIGH;5 MIN/5 MIN -HCR KILL VALVE 25OPSI LOW,TEST FAILED 10:00 - 15:00 5.00 BOPSUR N DPRB. 9,071.00 INTI CHANGE OUT HCR KILL VALVE 15:00 - 17:00 2.00 BOPSUR N DPRB.. 9,071.00 INTI TEST BOPE -RETEST HCR KILL, -TEST TIW#2,K4,CHOKE MANIFOLD VALVES 1-15,BLIND RAMS t 250 PSI LOW/3500 PSI HIGH 5 MIN/5 MIN TEST ACCUMULATOR •-CLOSING TIME FOR BOP COMPONENTS ANNULAR PREVENTOR-26 SEC UPPER PIPE RAMS-18 SEC BLIND/SHEAR RAMS-16 SEC LOWER PIPE RAMS-19 SEC HCR CHOKE-2 SEC HCR KILL-2 SEC -ACCUMULATOR PRESSURES SYSTEM PRESSURE-2950 PSI PRESSURE AFTER CLOSING BAG,PIPE RAMS,AND HCR'S-1800 PSI TIME TO ATTAIN 200 PSI-22 SEC TIME TO REGAIN SYSTEM PRESSURE-83 SEC NITROGEN BOTTLE AVERAGE PRESSURE, 14 EA.BOTTLES AT 2200 PSI -ACCUMULATOR CHARGE PUMP OPERATING IPRESSURES ELECTRIC PUMP ON PRESSURE/OFF PRESSURE-2650 PSI/2950 PSI AIR PUMP ON PRESSURE/OFF PRESSURE-2400 PSI/2900 PSI 17:00 - 19:30 2.50 BOPSUR N DPRB 9,071.00 INTI RIG DOWN TEST EQUIMENT -DRAIN BOP AND RISER -BLOW DOWN CHOKE MANIFOLD AND KILL LINE 19:30 - 20:30 1.00 BOPSUR N DPRB 9,071.00 INTI SET WEAR RING 20:30 - 21:30 1.00 BOPSUR N DPRB 9,071.00 INTI RUN IN HOLE -FROM SURFACE TO 195' -ENGAGE RTTS ROTATE 22 TURN OPENING RTTS -CLOSE ANN.PREVENTER PICK UP 2' • -MONITOR WELLAND RELAX RTTS PACKER -OPEN ANN.PREVENTER • Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 63 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 ' Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI. Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:30 1.00 BOPSUR N DPRB 9,071.00 INTI PULL OUT OF HOLE -FROM 6597'TO 6390' -UP WEIGHT 152K 22:30 - 23:30 1.00 BOPSUR N DPRB 9,071.00 INTI LAY DOWN RTTS 23:30 - 00:00 0.50 DRILL N DPRB 9,071.00 INTI RUN IN HOLE -F/6390'T/6657' -UP WT 153K DN WT 135K -ORIENT MOTOR TO HIGH SIDE i 6615' ;CIRCULATE 400 GPM(4)1870 PSI SPR'S:6,657'MD(6,535'TVD)-TIME=23:30, MW=1-1.0PPG #1 MP-20/30 SPM=273/368 PSI #2 MP-20/30 SPM=273/368 PSI 4/6/2013 00:00 - 01:00 1.00 DRILL N DPRB 9,071.00 INTI RIH F/6657'T/6861' UP WT 160K,DN WT 135K CBU 1.5X'S,STAGE PUMPS UP TO 500 GPM, 2600 PSI -BASELINE ECD 11.04 PPG 01:00 - 12:00 11.00 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE HOLE -F/ 6861'T/7335'(TVD 7145') -550 GPM,3325 PSI ON BTM,2800 PSI OFF BTM. -80 RPM;TQ ON 6K,TQ OFF 5K -AST 4.1 HRS,ART 3.0 HRS,ADT 7.1 HRS, JARS HRS=52.2 HRS -UP WT 163K,DOWN WT 141K,RT WT 146K -WOB 3-5K MW 10.8 -ECD=11.2 PPG SPR'S:7,232'MD(7,088'TVD)-TIME=1030, MW=10.8PPG #1 MP-20/30 SPM=273/368 PSI #2 MP-20/30 SPM=273/368 PSI 12:00 - 00:00 12.00 DRILL N DPRB 9.071.00 INTI ,DRILL 1/2"INTERMEDIATE HOLE -F/7,335'T/7,998'(TVD 7,772') -550 GPM©3625 PSI OFF BTM 2500 PSI ON ,BTM -90 RPM,TO ON 6K,TQ OFF 5K -AST.8 HRS ART 6.9 HRS ADT 7.6 FIRS JARS 159.9 HRS -UP WT 168K DOWN WT 145K RT WT 155K -WOB 8K -MW 10.8 -ECD 11.2 SPR'S:7,800'MD(7,602'TVD)-TIME=2035, MW=10.8 PPG #1 MP-20/30 SPM=221/329 PSI #2 MP-20/30 SPM=224/326 PSI Printed 6/24/2013 120:07PM North America-ALASKA-BP Page 64 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/7/2013 00:00 - 12:00 12.00 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE -F/7,998'T/8,592'(TVD 8,304') -525 GPM @ 3550 PSI ON BTM 3330 PSI OFF BTM -90 RPM,TQ ON 7K,TO OFF 6K -AST 1.2 HRS ART 5.6 HRS ADT 6.8 HRS JARS 66.7 HRS -UP WT 176K,DN WT 155K,RT WT 160K WOB 4-8K MW 10.9 ECD 11.26 SPR'S:8,278'MD(8,010'TVD)-TIME=0530, MW=10.9 PPG #1 MP-20/30 SPM=255/360 PSI '#2 MP-20/30 SPM=250/365 PSI NOTE:TIGHTENED UP THE HAMMER UNON ON THE GOOSE NECK. 12:00 - 14:30 2.50 DRILL N DPRB 9,071.00 INTI •DRILL 8 1/2"INTERMEDIATE F/8,592'T/8,734'(TVD 8,438') •-525 GPM @ 3790 PSI ON BTM 3700 PSI OFF BTM -90 RPM,TQ ON 7K,TQ OFF 6K -UP WT 175K,DOWN WT 156K,RT WT 160K -WOB 7K MW 10.8 -ECD 11.26 14:30 - 15:00 0.50 DRILL N DPRB 9,071.00 INTI SERVICE TOP DRIVE 15:00 - 18:00 3.00 DRILL N RREP 9,071.00 INTI CHANGE OUT TOP DRIVE GOOSE NECK 1002 0-RING 18:00 - 20:00 2.00 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE -F/8,734'T/8,805'(TVD 8,504') -500 GPM @ 3780 PSI ON BTM 3630 PSI OFF BTM -90 RPM,TQ ON 7K,TQ OFF 6K -UP WT 176K DOWN WT 156K RT Wi 165K -WOB 7K -MW 10.8 -ECD 11.26 20:00 - 20:30 0.50 DRILL N DPRB 9,071.00 INTI CUTTING AUGER PACK OFF -STAND BACK 1 STAND -RECIPROCATE PIPE -UP WT 183K DOWN WT 156K 20:30 - 00:00 3.50 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE -F/8,805'T/8,975'(TVD 8,656') -500 GPM @ 3780 PSI ON BTM 3630 PSI OFF BTM -90 RPM,TQ ON 7K,TQ OFF 6K -AST 0.0 HRS ART 4.4 HRS ADT 4.4 HRS JARS 71.1 HRS -UPWT176KDOWN WT 156K RT WT 165K -WOB 7K -MW 10.8 -ECD 11.26 REVERSE DRILLING BREAK GAMMA RAY CONFIRMED B-MARKER @ 8,840' Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 65 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date 4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/8/2013 00:00 - 02:00 2.00 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE -F/8,975'T/9,030'(TVD 8,708') -500 GPM @ 3780 PSI ON BTM 3630 PSI OFF BTM -90 RPM,TQ ON 7K,TQ OFF 6K -WOB 7K -MW10.8 CBU TO PICK TSAG SAND CONGLOMERATE WITH GLAUCONITE PRESENT SMALL AMOUNT OF SHALE IN SAMPLE -FORMATION TOP HIGHER THAN EXPECTED -MAKE DECISION TO DRILL ADDITIONAL 5'TO VERIFY TOP OF SAG RIVER 02:00 - 02:30 0.50 DRILL N DPRB 9,071.00 INTI DRILL 8 1/2"INTERMEDIATE -F/9,030'T/9,035'(TVD 8,713') -500 GPM @ 3590 PSI ON BTM 3440 PSI OFF BTM -UPWT179KDN WT158KROT WT168K -AST 0 ART 0.7 ADT 0.7 JARR HRS 71.8 -90 RPM,TQ ON 7K,TQ OFF 6K -WOB 8K MW 10.8 SPR'S:9,035'MD(8,713'TVD)-TIME=0230, MW=10.8 PPG #1 MP-20/30 SPM=250/370 PSI #2 MP-20/30 SPM=250/370 PSI CBU TO PICK TSAG -SAMPLES VERIFY TSAG -FORMATION TOP APPROX.10'HIGHER THAN EXPECTED 02:30 - 05:00 2.50 DRILL N DPRB 9,071.00 INTI CIRCULATE AND CONDITION MUD -CIRCULATE 500 GPM 3400 PSI,90 RPM -REDUCE TO 375 GPM 2100 PSI ON DOWN STROKE -PUMP 35 BBL HI VIS SWEEP,DUMP FROM SYSTEM CBU 3X 05:00 - 06:30 1.50 DRILL N DPRB 9,071.00 INTI POOH F/9035'T/8749' PUMP OUT 85 GPM,250 PSI 06:30 - 09:30 3.00 DRILL N RREP 9,071.00 INTI CHANGE OUT SAVER SUB 09:30 - 12:00 2.50 DRILL N DPRB 9,071.00 INTI PUMP OUT OF HOLE -F/8,749'T/7,892' -2 BBLS PER MIN @ 250 PSI UP WT 173K DN WT 141K 12:00 - 15:30 3.50 DRILL N DPRB 9,071.00 INTI PUMP OUT OF HOLE -F/7,903'T/6,560' -CIRCULATE 84 GPM 380 PSI UP WT 170K DN WT 137K 15:30 - 16:00 0.50 DRILL N DPRB 9,071.00 INTI RIG EVACUATION DRILL 16:00 - 16:30 0.50 DRILL N DPRB 9,071.00 INTI SERVICE TOP DRIVE AND BLOCKS 16:30 - 17:00 0.50 DRILL N DPRB 9,071.00 INTI INSTALL PS-21 Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 66 of 75 Operation Summary Report Common Well Name.F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 21:00 4.00 DRILL N DPRB 9,071.00 INTI RUN IN HOLE -ORIENT MWD -BLOW DOWN TOP DRIVE -F/6,560'T/9,034' UP WT 189K DN WT 152K -CIRCULATE LAST STAND DOWN 450 GPM 3370 PSI NOTE:HELD LINER RUNNING PLANNING MEETING WITH RIG PERSONNEL,BAKER AND SCHLUMBERGER NOT PRESENT 21:00 - 00:00 3.00 DRILL N DPRB 9,071.00 INTI CBU -PUMP 40 BBL HIGH VIS SWEEP -UP WT 180K DN WT 156K ROT WT 170K,90 RPM CIRCULATE UP 500 GPM 3520 PSI -REDUCE TO 450 GPM 2100 PSI ON DOWN STROKE MW 10.8 -CBU 3.5X SPR'S:9,035'MD(8,713'TVD)-TIME=22:30, MW=10.8 PPG #1 MP-20/30 SPM=250/370 PSI #2 MP-20/30 SPM=250/370 PSI 4/9/2013 00:00 - 00:30 0.50 DRILL N DPRB 9,071.00 INTI CBU -UP WT 180K DN WT 156K ROT WT 170K,90 • RPM -CIRCULATE UP 500 GPM 3370 PSI -REDUCE TO 450 GPM 2840 PSI ON DOWN STROKE -MW 10.8 -CBU 3.5X MONITOR WELL 10 MIN,STATIC 00.30 - 04:30 4.00 DRILL N DPRB 9,071.00 INTI POOH -F/9,035 T/7,241' -2 BBL MIN 250 PSI -UP WT 162K DN WT 140K 04:30 - 05:00 0.50 DRILL N DPRB 9,071.00 INTI LD SINGLE ON STD 67 -GALLED THREADS 05:00 - 06:00 1.00 DRILL N DPRB 9,071.00 INTI POOH -F/7,241'T/6,579'UP WT 162K,DN WT 140K • 06:00 - 12:00 6.00 DRILL N RREP 9,071.00 INTI CHANGE OUT SAVER SUB DUE TO GALLED THREADS -TIGHTEN CONNECTIONS ON TOP DRIVE, AND IRON DERRICKMAN -GREASE CROWN-INSPECT DERRICK- TROUBLE SHOOT AND ADJUST THE STAND JUMP FUNCTION • 12:00 - 13:00 1.00 DRILL N RREP 9,071.00 INTI TROUBLE SHOOT AND ADJUST THE STUMP JUMP FUNCTION ON TOP DRIVE. 13:00 - 17:30 4.50 DRILL N DPRB 9,071.00 INTI POOH -F/6,579'T/1,002' -UP WT 163K DN WT 147K -INCORRECT HOLE FILL @ 5,091'MONITOR WELL,STATIC 17:30 - 21:30 4.00 DRILL N DPRB 9,071.00 INTI POOH -F/1,002 T/260' -UP WT 57K DN WT 57K -STAND BACK 4'HWDP Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 67 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 1 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To • Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 00:00 2.50 DRILL N DPRB 9,071.00 INTI LD BHA -F/260'T/75' -DOWNLOAD MWD -GAIN/LOSS 0.2 BBL OVER DISP 4/10/2013 00:00 - 01:00 1.00 DRILL N DPRB 9,071.00 INTI COMPLETE L/D BHA -F175'T/SURFACE -DRAIN AND FLUSH MOTOR 01:00 - 04:00 3.00 BOPSUR N DPRB 9,071.00 INTI INSTALL7"PIPE RAMS -MONITOR WELL FOR 10 MIN,STATIC -CLEAR FLOOR -DRAIN STACK -PULL WEAR RING -INSTALL TEST PLUG -FILL STACK OUT W/ERESH WATER OUT OF ACTIVE PIT 1 -CLOSE BLINDS -M/U TEST JOINT 04:00 - 05:00 1.00 BOPSUR N DPRB 9,071.00 INTI TEST7"RAMS -LOW 250PSI HIGH 3500 PSI 05:00 - 06:00 1.00 BOPSUR N DPRB 9,071.00 INTI RD TEST EQUIPMENT -PULL TEST PLUG INSTALL WEAR RING -LDTESTJT -BLOW DOWN SURFACE LINES 06:00 - 08:00 2.00 CASING N DPRB 9,071.00 INTI RU CASING TOOLS -INSTALL PS-21 -CHANGE OUT ELEVATOR'S -R/U DOUBLE STACK TONGS 08:00 - 09:00 1.00 j CASING N RREP 9,071.00 INTI CHANGE OUT SAVER SUB 09:00 - 12:00 3.00 CASING N RREP 9,071.00 INTI CHANGE OUT ELEVATOR'S -CHANGE OUT PS-21 INSERTS TO 4" -ROUND TRIP 4 STANDS TO TROUBLE SHOOT COMPENSATOR ON TOP DRIVE 12:00 - 15:00 3.00 CASING N RREP 9,071.00 INTI ADJUST STAND JUMP FUNCTION AND CHANG OUT SAVER SUB 15:00 - 16:00 1.00 CASING N DPRB 9,071.00 INTI BREAK DOWN CEMENT XO -DRIFT THE CMT XO(DRIFT TO 2.4") -MU CMT XO 16:00 - 16:30 0.50 CASING N RREP 9,071.00 INTI SERVICE TOP DRIVE - — I 16:30 - 17:30 1.00 CASING N DPRB 9,071.00 INTI RIG UP TO RUN 7"CASING -CHANGE OUT PS-21 INSERTS -CHANGE OUT ELEVATORS 17:30 - 18:00 0.50 CASING N DPRB 9,071.00 INTI PJSM WITH COMPANY REP,DOYON CASING, AND RIG CREW NOTE:HOLD 6 1/8"PRODUCTION SECTION PLANNING MEETING W/RIG MANAGEMENT, SERVICE CREW AND FIELD SUPERINTENDENT 18:00 - 22:30 4.50 CASING N DPRB 9,071.00 INTI RIH WITH 62 JTS OF 7"26#VAMTOP HC -M/U SHOE TRACK AND CHECK FLOATS -F/SURFACE T/2571' -JT 10 UP WT 41K DW WT 44K -JT 20 UP WT 50K ON WT 50K -JT30UPWT60KDNWT60K -JT 40 UP WT 70K DN WT 70K -JT 50 UP WT 80K DN WT 80K -JT60UPWT87KDNWT87K -FILL PIPE EVERY 10 JTS -1 BBL LOSS Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 68 of 75 Operation Summary Report Common Wet Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth , Phase Description of Operations (hr) I (usft) 22:30 - 00:00 1.50 CASING N DPRB • 9,071.00 INTI RIH ON DRILL PIPE -CHANGE OUT ELEVATORS TO 4" -PU JT HT 38 DP -MU 7"LINER HANGER -F/2,571'T/2.603' -CHANGE OUT PS-21 INSERTS TO 5" 4/11/2013 00:00 - 01:00 1.00 CASING N DPRB 9,071.00 INTI MIX AND POUR PAL FLUID INTO PBR AND ALLOW TO SET 1/2 HOUR -L/D SINGLE 01:00 - 01:30 0.50 CASING N DPRB 9,071.00 INTI P/U STD CIRCULATE LINER VOLUME,210 GPM,220 PSI UP WT91k,ONWT9IK 01:30 - 07:00 5.50 CASING N DPRB 9,071.00 INTI RIH F/2581'T/6545' -UP WT 153K,DN WT 134K -SLOWED MAX RUNNING SPEED TO 50'/MIN, PUSHED FLUID AWAY AT 60'/MIN 07:00 - 09:00 2.00 CASING N DPRB 9,071.00 INTI CBU 1X,1.90 GPM,.430 PSI 09:00 - 12:30 3.50 CASING N DPRB 9,071.00 INTI RIH F/6545'T/9008' -P/U CEMENT HEAD,M/U CEMENT HOSE -P/U SINGLE,M/U CEMENT HEAD TO SINGLE -WASH DN TO 9035',42 GPM,385 PSI -UPINT 207K,DNWT143K 12:30 - 16:30 4.00 . CEMT N DPRB 9,071.00 INTI CIRCULATE AND CONDITION MUD -STAGE PUMPS UP IN 1 BPM INCREMENTS I TO 210 GPM,680 PSI Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 69 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 19:00 2.50 CEMT N DPRB 9,071.00 INTI CEMENT 7"LINER AS FOLLOWS: SET LINER ON DEPTH 9033" PTEST CEMENT LINE PUMP 5.1 BBLS H2O AND TEST TO 700 PSI, TEST GOOD -PRESSURE UP TO 4700 PSI,NO LEAKS -BLEED OFF H2O TO FLOW LINE NO LEAKS IN CEMENT LINE PROCEED W/ JOB -PUMP 31.5 BBLS 12.5 PPG MUD PUSH AT 4 BPM ,TAIL -PUMP 29.5 BBLS,15.8 PPG CLASS G CEMENT AT 5.0 BPM -YIELD 1.16 CU FT/SX(142 SX) -DROP DP WIPER POSITIVE INDICATION DART LEFT CEMENT HEAD DISPLACE DISPLACE WITH CEMENTERS WITH 10.8 'PPG LSND MUD -7 BPM,896 PSI MAX PRESSURE BEFORE LATCHING -SLOW TO 3 BPM -LATCH DP WIPER INTO LINER WIPER PLUG, 68.0 BBL DISPLACED -INCREASE RATE T/7 BPM,1276 PSI MAX PRESSURE BEFORE CEMENT OUT SHOE -SLOW PUMP TO 2 BPM,156 BBL DISPLACED -BUMP PLUG,164 BBL DISPLACED,1166 PSI DID NOT RECIPROCATE PIPE AFTER STARTED PUMPING CEMENT INCREASE PRESSURE TO 3020 PSI TO SET HANGER -SET 70K DN WT ON HANGER TO CONFIRM SET INCREASE PRESSURE TO 4200 PSI TO RELEASE RUNNING TOOL -P/U 7',EXPOSE DOGS -SET 60K DN WT,SET PACKER -P/U 5 AND SET DN TO CONFIRM BLEED OFF,CHECK FLOATS,GOOD CEMENT IN PLACE AT 18:47 HRS -NO LOSSES 19:00 - 20:00 1.00 CEMT N DPRB 9,071.00 INTI B/D CEMENTERS -KNOCK OFF HOSE AND B/D -ROTATE AT 25 RPM AND SET 60K DN TO CONFIRM PACKER SET Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 70 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. j UWI: Active datum:F-13B plan P272(81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 21:00 1.00 CEMT N DPRB 9,071.00 INTI PRESSURE UP TO 500 PSI -P/U UNTIL PRESSURE TO SEE PRESSURE DECREASE -BRING PUMPS UP TO 420 GPM,1275 PSI -MARK PIPE FOR NO-GO WHILE CIRCULATING -CBU 1X --NO CEMENT RETURNS 21:00 - 22:00 1.00 CEMT N DPRB 9,071.00 INTIL/D CEMENT HEAD,B/D TD 22:00 - 23:30 1.50 CEMT N DPRB 9,071.00` INT1 POOH F/6462'T/5302' -UPWT108K,DNWT108K 23:30 - 00:00 0.50 CEMT N DPRB 9,071.00 INTI PUMP DRY JOB -B/DTD 4/12/2013 00:00 - 05:00 5.00 CEMT N DPRB 9,071.00 INTI POOH F/5302 TO SURFACE -UP WT 100K DN WT 100K -3.5 BBLS OVER DISPLACEMENT - -LD LINER RUNNING TOOL MONITOR WELL <STATIC> 05:00 - 05:30 0.50 CEMT N ` DPRB 9,071.00 INTI CLEARAND'CLEAN FLOOR 05:30 - 07:30 2.00 BOPSUR _N DPRB 9,071.00 INTI MONITOR WELL -PULL WEAR RING -SET TEST PLUG -CHANGE TOP RAMS,7"TO 2 7/8"X 5"VBR'S 07:30 - 17:00 9.50 BOPSUR N DPRB 9,071.00 INTI TEST BOPE -R/U TEST JT -FILL SURFACE LINES,STACK,GAS BUSTER. -TEST,K4,CHOKE MANIFOLD VALVES 1-15, BLIND RAMS 250 PSI/3500 PSI, 5 MIN/5 MIN -4"&4 1/2"TEST JTS,NC-50 FOSV ON 4 1/2", HT 38"FOSV AND DART VALVE ON 4"TEST JT MANUAL AND SUPER CHOKE 250 PSI LOW 1500 PSI HIGH TEST ACCUMULATOR -CLOSING TIME FOR BOP COMPONENTS ANNULAR PREVENTOR-35 SEC UPPER PIPE RAMS-16 SEC BLIND/SHEAR RAMS-30 SEC LOWER PIPE RAMS-16 SEC HCR CHOKE-.5 SEC HCR KILL-.5 SEC 1-ACCUMULATOR PRESSURES I SYSTEM PRESSURE-2950 PSI PRESSURE AFTER CLOSING BAG,PIPE RAMS,AND HCR'S-1800 PSI TIME TO ATTAIN 200 PSI-22 SEC TIME TO REGAIN SYSTEM PRESSURE-91 SEC NITROGEN BOTTLE AVERAGE PRESSURE, 14 EA.BOTTLES AT 2100 PSI -ACCUMULATOR CHARGE PUMP OPERATING PRESSURES ELECTRIC PUMP ON PRESSURE/OFF PRESSURE-2650 PSI/2950 PSI AIR PUMP ON PRESSURE/OFF PRESSURE-2350 PSI/2900 PSI -TEST WITNESSED BY(CHUCK SCHEVE) Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 71 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad - --I Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations I (hr) (usft) 17:00 - 18:30 1.50 BOPSUR N DPRB 9,071.00 INTI RD TEST EQUIMENT -DRAIN STACK -INSTALL WEAR RING CLEAN AND CLEAR RIG FLOOR 18:30 - 20:00 1.50 CEMT N DPRB 9,071.00 INTI TEST LINER TOP/CASING -250 PSI LOW 5 MIN -3500 PSI HIGH 30 MIN -12 PSI PRESSURE DROP 1ST 15 MIN -3 PSI PRESSURE DROP 2ND 15 MIN -15 PSI TOTAL PRESSURE DROP -TEST GOOD 20:00 - 21:00 1.00 DRILL N RREP 9,071.00 INTI CHANGE QUT STAND JUMP CARTRIDGE -ADJUSTED LINK TILT 21:00 - 21:30 0.50 DRILL N DPRB 9,071.00 INTI SERVICE TOP DRIVE 21:30 - 22:00 0.50 DRILL N DPRB 9,071.00 -J INTI PJSM WITH DD/MWD ON PICKING UP BHA 22:00 - 00:00 2.00 DRILL N DPRB, 9,071.00 INTI PICK UP 6-1/8"PRODUCTION BHA -UP WT 40K DN WT 40 4/13/2013 00:00 - 03:30 3.50 DRILL N DPRB 9,071.00 INTI 6 1/8"BHA -MU BHA#10 PER DD/MWD -CORROSION RING ON TOP OF NON-MAG BELOW CIRC SUB -PJSM WITH MWD TO LOAD NUKE SOURCE, •LOAD SAME 03:30 - 10:00 6.50 DRILL N 1 RREP 9,071,00 INTI REPAIR IRON DERRICKMAN AND IRON ROUGHNECK(IR) 10:00 - 12:00 2.00 , DRILL N DPRB 9,071.00 INTI CUT AND SLIP 80'OF DRILLING LINE 12:00 - 13:00 1.00 DRILL N RREP 9.071.00 INTI SERVICE IR,TROUBLE SHOOT SAME 13:00 - 14:00 1.00 DRILL N DPRB 9,071.00 INTI MAKE UP BHA -F/204'T/942' i -UP WT 60K DN WT 64K 14:00 - 19:00 • 5.00 DRILL N DPRB 9,071.00 INTI RIH W/6 1/8"DRILLING ASSEMBLY F/942'T/6,141' -UPWT136KDNWT126K -FILL EVERY 20 STANDS 19:00 - 21:00 2.00 DRILL N DPRB 9,071.00 INTI D1 DRILL -KICK WHILE DRILLING D6 DRILL -STRIPPING IN THE HOLE -MR FOLLOWING DRILL 21:00 - 21:30 0.50 DRILL N DPRB 9,071.00 INTI ,R/D TIW AND DART VALVE -BLOW DOWN KILL AND CHOKE MANIFOLD 21:30 - 00:00 2.50 DRILL N DPRB 9,071.00 INTI RIH W/6 1/8"DRILLING ASSEMBLY F/6,141'T/8,937' UP WT 188K DN W1-144K -FILL EVERY 20 STDS 4/14/2013 00:00 - 03:30 3.50 DRILL N DPRB 9,071.00 INTI FLUID SWAP -CIRCULATE 254 GPM,2500 PSI -SWAP 10.8 LSND TO 8.7 KCL QUIKDRIL PUMP 50 BBL SPACER -PUMP 50 BBL EP MUD LUBE,BEFORE SENDING NEW MUD DOWN HOLE • -DUMP SPACER AND EP MUD LUBE AT SURFACE Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 72 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7.206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 03:30 - 04:30 1.00 DRILL N DPRB 9,071.00 INTI PERFORM NEGATIVE PRESSURE TEST,TEST GOOD-NO FLOW -APPROVED BY WTL M.SCHULTZ SPR'S:8,937'MD(8,623'TVD) MW=8.7 PPG #1 MP-20/30 SPM=375/490 PSI #2 MP-20/30 SPM= 370/485 PSI 04:30 - 10:00 5.50 N DPRB 9,071.00 INTI DRILL CEMENT AND FLOAT EQUIPMENT -F/8,945'T/9,035' -DRILL 20'OF NEW FORMATION F/9,035'T/ 9,055' -WOB=7K,RPM=35 -PSI ON=1200,PSI OFF 1100,GPM=275 -TO ON= 7K,TQ OFF=2K -UP WT.=160K,DN WT 144K,RT WT=169K 10:00 - 11:30 1.50 N DPRB 9,071.00 INTI CIRCULATE BOTTOMS UP -300 GPM,1460 PSI -UP WT=180K,DN WT=160K -MONITOR WELL FOR 10 MINUTES,STATIC 11:30 - 12:00 0.50 N DPRB 9,071.00 INTI PJSM -RIG UP AND PERFORM FIT -EMW OF 9.8 PPG,500 PSI -APPROVED BY ODE F.MAMMADOV 12:00 - 12:30 0.50 N DPRB 9,071.00 PROD1 CIRCULATE -300 GPM 1460 PSI UP WT 180K DN WT 160K 12:30 - 21:00 8.50 DRILL P PROD1 DRILL 6 1/8 PRODUTION -F/9,055'T/9,258'(TVD 8,899') -300 GPM @ 1600 PSI ON BTM 1475 PSI OFF BTM UP WT185KDNWI.156KROT WT169K -AST 4.6 ART 2.5 ADT 7.1 JARR HRS 78.9 70 RPM,TQ ON 5K,TQ OFF 5K -WOB 12K -MW 8.6 SPR'S:9,258'MD(8,899'TVD)-TIME=2100, MW=8.6 PPG #1 MP-20/30 SPM=375/490 PSI K2 MP-20/30 SPM=370/485 PSI 21:00 - 22:00 1.00 DRILL P PROD1 POOH -F/9,258'17 9,030' '-CBU 1X -UP WT 185KK ON WT 156K -300 GPM 1475 PSI 22:00 - 00:00 2.00 DRILL N WAIT 9,031.00 PROD1 MONITOR WELL ON TRIP TANK -CONDUCT SAFETY STAND DOWN WITH MYLES WAYNE CREW 4/15/2013 00:00 - 07:00 7.00 DRILL N WAIT 9,031.00 PROD1 MONITOR WELL ON TRIP TANK -CONDUCT SAFETY STAND DOWN WITH •MYLES WAYNE CREW 07:00 - 07:30 0.50 DRILL P PROD1 RIH F/9031'T/9258',UP WT 185K,ON WT 156K Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 73 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. 'UW 1: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 12:00 4.50 DRILL P PROD1 PJSM,MONITOR WELL FOR 10 MINUTES, STATIC DRILL 6-1/8"PRODUCTION -F/9,258'T/9,356'(TVD 8,973') -300 GPM @ 1600 PSI ON BTM 1500 PSI OFF BTM -UPWT181KDNWT161KROT WT172K -AST 0.8 ART 0.9 ADT 1.7 JAR HRS 80.6 -50 RPM,TQ ON 4K,TQ OFF 4K -WOB 10K -MW8.6 -FUNCTION TEST CROWN-O-MATIC AND PERFORM BRAKE CAPACITY TEST SPR'S:9,242'MD(8,888'TVD)-TIME=08:15, MW=8.6 PPG #1 MP-20/30 SPM=426/542 PSI #2 MP-20/30 SPM=423/542 PSI 12:00 - 16:00 4.00 DRILL P :1 PROW DRILL 6-1/8"PRODUCTION -F/9,356'T/9,424'(TVD 9,027') -300 GPM @ 1600 PSI ON BTM 1500 PSI OFF BTM -UP WT 181K DN WT 161K ROT WT 170K -AST 1.6 ART 1.9 ADT 3.5 JAR HRS 83.5 -50 RPM TQ ON 6K TO OFF 4K -WOB 12K -MW 8.6 SPR'S:9,424'MD(9,027'TVD)-TIME=16:00, MW=8.6PPG #1 MP-20/30 SPM=380/500 PSI #2 MP-20/30 SPM=380/500 PSI PENETRATION RATE DROPPED OFF AT 9410' FROM 10'/HR TO 0'/HR -TORQUE ERRATIC -DRILLED ADDITIONAL 14'TO 9424' -CONFERENCE WITH F.MAMMADOV,AND M. SCHULTZ,MADE DECISION TO PULL BIT 16:00 - 17:30 1.50 DRILL N DFAL 9,424.00 PROD1 CBU -300 GPM 1500 PSI -UPWT181KDNWT161K_ 17:30 - 00:00 6.50 DRILL N DFAL 9,424.00 PROD1 POOH -F/9,424 T/942' -PUMP DRY JOB @ 8,970'1450 PSI UP WT 58K DN WT 65K -MONITOR WELL @ 9,424'AND @ SHOE < ISTATIC> 4/16/2013 00 00 - 02:30 2.50 DRILL N DFAL 9,428.00 PROD1 L/D BHA F/942'T/189' 02:30 - 03:00 0.50 DRILL N DFAL 9,428.00 PROD1 1 LAY DOWN 2 NM DRILL COLLAR'S F/189'T/158' -TRIP GAIN/LOSS.4 UNDER DISP. 03:00 - 03:30 0.50 DRILL N DFAL 9,428.00 PROD1 PJSM TO PULL SOURCE 03:30 - 04:00 0.50 DRILL N DFAL 9,428.00 PROD1 MAKE UP NM STAND BACK IN DERRICK -BREAK OUT BIT Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 74 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 04:00 - 08:00 4.00 DRILL N DFAL 9,428.00 PROD1 MAKE UP BHA WITH NEW 6-1/8"XR-20 SMITH BIT -FROM SURFACE TO 941'. -BIT 5/16"OUT OF GAUGE WITH GAUGE ROW TEETH MISSING. -BIT GRADE 1-8-BT-G-0-5-LT-PR 08:00 - 10:30 2.50 DRILL N RREP 941.00 PROD1 PJSM,CHANGEOUT SAVER SUB ON TOP •DRIVE. 10:30 - 12:00 1.50 DRILL N DFAL 9,428.00 PROD1 RUN IN THE HOLE F/941'T/1,783' -FILL PIPE EVERY 20 STANDS. -DNWT 75KUPWT 67K -TEST MWD AT 1,035'300 GPM •12:00 - 13:00 1.00 DRILL N DFAL 9.428.00 PROD1 RUN IN THE HOLE F/1,783'T/2,831' FILL PIPE EVERY 20 STANDS. '-DN WT 80K UP WT 80K 13:00 - 13:30 0.50 DRILL P PROD1 SERVICE CROWN AND.TOP DRIVE 13:30 - 14:00 0.50 DRILL - P PROD1 PERFORMED SIMULTANEOUS DRILLS -D1 1 MIN 5 SEC -FIRE DRILL 1 MIN 30 SEC NOTE:HAD A SECOND DRILL JUST FOR ROUSTABOUTS FOR WELL CONTROL 14:00 - 15:00 1.00 DRILL N RREP 1,783.00 PROD1 CHANGE OUT HYDRAULIC HOSE ON IDL 15:00 - 20:30 5.50 DRILL N DFAL 9,428.00 PROD1 RUN IN THE HOLE F/2,831'T/9,224' FILL PIPE EVERY 20 STANDS. -DNWT 159KUPWf180K 20:30 - 22:00 1.50 DRILL N DFAL 9,428.00 PROD1 REAM DOWN -F/9,224'T/9,424' -CIRCULATE 225 GPM @ 1000PSI -UPWT181KDNWT160KRTWT170K 40 RPM -TQ 3K -WOB 3K NOTE:TOOK WT(§9380'3K 22:00 - 00:00 2.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION -F/9,424'T/9,477'(TVD 9,057') -300 GPM©1650 PSI ON BTM 1550 PSI OFF BTM -UPWT181KDNWT160KROT WT170K -AST 0.7 ART 0.6 ADT 1.3 JAR HRS 85.4 -50 RPM,TQ ON 4K,TO OFF 3K -WOB 10K -MW8.6 SPR'S:9,424'MD(9,027'TVD)-TIME=22:00, MW=8.6PPG #1 MP-20/30 SPM=380/500 PSI #2 MP-20/30 SPM=380/500 PSI Printed 6/24/2013 1 20:07PM North America-ALASKA-BP Page 75 of 75 Operation Summary Report Common Well Name:F-13 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/16/2013 End Date:4/18/2013 X3-0128W-C:DRILL(7,206,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/17/2013 00:00 - 06:00 6.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION -F/9,477 T/9680'(9201'TVD) -300 GPM©1670 PSI ON BTM 1540 PSI OFF BTM -UPWT193KDNWT161KROT WT175K -50 RPM,TQ ON 4K,TQ OFF 4K -WOB 12K • -MW8.6 AST=0 HRS,ART=3.8 HRS,ADT=3.8 HRS, JAR HRS=89.3 HRS SPR'S:9680'MD(9,201'TVD)-TIME=06:00, MW=8.6PPG. #1 MP-20/30 SPM=390/520 PSI #2 MP-20/30 SPM=390/590 PSI 06:00 - 06:30 0.50 DRILL P PROD1 CONDITION MUD AND CIRCULATE HOLE CLEAN. 06:30 - 12:00 5.50 DRILL P PROD1 MAD PASS FROM 9680'10 9033'(7"LINER SHOE). -300 GPM,50 RPM. • -PULL 150'PER HOUR. 12:00 - 13:00 1.00 DRILL P PROD1 MONITOR WELL FOR 10 MINUTES,STATIC. -RUN IN THE HOLE FROM 9033'TO 9680'. -UP WT 190K DN WT 164K. -NO FILL ENCOUNTERED ON TRIP IN. 13:00 - 15:00 2.00 DRILL P PROD1 CIRCULATE HI VIS SWEEP. :72550GPM DOWN AT 1240 PSI,300 GPM UP AT 1550 PSI. -UP WT 190K DN WT 164K ROT WT 170K 11 -50 RPM,4K TORQUE. NOTE:CHANGE OUT HOSE ON IDL 15:00 - 22:00 7.00 DRILL P . PROD1 PUMP DRY JOB,POOH -F/9,680'T/942' UP WT 60K DN WT 60K MONITOR WELL 10 MIN(4)BOTTOM,SHOE, BHA<STATIC> 22:00 - 00:00 2.00 DRILL P PROD1 LAY DOWN 6-1/8"DRILLING ASSEMBLY. -4"HWDP -F/942'T/509' -UP WT 50K DN WT 50K -REMOVE PS-21@ 721'(JARS) 4/18/2013 00:00 - 01:00 1.00 DRILL P PROD1 CONTINUE TO LAY DOWN 6-1/8"DRILLING ASSEMBLY. -FROM 509'TO 200' -LAY DOWN REMAINING 4"HWDP. 01:00 - 01:30 0.50 DRILL P PROD1 SAFETY MEETING WITH BAKER TO PULL NUCLEAR SOURCE _ -PULL NUCLEAR SOURCE 01:30 - 02:30 1.00 DRILL P PROD1 CONTINUE TO LAY DOWN BHA 102:30 - 03:00 0.50 DRILL P PROD1 PLUG IN AND DOWN LOAD DATA F/MWD 03:00 - 04:30 1.50 DRILL P PROD1 LAY DOWN BHA -BREAK OUT BIT -DRAIN MOTOR -MONITOR WELL<STATIC> -CLOSE BLINDS 04:30 - 05:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE AND IDL Printed 6/24/2013 1:20:07PM North America-ALASKA-BP Page 1 of 6 Operation Summary Report Common Well Name:F-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:4/18/2013 End Date:4/23/2013 X3-0128W-C:DRILL(3,180,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/18/2013 05:00 - 06:00 1.00 CASING P RUNPRD PRE JOB SAFETY MEETING TO RIG UP CASING -RIG UP CASING TOOLS TO RUN 4 1/2"LINER 06:00 - 10:30 4.50 CASING P RUNPRD RUN 4 1/2"LINER -T/837' -PICK UP LINER HANGER,RS NIPLE,LINER PACKER,BOT SETTING TOOL AND X OVER HT38 X NC38 10:30 - 11:00 0.50 CASING P RUNPRD RIG DOWN CASING CREW AND TOOLS 11:00 - 11:30 0.50 CASING P RUNPRD FILL TIE BACK SLEEVE WITH PAL MIX 11:30 - 12:00 0.50 CASING P RUNPRD PICKUP FIRST STAND OF DRILL PIPE MAKE UP TO LINER HANGER 12:00 - 12:30 0.50 CASING P RUNPRD CIRCULATE LINER VOLUME -126 GPM @ 55PS1 UP WT 55K DN WT 55K 12:30 - 20:00 7.50 CASING P RUNPRD RUN IN HOLE -F/837'T/9,035' -1,782',UP WT 70K DN WT 70K -2,727',UP WT 85K DN WT 85K -3,673',UP WT 90K DN Wr 90K •-4.618',UP WT 100K DN WT 100K -5,563',UP WT 115K DN WT 115K •-6,509',UP WT 128K DN WT 125K 7,454',UP WT 145K DN WT 137K -8,400',UP WT 155K DN WT 143K -9,035',UP WT 164K DN WT 149K 20:00 - 22:00 2.00 CASING P RUNPRD CIRCULATE BOTTOMS UP -126 GPM @ 300 PSI -UP WT 161K DN WT 146K 22:00 - 00:00 2.00 CASING P RUNPRD RUN IN HOLE -F/9,035'T/9,662' -UP WT 171K DN Wr 153K 4/19/2013 00:00 - 00:30 0.50 CASING P RUNPRD PJSM AND RIG UP CEMENT HEAD. • -PICK UP CEMENT HEAD. RIG UP CEMENT LINES. 00:30 - 01:00 0.50 CASING P RUNPRD WASH LINER TO BOTTOM. -F/9661'T/9680'. -50 GPM 263 PSI. 01:00 - 03:30 2.50 CEMT P RUNPRD STAGE UP PUMPS.CIRCULATE AND RECIPRICATE BOTTOMS UP. -50 GPM 263 PSI. -100 GPM 305 PSI. -150 GPM 460 PSI. -200 GPM 550 PSI. -250 GPM 675 PSI. NO LOSSES WHILE STAGING PUMPS UP. -PJSM FOR CEMENT JOB. 03:30 - 04:00 0.50 CEMT P RUNPRD PRESSURE TEST CEMENT LINES. -PUMP 5 BBL WATER -PRESSURE TEST LINE TO LOW 250 PSI. — _ HIGH 4500 PSI. • 11 Printed 6/24/2013 1:22:33PM North America-ALASKA-BP Page 2 of 6 Operation Summary Report Common Well Name:F-13 AFE No Event Type:COM-ONSHORE(CON) I Start Date:4/18/2013 End Date:4/23/2013 X3-0128W-C:DRILL(3.180,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 I Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. I UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) . Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) Y 04:00 - 05:30 1.50 CEMT P RUNPRD PUMP CEMENT. ��1i) -PUMP 25 BBL 12.5 BBL MUD PUSH. ) -5 BPM,570 PSI. -PUMP 25 BBL 15.8 CLASS G CEMENT (1 • -5 BPM,620 PSI. -DROP PLUG -DISPLACE WITH 8.6 PPG DRILLING FLUID. -5 BPM,130 PSI ICP 950 PSI FCP. -LATCH DART AT 92 BBL INTO DISPLACEMENT. I -BUMP PLUG AT 102.4 BBL INTO DISPLACEMENT. -CEMENT IN PLACE AT 05:13 HRS. -SET HANGER. -INCREASE PUMP PRESSURE TO 4200 PSI AFTER PLUG BUMP. • • -SET DOWN 74K ON HANGER TO CONFIRM SET.GOOD. • 1- -CHECK FLOATS: -BLEED BACK 1.5 BBL ' -CONFIRMED NO FLOW AFTER BLEED BACK. 05:30 - 06:00 0.50 CEMT P 1 RUNPRD BLOW DOWN CEMENT LINE. -BLOW LINE BACK TO SLB. -BLOW LINE BACK TO MUD MANIFOLD. -LINE UP TO PUMP DOWN DRILL PIPE.. 06:00 - 08:00 2.00 CEMT • P ! RUNPRD 'CIRCULATE LINER TOP CLEAN. -RELEASE FROM LINER. -550 GPM,1250 PSI. -UP WEIGHT 164K,DOWN WEIGHT 154K. -10 BBL CMT BACK TO SURFACE. 08:00 - 08:30 0.50 CEMT P ' RUNPRD i RIG DOWN CEMENT HEAD. -BREAK DOWN CEMENT HEAD AND LAY ' I ;DOWN. -RIG DOWN CEMENT LINES. 08:30 - 11:00 2.50 CASING P RUNPRD DISPLACE WELL TO 8.5 PPG SEAWATER. -PRE-JOB SAFETY MEETING. I-PUMP AT 420 GPM,850 PSI. -MONITOR WELL. STATIC. 11:00 - 20:30 9.50 CASING P RUNPRD •LAY DOWN DRILL PIPE. I -F/8850'T/2362'. -UP WEIGHT 65K.DOWN WEIGHT 65K. 20:30 - 21:00 0.50 CASING P RUNPRD H2S DRILL. -PERFORMED H2S DRILL IN CONJUNCTION WITH RIG EVACUATION DRILL. -AFTER ACTION REVIEW WITH DRILLING TEAM. 21:00 - 22:30 1.50 CASING P RUNPRD ;TRIP OUT OF THE HOLE. I F/2362'T/59'. 22:30 - 23:00 0.50 CASING P RUNPRD 'LAY DOWN LINER RUNNING TOOL. 23:00 - 00:00 1.00 BOPSUR P RUNPRD RIG UP TO PRESSURE TEST BOP EQUIPMENT -MONITOR WELL.STATIC. -DRAIN RISER AND STACK. -PULL WEAR RING. -SET TEST PLUG. Printed 6/24/2013 1:22:33PM North America-ALASKA-BP Page 3 of 6 Operation Summary Report Common Well Name:F-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:4/18/2013 End Date:4/23/2013 X3-0128W-C:DRILL(3,180,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/20/2013 00:00 - 03:00 3.00 BOPSUR P RUNPRD RIG UP FOR TESTING BOP EQUIPMENT. RIG UP TEST JOINT. RIG UP TEST CHART. RIG UP TEST MANIFOLD. FLUID PACK ALL EQUIPMENT FOR BOP TEST. PRE-JOB FOR TESTING BOP EQUIPMENT. 03:00 - 09:00 6.00 BOPSUR N RREP RUNPRD TROUBLESHOOT AND REPAIR BOP TEST MANIFOLD AND PUMP. 09:00 - 12:00 3.00 CASING P RUNPRD LAY DOWN 30 STANDS 4"DP WITH FORE ARM CRANE AND PIPE CAT. 12:00 - 17:00 5.00 BOPSUR P RUNPRD TEST BOPE TEST,K4,CHOKE MANIFOLD VALVES 1-15, BLIND RAMS @ 250 PSI/3500 PSI, 5 MIN/5 MIN -4"&4 1/2"TEST JTS,NC-50 FOSV ON 4 1/2", HT 38"FOSV AND DART VALVE ON 4"TEST JT MANUALAND SUPER CHOKE 250 PSI LOW 1500 PSI HIGH • TEST ACCUMULATOR -CLOSING TIME FOR BOP COMPONENTS ANNULAR PREVENTOR-27 SEC UPPER PIPE RAMS-17 SEC BLIND/SHEAR RAMS-30 SEC LOWER PIPE RAMS-16 SEC • HCR CHOKE-2 SEC HCR KILL-2 SEC -ACCUMULATOR PRESSURES SYSTEM PRESSURE-2950 PSI PRESSURE AFTER CLOSING BAG,PIPE RAMS,AND HCR'S-1800 PSI TIME TO ATTAIN 200 PSI-23 SEC TIME TO REGAIN SYSTEM PRESSURE-91 SEC NITROGEN BOTTLE AVERAGE PRESSURE, 14 EA.BOTTLES AT 2100 PSI -ACCUMULATOR CHARGE PUMP OPERATING PRESSURES ELECTRIC PUMP ON PRESSURE/OFF PRESSURE-2650 PSI/2950 PSI AIR PUMP ON PRESSURE/OFF PRESSURE-2350 PSI/2850 PSI -TEST WITNESS WAIVED BYAOGCC:BOB NOBLE 17:00 - 18:30 1.50 BOPSUR P RUNPRD RIG DOWN TEST EQUIPMENT. -PULL TEST PLUG. CLEAR AND CLEAN RIG FLOOR. 18:30 - 20:30 2.00 CASING P RUNPRD TEST ZXP LINER LAP -250 PSI LOW,5 MIN. -3500 PSI HI,30 MIN. -0 PSI LOST IN FIRST 15 MINUTES,0 PSI LOST IN LAST 15 MINUTES. -7.7 BBL BLEED BACK. -RIG DOWN,BLOW DOWN. 20:30 - 23:30 3.00 CASING P RUNPRD LAY DOWN 17 STANDS 4"DP WITH FORE ARM CRANE AND PIPE CAT. 23:30 - 00:00 0.50 RUNCOM P RUNCMP MAKE UP 4 1/2"DX TUBING HANGER ON LANDING JOINT. -DUMMY RUN W/TUBING HANGER. Printed 6/24/2013 1:22:33PM North America-ALASKA-BP Page 4 of 6 ,,,, Operation Summary Report w Common Well Name:F-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:4/18/2013 I End Date:4/23/2013 X3-0128W-C:DRILL(3,180,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor.PARKER DRILLING CO. UWI: Active datum:F-13B plan P272©81.55usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (usft) 4/21/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP DUMMY RUN W/HANGER. -VERIFY HANGER DEPTH TO RKB WITH 1_CAMERON. 01:00 - 02:00 1.00 RUNCOM P RUNCMP RIG UP CASING TONGS,TQ TURN EQUIPMENT. 02:00 - 02:30 0.50 RUNCOM P RUNCMP SAFETY MEETING ON RUNNING COMPLETION TUBING WITH ALL HANDS. 02:30 - 12:00 9.50 RUNCOM P RUNCMP RUN 4 1/2"12.6#VT COMPLETION FROM SURFACE TO 5420'. '-MONITOR DISPLACEMENT WITH TRIP TANK 12:00 - 13:00 1.00 RUNCOM P RUNCMP CONTINUE TO RUN IN THE HOLE WITH 4'A" 12.6 LB/FT VAMTOP COMPLETION. -FROM 5420'TO 5875'. I-UP WEIGHT=102K LBS;DOWN WEIGHT= ' 98K LBS. 113:00 - 13:30 0.50 RUNCOM P RUNCMP SERVICE TOP DRIVEAND BLOCKS. -TROUBLE SHOOT ELECTRICAL ISSUE WITH TOP DRIVE MONKEY BOARD COLLISION AVOIDANCE SYSTEM. 13:30 - 14:30 1.00 RUNCOM N RREP 5,875.00 RUNCMP TROUBLE SHOOT ELECTRICAL ISSUE VNTH i TOP DRIVE MONKEY BOARD COLLISION AVOIDANCE SYSTEM. 14:30 - 21:30 7.00 _ RUNCOM P RUNCMP CONTINUE TO RUN IN THE HOLE WITH 4'r4" 12.6 LB/FT VAMTOP COMPLETION. -FROM 5875'TO 8857'. UP WEIGHT=140K LBS;DOWN WEIGHT= 123K LBS. 21:30 - 22:00 0.50 RUNCOM P -. RUNCMP TAG UP ON TOP OF LINER TOP AND WORK WLEG INTO LINER TIE BACK SLEEVE. -TAG LINER TOP TIMES. -TURN COMPLETION 1/2 TURN. -TAG UP ON NO-GO IN TIE BACK SLEEVE 16.5'ON JOINT#208. -TOP OF TIE BACK SLEEVE AT 8857'. -BOTTOM OF LINER TIE BACK SLEEVE AT 8868'. 22.00 - 23:30 1.50 RUNCOM P RUNCMP SPACE OUT AND LAND TUBING HANGER. -SPACE OUT WITH 5.86'PUP JOINT TO LAND COMPLETION AT 8863'. -WLEG 6'INTO LINER TIE BACK SLEEVE. -MAKE UP TUBING HANGER ON LADING JOINT. -SUCK OUT STACK -LAND 4.5"COMPLETION. 23 30 - 00:00 0.50 RUNCOM P RUNCMP RUN IN LOCK DOWN SCREWS ON TUBING HANGER AND RIG DOWN DOYON CASING. 4/22/201300:00 - 01:00I 1.00 RUNCOM P RUNCMP RIG UP FOR DISPLACEMENT. ----1- I -PRE-JOB. Printed 6/24/2013 1:22 33PM North America-ALASKA-BP Page 5 of 6 Operation Summary Report Common Well Name:F-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:4/18/2013 End Date:4/23/2013 X3-0128W-C:DRILL(3,180,000.00) Project Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:OOAM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UWI: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) _ Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 05:30 4.50 RUNCOM P RUNCMP SPOT IN CORROSION INHIBITOR. -REVERSE CIRCULATE 85 BBL 8.5 PPG SEAWATER -168 GPM,475 PSI. -REVERSE CIRCULATE 188 BBL 8.5 PPG CORROSION INHIBITED SEAWATER. -168 GPM,401 PSI. -REVERSE CIRCULATE 205 BBL 8.5 PPG SEAWATER -168 GPM,401 PSI. -CIRCULATE 5 BBL DOWN TUBING TO CLEAN XN NIPPLE SEAT. -DROP BALL AND ROD ASSEMBLY. 05:30 - 06:00 0.50 RUNCOM P f i RUNCMP RIG UP FOR PACKER SET AND PRESSURE TESTING. 06:00 - 07:30 1.50 RUNCOM P RUNCMP PRESSURE TEST TUBING -PRESSURE TEST TBG TO 250 PSI FOR 5 • MIN. GOOD. -PRESSURE TEST TBG TO 3500 PSI FOR 30 MIN. GOOD.' -INITIAL: 3720 PSI - —15 MIN:3660PSI -30 MIN:3640 PSI • -BLEED DOWN PRESSURE ON TBG SIDE TO 1500 PSI AND MAINTAIN FOR PACKER TEST. 07:30 - 10:30 3.00 RUNCOM N SFAL , RUNCMP PRESSURE TEST PACKER ASSEMBLY -BAD SENSATOR BLADDER,REPLACED. -BAD FITTING IN SENSATOR LINE. -PURGE AIR FROM TEST EQUIPMENT. 10:30 - 11:30 1.00 RUNCOM P RUNCMP PRESSURE PACKER ASSEMBLY. j - -PRESSURE TEST PACKER ASSEMBLY TO 250 PSI FOR 5 MIN. GOOD. -PRESSURE TEST PACKER ASSEMBLY TO 3500 PSI FOR 30 MIN. GOOD. -VOLUME PUMPED FOR TEST,8.5 BBL -VOLUME BLED BACK,8.5 BBL. 11:30 - 12:30 1.00 RUNCOM P RUNCMP MONITOR WELL. STATIC. -R/U T-BAR AND TWO WAY CHECK VALVE WHILE MONITORING WELL. 12:30 - 13:00 0.50 RUNCOM P RUNCMP ,SHEAR DCK VALVE. -PRESSURE UP IA TO 2850 PSI TO SHEAR. -REVERSE CIRCULATE,168 GPM 650 PSI. -CIRCULATE DOWN TUBING,168 GPM 800 PSI. 13:00 - 15:00 2.00 WHSUR P RUNCMP INSTALL AND TEST TWC. -TEST FROM ABOVE -TEST LOW,250 PSI 5 MIN. -TEST HIGH,3500 PSI 5 MIN. -TEST FROM BELOW -TEST LOW,250 PSI 5 MIN. -TEST HIGH,2000 PSI 30 MIN. 15:00 - 16:30 1.50 BOPSUR P RUNCMP BLOW DOWN,RIG DOWN. -RIG DOWN TEST EQUIPMENT. -BLOW DOWN CHOKE,KILL,2ND KILL. -PUMP OUT BOP STACK 16:30 - 21:00 4.50 BOPSUR P RUNCMP NIPPLE DOWN BOP EQUIPMENT. -LAY DOWN FLOW RISER -NIPPLE DOWN STACK AND RISERS. -LAY DOWN MOUSEHOLE. Printed 6/24/2013 1:22:33PM North America-ALASKA-BP Page 6 of Operation Summary Report Common Well Name:F-13 AFE No Event Type:COM-ONSHORE(CON) Start Date:4/18/2013 End Date:4/23/2013 X3-0128W-C:DRILL(3,180,000.00) Project:Prudhoe Bay Site:PB F Pad Rig Name/No.:PARKER 272 Spud Date/Time:2/5/1980 12:00:00AM Rig Release:4/23/2013 Rig Contractor:PARKER DRILLING CO. UW: Active datum:F-13B plan P272 @81.55usft(above Mean Sea Level) Date From-To ' Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 23:30 2.50 WHSUR P RUNCMP NIPPLE UP TREE I -NIPPLE UP TREE ADAPTER -NIPPLE UP TREE. '23:30 - 00:00 0.50 WHSUR P RUNCMP RIG UP TO PULL TWO WAY CHECK. -PICK UP LUBRICATOR. 4/23/2013 '00:00 - 00:30 0.50 WHSUR N WAIT RUNCMP WAIT ON PUMP IN ADAPTER FOR OTIS CONNECTION. 00:30 - 01:30 1.00 WHSUR P RUNCMP I FINISH NIPPLING UP DRY-HOLE TREE. 01:30 - 02:30 1.00 WHSUR P RUNCMP TEST ADAPTER FLANGE. -LOW 250 PSI,5 MIN. -HIGH 5000 PSI,30 MIN. 02:30 - 04:00 1.50 WHSUR P RUNCMP TEST DRY-HOLE TREE. I 1 -LOW 250 PSI,5 MIN. -HIGH 5000 PSI,10 MIN 04:00 - 05:30 1.50 1 WHSUR P i RUNCMP RIG UP AND TEST LUBRICATOR. -LOW 250 PSI,5 MIN. -HIGH 3500 PSI,10 MIN. REMOVE BPV. 05:30 - 06:00 0.50 WHSUR P IRUNCMP RIG UP FOR FREEZE PROTECT. 06:00 - 09:30 3.50 WHSUR P RUNCMP PUMP FREEZE PROTECT. REVERSE CIRCULATE 151 BBL DIESEL AT 4 BPM. 09:30 - 10:30 1.qo WHSUR P . RUNCMP U-TUBE. I 'ALLOW DIESEL TO U-TUBE AND EQUALIZE IN IA X TUBING. 10:30 - 13:00 2.50 WHSUR P RUNCMP RIG UP AND TEST LUBRICATOR _ -LOW 250 PSI 5 MIN -HIGH 3500 PSI 5 MIN INSTALL BPV. TEST FROM UNDER. -LOW 250 PSI 5 MIN -HIGH 2000 PSI 5 MIN 113:00 - 15:00 2.00 � WHSUR P j RUNCMP RIG DOWN -RIG DOWN LUBRICATOR. -RIG DOWN REV CIRCULATION AND U-TUBE EQUIPMENT. Printed 6/24/2013 1:22:33PM F-13B, Well History (Post Rig Sidetrack) Date Summary 05/29/13 T/I/O=0/0/0; Conduct PJSM; Start barriers list= SSV&SV,verified by independently bleeding of each valve; R/U lubricator and test against SV to 300 and 3500 psi for 5 min. LTT passed; Pull 4-1/16" CIW "H" BPV#149 through tree post Parker 272; 1-1' ext used,tagged at 114"; S/I barriers, RDMO 05/31/13 DRIFT TO TD W/RPM DRIFT, TAG TD @ 9414' SLM. S/D HIGH W/RPM TOOL, MAKE ADJUSTED LOGGING PASSES(see log for info). RIH W/2.625"CENT, 2'x1-7/8" STEM, 2.25" S. BAILER, S/D @ 9411' SLM. MAKE 2 RUNS W/8'-2.25" DRIVE DOWN BAILER TO 9,411' SLM, RECOVER TOTAL OF —2.5 GALLONS OF WET CEMENT. 06/01/13 RUN 10'-3.00" DRIVE DOWN BAILER TO 9,412' SM, MADE NO HOLE (recovered 2+gal wet cement). SET WHIDDON C SUB @ 8,813' SLM/8,850' MD. PULL RK-DGLV FROM ST#3 @ 5,895' SLM/5,925' MD. PULL RKP-SHEAR VALVE FROM ST#4 @ 3,709' SLM/3,740' MD. SET RK-LGLV(1500#TRO, 16/64" ports) IN ST#4 @ 3,709' SLM/3,740' MD. SET SET RK-OGLV(20/64" ports) IN ST#3 @ 5,895' SLM/5,925' MD. PULL WHIDDON C SUB @ 8,813' SLM/8,850' MD. 06/07/13 CTU#9 w/ 1.75" CT. Objective: Mill Cement. MIRU. RIH w/3.70"Junk Mill w/Opti-Cut(moderately aggressive), 2-7/8"X-Treme Motor, 3.16" Bowen U/D Jar. 06/08/13 CTU#9 w/ 1.75" CT. Objective: Mill Cement<<>> RIH w/3.70"Junk Mill w/Opti-Cut(moderately aggressive), 2-7/8"X-Treme Motor, 3.16" Bowen U/D Jar. Mill from 9300'to PBTD at 9568'CTM making frequent PowerVis gel sweeps and short trips. No observable motor work while milling. Set down and stall on wiper plug at PBTD multiple times. Chase OOH to surface w/24 bbl PowerVis gel sweep to surface at 80%. Pop off. ND milling BHA. Mill shows no obvious wear. Stab on w/2" SJN. Wash BOPs w/KCI. RIH to 2500'CTM. FP well at 80%w/50/50 meth. RDMO. 06/12/13 DRIFT W/20'x 3.375" DMY GUN, 2.5" SAMPLE BAILER, TAG HARD BTM @ 9,568' SLM, FLAGGED WIRE @ 9,554' SLM. RAN BAKER RPM TOOL AS PER PROGRAM (GOOD DATA). 06/12/13 INITIAL T/I/O =250/0/0 PSI. CURRENTLY RIH W/2-7/8"X 20'2906 POWERJET OMEGA HMX GUN. 06/13/13 INITIAL T/I/O = 1250/0/0. TAG TD AT 9588'. TIED INTO BKR MWD DATED 17-APRIL-2013. SHOOT INTERVAL 9520'-9540'. CCL TO TOP SHOT: 3.5'. CCL STOP DEPTH: 9516.5'. LOG JEWELRY FROM TD TO 200'. SHOOT THE INTERVAL 9500'-9520'. TOP SHOT=9500'; CCL TO TOP SHOT=3.5'; CCL STOP DEPTH =9496.5'. POOH. GUN INFO: 2-7/8"2906 PJ OMEGA HMX/6 SPF/60 DEG PHASING. FINAL T/I/O=20/0/50. Page 1 of 1 rpI BAKER HUGHES North America - ALASKA - BP Prudhoe Bay PB F Pad F-13 - Slot 13 F-13B Design: F-13B Survey Report - Geographic 26 April, 2013 Øbp ri- BAKER Survey Report-Geographic 0 by HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay TVD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13B Survey Calculation Method: Minimum Curvature Design: F-13B Database: EDM R5K-Alaska PROD-ANCP1 Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB F Pad,TR-11-13 Site Position: Northing: 5,972,527.29 usft Latitude: 70°19'55.283 N From: Map Easting: 650,960.70 usft Longitude: 148°46'31.47 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 1.15° Well F-13 API No. 500292043400 Well Position +N/-S 0.00 usft Northing: 5,974,812.00 usft Latitude: 70°20'17.552 N +E/-W 0.00 usft Easting: 651,958.00 usft Longitude: 148°46'1.00 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.60 usft Wellbore F-13B API no. 500292043402 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 2/21/2013 20 53 81.04 57,628 Design F-13B Audit Notes: Version: Phase: ACTUAL Tie On Depth: 6,616.76 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 45.66 0.00 0.00 350.93 Survey Program Date: 4/19/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 116.76 6,616.76 1 :Sperry-Sun BOSS gyro multi(F-13) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6,638.00 6,873.00 MWD(F-13B) INC+TREND Inclinometer+known azi trend 6,900.59 9,623.05 MWD 2(F-13B) MWD+IFR+MS MWD+IFR+Multi Station 4/26/2013 10:27:05AM Page 2 COMPASS 5000.1 Build 61 IN"- BAKEtlGI�IES Survey Report-Geographic0 bp HCompany: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay TVD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13B Survey Calculation Method: Minimum Curvature Design: F-13B Database: EDM R5K-Alaska PROD-ANCP1 Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting li,, (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 6,616.76 3.63 358.61 6,494.94 818.05 -124.37 5,975,627.31 651,817.09 70°20'25.598 N 148°46'4.63 W TIP 6,638.00 3.52 359.06 6,516.14 819.38 -124.39 5,975,628.63 651,817.04 70°20'25.611 N 148°46'4.63 W' KOP 6,710.57 4.42 343.48 6,588.54 824.29 -125.23 5,975,633.52 651,816.11 70°20'25.659 N 148°46'4.66 W I 6,742.63 6.41 340.68 6,620.45 827.16 -126.17 5,975,636.37 651,815.10 70°20'25.687 N 148°46'4.69 W 6,773.92 8.52 338.80 6,651.48 830.97 -127.59 5,975,640.15 651,813.61 70°20'25.725 N 148°46'4.73 W' 6,804.90 10.98 337.44 6,682.01 835.84 -129.55 5,975,644.98 651,811.55 70°20'25.773 N 148°46'4.78 W 6,841.44 13.32 336.23 6,717.72 842.90 -132.58 5,975,651.98 651,808.38 70°20'25.842 N 148°46'4.87 W 6,873.00 14.82 335.41 6,748.34 849.90 -135.72 5,975,658.91 651,805.09 70°20'25.911 N 148°46'4.97 W End Inc+Trend 6,900.59 16.64 334.83 6,774.89 856.68 -138.87 5,975,665.63 651,801.80 70°20'25.978 N 148°46'5.06 W Start MWD+IIFR+MS 6,935.98 17.83 333.52 6,808.69 866.12 -143.44 5,975,674.97 651,797.04 70°20'26.070 N 148°46'5.19 W 6,967.45 18.84 328.83 6,838.57 874.78 -148.22 5,975,683.53 651,792.09 70°20'26.156 N 148°46'5.33 W 6,994.67 20.07 322.72 6,864.23 882.26 -153.33 5,975,690.91 651,786.84 70°20'26.229 N 148°46'5.48 W 7,030.68 20.60 319.66 6,898.00 892.00 -161.17 5,975,700.49 651,778.80 70°20'26.325 N 148°46'5.71 W 7,062.33 21.94 317.30 6,927.50 900.59 -168.79 5,975,708.92 651,771.01 70°20'26.409 N 148°46'5.93 W 7,088.28 23.68 315.12 6,951.42 907.85 -175.75 5,975,716.04 651,763.90 70°20'26.481 N 148°46'6.13 W 7,183.78 24.32 314.40 7,038.66 935.20 -203.33 5,975,742.82 651,735.77 70°20'26.750 N 148°46'6.94 W 7,278.41 25.45 319.26 7,124.51 964.24 -230.53 5,975,771.30 651,708.00 70°20'27.035 N 148°46'7.73 W 7,373.16 25.20 319.79 7,210.15 995.07 -256.84 5,975,801.59 651,681.07 70°20'27.339 N 148°46'8.50 W 7,467.33 24.69 319.30 7,295.54 1,025.29 -282.61 5,975,831.28 651,654.70 70°20'27.636 N 148°46'9.26 W 7,562.30 25.34 320.14 7,381.60 1,055.93 -308.57 5,975,861.38 651,628.12 70°20'27.937 N 148°46'10.01 W 7,656.98 24.92 319.35 7,467.32 1,086.62 -334.55 5,975,891.54 651,601.53 70°20'28.239 N 148°46'10.77 W 7,751.60 24.66 319.65 7,553.22 1,116.78 -360.31 5,975,921.17 651,575.16 70°20'28.536 N 148°46'11.53 W 7,845.61 25.55 320.44 7,638.35 1,147.36 -385.92 5,975,951.22 651,548.93 70°20'28.836 N 148°46'12.27 W 7,940.37 25.39 321.01 7,723.90 1,178.91 -411.72 5,975,982.23 651,522.51 70°20'29.147 N 148°46'13.03 W 8,034.65 25.13 320.61 7,809.16 1,210.09 -437.14 5,976,012.89 651,496.46 70°20'29.453 N 148°46'13.77 W 8,129.93 24.89 321.76 7,895.51 1,241.47 -462.39 5,976,043.76 651,470.58 70°20'29.762 N 148°46'14.51 W 8,223.66 26.28 322.45 7,980.05 1,273.42 -487.25 5,976,075.19 651,445.08 70°20'30.076 N 148°46'15.23 W 8,318.04 25.84 322.20 8,064.83 1,306.23 -512.59 5,976,107.48 651,419.09 70°20'30.399 N 148°46'15.97 W 8,412.90 25.36 322.74 8,150.38 1,338.74 -537.56 5,976,139.47 651,393.47 70°20'30.718 N 148°46'16.70 W 8,508.35 24.93 323.10 8,236.78 1,371.09 -562.01 5,976,171.32 651,368.36 70°20'31.037 N 148°46'17.42 W 8,602.25 26.22 322.74 8,321.48 1,403.43 -586.45 5,976,203.16 651,343.27 70°20'31.355 N 148°46'18.13 W 8,696.89 25.84 322.57 8,406.52 1,436.45 -611.65 5,976,235.65 651,317.42 70°20'31.679 N 148°46'18.87 W 8,792.02 25.40 322.88 8,492.30 1,469.18 -636.56 5,976,267.87 651,291.85 70°20'32.001 N 148°46'19.60 W 8,886.62 24.83 322.98 8,577.96 1,501.22 -660.76 5,976,299.41 651,267.00 70°20'32.316 N 148°46'20.30 W 8,977.51 24.34 322.95 8,660.61 1,531.40 -683.54 5,976,329.12 651,243.62 70°20'32.613 N 148°46'20.97 W 9,074.19 25.51 320.22 8,748.28 1,563.30 -708.86 5,976,360.50 651,217.65 70°20'32.927 N 148°46'21.71 W 9,106.03 28.44 317.46 8,776.66 1,574.16 -718.38 5,976,371.17 651,207.92 70°20'33.034 N 148°46'21.99 W 9,137.64 31.86 315.24 8,803.99 1,585.64 -729.35 5,976,382.41 651,196.73 70°20'33.146 N 148°46'22.31 W 9,168.79 33.35 315.32 8,830.23 1,597.56 -741.16 5,976,394.10 651,184.68 70°20'33.264 N 148°46'22.65 W 9,200.45 37.10 315.46 8,856.09 1,610.56 -753.98 5,976,406.83 651,171.60 70°20'33.392 N 148°46'23.03 W 9,236.30 39.18 317.24 8,884.28 1,626.58 -769.25 5,976,422.54 651,156.00 70°20'33.549 N 148°46'23.47 W 9,268.41 39.70 318.37 8,909.08 1,641.70 -782.95 5,976,437.37 651,142.00 70°20'33.698 N 148°46'23.87 W 9,295.46 40.16 319.54 8,929.82 1,654.79 -794.35 5,976,450.23 651,130.34 70°20'33.827 N 148°46'24.21 W 9,327.22 41.77 319.73 8,953.80 1,670.66 -807.84 5,976,465.82 651,116.53 70°20'33.983 N 148°46'24.60 W 9,359.23 43.34 318.69 8,977.38 1,687.04 -821.98 5,976,481.92 651,102.06 70°20'34.144 N 148°46'25.01 W 9,390.49 44.35 318.21 8,999.93 1,703.25 -836.34 5,976,497.83 651,087.38 70°20'34.303 N 148°46'25.43 W 9,426.06 44.73 318.12 9,025.28 1,721.84 -852.98 5,976,516.07 651,070.36 70°20'34.486 N 148°46'25.92 W 9,457.84 46.09 316.42 9,047.59 1,738.46 -868.34 5,976,532.38 651,054.67 70°20'34.649 N 148°46'26.37 W 9,484.68 46.63 314.83 9,066.11 1,752.34 -881.93 5,976,545.98 651,040.81 70°20'34.786 N 148°46'26.77 W 9,579.53 46.06 315.45 9,131.59 1,800.98 -930.33 5,976,593.63 650,991.43 70°20'35.264 N 148°46'28.18 W 9,623.05 45.65 315.53 9,161.90 1,823.25 -952.23 5,976,615.45 650,969.09 70°20'35.483 N 148°46'28.82 W 4/26/2013 10:27:05AM Page 3 COMPASS 5000.1 Build 61 BAKER Survey Report-Geographic 0 by HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay TVD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B©80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13B Survey Calculation Method: Minimum Curvature Design: F-13B Database: EDM R5K-Alaska PROD-ANCP1 Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +EI-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 9680.00 45.65 315 53 9,201 71 1,852.31 -980.75 5,976,643 92 650,939.98 70°20'35.769 N 148°46'29.65 W Projection to Bit Depth 4/26/2013 10:27:05AM Page 4 COMPASS 5000.1 Build 61 BAKER HUGHES North America - ALASKA - BP Prudhoe Bay PB F Pad F-13 - Slot 13 F-13BPB1 Design: F-13BPB1 Survey Report - Geographic 26 April, 2013 Qbp BAKER Survey Report-Geographic 0 by HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay TVD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13BPB1 Survey Calculation Method: Minimum Curvature Design: F-13BPB1 Database: EDM R5K-Alaska PROD-ANCP1 Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB F Pad,TR-11-13 Site Position: Northing: 5,972,527.29 usft Latitude: 70°19'55.283 N From: Map Easting: 650,960.70 usft Longitude: 148°46'31.47 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 1.15° Well F-13 API No. 500292043400 Well Position +N/-S 0.00 usft Northing: 5,974,812.00 usft Latitude: 70°20'17.552 N, +E/-W 0.00 usft Easting: 651,958.00 usft Longitude: 148°46'1.00 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.60 usft Wellbore F-13BPB1 API no. 500292043470 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°l (nT) BGGM2012 2/21/2013 20.53 81.04 57,628 Design F-13BPB1 Audit Notes: Version: Phase: ACTUAL Tie On Depth: 7,516.76 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 45.66 0.00 0.00 351.80 Survey Program Date: 4/17/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 116.76 7,516.76 1 :Sperry-Sun BOSS gyro multi(F-13) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,576.00 7,755.00 GyroData Gyro(F-13BPB1) GYD-GC-SS Gyrodata gyro single shots 7,796.08 8,905.90 MWD(F-13BPB1) MWD+IFR+MS MWD+IFR+Multi Station 4/26/2013 10.05:42AM Page 2 COMPASS 5000.1 Build 61 FS' BAKER Survey Report-Geographic 0 bp HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay ND Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13BPB1 Survey Calculation Method: Minimum Curvature Design: F-13BPB1 Database: EDM RSK-Alaska PROD-ANCP1 Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 7,516.76 0.47 37.20 7,394.37 846.77 -122.94 5,975,656.04 651,817.93 70°20'25.880 N 148°46'4.59 W lip 7,576.00 0.28 37.64 7,453.61 847.08 -122.71 5,975,656.36 651,818.16 70°20'25.883 N 148°46'4.59 W KOP 7,599.00 1.36 34.35 7,476.60 847.35 -122.52 5,975,656.63 651,818.34 70°20'25.886 N 148°46'4.58 W 7,626.00 1.88 12.02 7,503.59 848.05 -122.25 5,975,657.33 651,818.60 70°20'25.893 N 148°46'4.57 W 7,655.00 3.39 357.68 7,532.56 849.37 -122.18 5,975,658.65 651,818.64 70°20'25.906 N 148°46'4.57 W 7,696.00 5.43 352.42 7,573.44 852.50 -122.49 5,975,661.78 651,818.27 70°20'25.936 N 148°46'4.58 W 7,726.00 7.52 350.09 7,603.25 855.84 -123.01 5,975,665.11 651,817.68 70°20'25.969 N 148°46'4.59 W 7,755.00 9.31 345.86 7,631.93 859.99 -123.91 5,975,669.24 651,816.70 70°20'26.010 N 148°46'4.62 W End Gyro 7,796.08 11.49 342.11 7,672.34 867.10 -125.98 5,975,676.31 651,814.48 70°20'26.080 N 148°46'4.68 WI Start MWD+IIFR+MS 7,827.93 12.70 332.96 7,703.48 873.24 -128.55 5,975,682.39 651,811.79 70°20'26.140 N 148°46'4.76 W 7,879.50 14.45 324.86 7,753.61 883.55 -134.83 5,975,692.58 651,805.30 70°20'26.242 N 148°46'4.94 W 7,974.43 18.05 322.09 7,844.74 904.85 -150.69 5,975,713.55 651,789.02 70°20'26.451 N 148°46'5.40 W 8,069.25 20.61 324.77 7,934.21 930.08 -169.34 5,975,738.39 651,769.86 70°20'26.699 N 148°46'5.95 W 8,164.44 22.04 329.68 8,022.88 959.18 -188.03 5,975,767.11 651,750.59 70°20'26.986 N 148°46'6.49 W 8,259.56 24.78 332.34 8,110.17 992.25 -206.29 5,975,799.80 651,731.66 70°20'27.311 N 148°46'7.03 W 8,353.49 27.40 332.58 8,194.52 1,028.88 -225.39 5,975,836.03 651,711.82 70°20'27.671 N 148°46'7.58 W 8,447.62 29.79 328.93 8,277.17 1,068.14 -247.44 5,975,874.83 651,688.99 70°20'28.057 N 148°46'8.23 W 8,542.22 31.19 329.13 8,358.69 1,109.30 -272.13 5,975,915.47 651,663.46 70°20'28.462 N 148°46'8.95 W 8,636.91 35.18 328.90 8,437.92 1,153.72 -298.81 5,975,959.34 651,635.89 70°20'28.899 N 148°46'9.73 W 8,674.03 37.76 328.16 8,467.76 1,172.53 -310.34 5,975,977.92 651,623.99 70°20'29.084 N 148°46'10.07 W 8,705.53 40.15 327.85 8,492.26 1,189.33 -320.83 5,975,994.49 651,613.16 70°20'29.249 N 148°46'10.37 W 8,731.68 41.73 326.20 8,512.01 1,203.70 -330.16 5,976,008.67 651,603.54 70°20'29.390 N 148°46'10.65 W 8,827.17 44.54 324.70 8,581.69 1,257.45 -367.20 5,976,061.66 651,565.42 70°20'29.919 N 148°46'11.73 W 8,905.90 45.40 322.30 8,637.39 1,302.17 -400.30 5,976,105.69 651,531.43 70°20'30.359 N 148°46'12.69 W 9,071.00 45.40 322.30 8,753.32 1,395.18 -472.18 5,976,197.22 651,457.68 70°20'31.274 N 148°46'14.79 W Projection to Bit Depth 4/26/2013 10:05:42AM Page 3 COMPASS 5000.1 Build 61 Fr BAKER Survey Report-Geographic bp HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well F-13-Slot 13 Project: Prudhoe Bay TVD Reference: F-13B©80.26usft(Parker 272(45.66ft RT-BF)) Site: PB F Pad MD Reference: F-13B @ 80.26usft(Parker 272(45.66ft RT-BF)) Well: F-13 North Reference: True Wellbore: F-13BPB1 Survey Calculation Method: Minimum Curvature Design: F-13BPB1 Database: EDM R5K-Alaska PROD-ANCP1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 8,956.71 8,673.07 DRILLING LINER 1 7.000 8.500 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (1 6,111.71 5,992.76 CM3 7,813.71 7,689.59 KINGAK 8,958.71 8,674.47 SAG RIVER Design Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) (usft) (usft) Comment 7,516.76 7,394.37 846.77 -122.94 TIP 7,576.00 7,453.61 847.08 -122.71 KOP 7,755.00 7,631.93 859.99 -123.91 End Gyro 7,796.08 7,672.34 867.10 -125.98 Start MWD+IIFR+MS 9,071.00 8,753.32 1,395.18 -472.18 Projection to Bit Depth Checked By: Approved By: Date: 4/26/2013 10:05:42AM Page 4 COMPASS 5000.1 Build 61 by " 0_, N ., -' - ' .„ k.-.I Date:06/20/2013 0 . „ . Transmittal Number:93295 L.IJ BPXA WELL DATA TRANSMITTAL .... RANSMITTAL ` ! _ L) 1 AOGCC: Makana Bender 7 Enclosed are the materials listed below. '').' 9 5 1 If you have any questions,please contact BreAnne Hovley: 907-564-5349 or breanne.hovley@bp.com Color Well Name Date Company Log Description Prints CD Baker 15-17 2/15/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker 01-20 4/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker F-06A 4/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker L5-23 4/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D, 1 1 Baker 06-02B 4/19/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker B-27B 5/8/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker 15-34A 6/10/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker Z-08A 6/10/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker Z-05 6/11/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 , 911 1 Baker I F-13B 6/13/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 Baker 15-29B 6/17/13 Hughes RESERVOIR PERFORMANCE MONITOR PNC 3D 1 1 C'SI Please 'gn and Re one cy of this transmittal. 4-At, J le)/e4o, ,. . Thank You, Bre.Ylnne 3Covley Petrotechnical Data Center Petrotechnical Data Center LR2-1 900 E.Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 RECEIVED Mail to: Paper Log CD MAY 3 1 2013 ConocoPhillips Alaska Inc. Attn: Ricky Elgaricio AOGCC PO Box 100360 Anchorage, Ak 99510 0 1 t 3 0 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 R�o Anchorage, AK 99503 1 1 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 1 1 DNR - Division of Oil & Gas *** Attn: Sean Clifton 550 West 7th Avenue, Suite 802 Anchorage, Alaska 99501 0 1 Baker Hughes !!ic Attn: Sachin Gandra 795E 94th Avenue, Anchorage, Alaska 99515 0 1 Total 2 5 Pgct PN) za.zW-Io STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report • Submit to: jim.reaga,alaska.gov AOGCC.Inspectors(a alaska.gov phoebe.brooksa,alaska.gov Contractor: Parker Rig No.: 272 DATE: 4/20/13 Rig Rep.: Kelly Burson Rig Phone: 907-659-8378 Rig Fax: Operator: BP Op. Phone: 907-659-8378 Op. Fax: Rep.: Chris Weaver E-Mail rig272srmgr@parkerdrilling.com Well Name: PBU F-13B PTD# 2121410 Operation: DrIg: X Workover: Explor.: Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 - Valves: 250/3500 - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P - Well Sign P Upper Kelly 1 P - Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P . Hazard Sec. P - Ball Type 3 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P • P Annular Preventer 1 13 3/8 P - Pit Level Indicators P P - #1 Rams 1 2 7/8 x 5 1/2 P - Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P - P #3 Rams 1 2 7/8 x 5 1/2 P - H2S Gas Detector P - P - #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8 P Inside Reel valves 0 NA HCR Valves 2 3 1/8 P - Kill Line Valves _ 2 3 1/8, 2 1/8 P - Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2950 P CHOKE MANIFOLD: Pressure After Closure 1800 P Quantity Test Result 200 psi Attained 22 P No. Valves 15 - P ' Full Pressure Attained 91 P . Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P • Nitgn. Bottles (avg): 14 ea. 2100 psi CH Misc 0 NA ACC Misc NA Test Results Number of Failures: 0 Test Time: 9.5 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Test with 4"&4 1/2"test joints, 3 ball type safety valves, (2) HT-38, (1) NC-50. Function all components from LER, Rig Managers office and Koomey Unit, All test Pass. Had problem with relief valve on test pump 24 HOUR NOTICE GIVEN YES X NO Waived By Bob Noble Date 4/18/13 Time 1500 hrs Witness Test start 4/19/13 Finish 4/20/13 (sForf(5- Form m 10-424 (Revised 03/2013) Parker 272 BOP Test 4-12-13 (2).xls Pepi& F-136 Pryer- /Z\1 Z7 2 apee- esr 4 kIi3 • P 7-It.-14,0 A5µ l yK / 30M. ,• fr / /--- 1110, 0,00410•: allillitift A0000.4°. 1°1° 0 Ailt ,4\kito44 s4, , i / ..... •,N, ,•,‘N`.•>"-‘‘ ,- ,�. � �'0,,f , 7 ,/ice- �%.. .'' iii% , -;!, 4 74,:, 00,......fter,.. ..,,,.%.A'k•., 4sN. ... ‘A 1 it 44,\ .. \ •*:1•1-r----E":"70.0.. % \ N.,,k . \%\\ thy ..,-.,\;>,, , ‘.. �./ ��� � .,/ .��000.4.1.0** .);�'' �� ' 0 , ,, , f: thillitett lig 4.-y- •.„ wit,...E.4# • •- 4,,,\ N. , ,1 th 4161044114,4 / ...;. •, oto , \ Ni \Aix r �t* ` 111 oto .� �•� ..��. »� 1111111111 11111011011111110171114/1111011111111111111#10.111"7 ,01tfint"1111111 � e��. N ,�`i�,���ii1111111111����Y RINANIIIIIIIIIIII� ��� IIt,t " VA 1\\VII% I Ill�il i � _ i 11I� II10-Att*VallititialtX-1-).. 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IA"a35M000.44/10 0/ Ill%Pl\iiiwar,414111111146Lsialak .OM _. yo"), 4> N ,,,, ,4%• ,-iift.*rare--.--%.---r...--.. °°. 0;,e// ,IN:, 4.4.. ..... .......7.....=:".. .! 0,11:1_,_,J01....- __ Ht- r5 Z/4, A3(/1f-13� P - 27 a_ A1C- T- `F,Zoi • Pn 2111410 45 M. ,,, 0,e.goiOoOo ,11""I''''', „„, 1 Al -1 ••••••••m am...0.....fttpolifi / 0,01 •••••••~.................,=: _____ 41 --) ,j0.4$°;*>4 106=00,...WW--"Am..."....4.444ki&44b44444,4 . f./ if"cerd .07,01.Zare=Uriftrim , /' ,41.0°I.:°glaFX:04, \ ai, i //60# *IsSiff.44- 4 .1' '' ' !IL,, if fifP 6601;000E0041** '‘'. -41` 1c,‘ ,\\V tittike4144,*-0 sr gw.1.4:204%; . \ \\ A �, f 1 • ♦ .�. � ♦ o �� �\®,. .�r�.I ro � I r s ��� ,,kwitigito/ , 1 Il I�i� �� j t� k. .A. a� 1�\\1����t�,� �� 11 ri j, ,, � . .. .... , 111111 111 1��r ��� ,,, ... ; ,,. 11111 .%°:/ II Fr. 4, kt\••.. % \ ‘. Itl► 1�rr� �,, . � ..�.,�'�i�iit�ititt� ��Ill A 111111111111111#4101#44 III Nir �� Ott W ..,�,Z �a I �� „'�� ��� � oit �� _ ��� i�\ ISAi\ IIImIfIL ���� �, .. . �� Wa , „ , SII III , Ilt..i^ �_ a )9.81/41/111101111111111111111111101111111111t� II��II�( f � ��� ,.��,� doIr� l�t►tttt�tttt�� .� o}�. � !�II1 � /1 IttlISSI"”" t ..I%.%, \\ ;•*NIA re /. , I�i ` r ��i �,�.� , !y , 1 tl SI ill.411/*/#i:90 ///// . NV:\\\�\��1 . OOSall iG � //f/4# lir�z `\\\.%\ `` •.41m..-1,1_80 �`mow_+iN. S'', gOr/L /1"/hi ,1 \ ‘.\\\.N. ‘,.• *. 4. /.0,/A7, / i 4', `-_,' -.,4* `mow 7 • -..+!' r i4..,/- A , ,.. ......--17.--- -..- ,......i-l&w.L....-....%,;;/_„0, , 1 •...._._..__._________.. am gr-wmw- , w sr P6L( PDS ZI7.14I0 ACCUMULATOR SYSTEM TEST 1.Record Accumulator pressure. 2.Turn Electric and Air pump off. 3.Close all manual valves at Accumulator(DO NOT CLOSE THE BLIND RAMS) At this time record the pressure in the back up nitrogen bottles.Record the bottle pressure average. 4.Record Accumulator Pressure. 5.Start Electric pump and stop watch. 6. When a 200 psi increase on the Accumulator is reached,Record the time it took then start the Air Pump. 7.When the pumps shut off and the Accumulator is at the final PSI Record the time. Accumulator System Test Date: 4-20-13 Well# F-13B 1.Record Accumulator PSI t 4 S-17 2.Turn off Elec.&Air pumps 3.Close(Not Blinds) Valves.(CK Nitrogen) 4.Record Accumulator PSI /8 0 0 5.Start stop watch and Elect. Pump 6.Time @ 200 PSI gain. Start air pump 3 7.Time @ final PSI 4 1 Back Up Bottles Bottle#1 1700 Bottle#8 Ira c Bottle#2 2 2 o o Bottle#9 2 i o Bottle#3 Z 2 o• Bottle#10 Z 0 0 Bottle#4 c u Bottle#11 2 8 0 0 Bottle#5 Z l o c Bottle#12 2, too Bottle#6 2i o o Bottle#13 ?2 to Bottle#7 1 Z ea Bottle#14 'Z, r D 0 Bottle Pressure Average= Z /0 co Pau -i2g 13)21214(0 Parker rig 272 BOPE Test Order 04-20-13 Closing Times for BOP Components: Annular Preventer= 7 sec. Upper Pipe rams = /7 sec. Blind/Shear rams = a4 sec. Lower Pipe Rams = / , sec. - HCR Choke = / sec. - HCR Kill = / sec. Accumulator Test: Time/Pressure System Pressure = p fro psi Pressure after Closure = /f00 psi 200 psi Attained = sec. • Full Pressure Attained = 4,/ sec. ' Nitrogen Bottle Average=14ea.= AI00 asi Average Electric pump kick on pressure = ,7$D psi Electric pump kick off pressure = "S. psi Air pump kick on pressure = ,o .3.)--b psi Air pump kick off pressure = „.g5t, psi • W6!lit /f /?77, 2JZ- (4 I Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Friday, March 29, 2013 2:05 PM To: 'Lastufka, Joseph N' Subject: RE: F-13B Revised Wellplan(PTD 212-141) Joe, You have verbal approval to proceed with this revised well plan. Please submit a 10-403: Change of Approved Program as soon as possible. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria ferquson(a�alaska.gov From: Lastufka,Joseph N [mailto:Joseph.Lastufka©bp.coml Sent: Friday, March 29, 2013 1:22 PM To: Ferguson, Victoria L(DOA) Subject: FW: F-13B Revised Wellplan Victoria, Please look over the wellplan and let me know if you have any questions. As soon as I have your verbal approval, I will send the 10-403 over. Thanks! Joe From: Mammadov, Famil Sent: Friday, March 29, 2013 1:20 PM To: Lastufka, Joseph N Subject: F-13B Revised Wellplan Joe, Please find attached Well Plan for F-13B well Regards Famil Mammadov 1 P7.1 Regg, James B (DOA) Z(Z-14(0 From: Rig 272 Senior Manager[rig272srmgr@parkerdrilling.com] Sent: Thursday, March 28, 2013 6:45 PM To: 272 WSL; DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Lynda Bolling; Brooks, Phoebe L (DOA) Cc: AADU Tech Limit Engineer; Moore, Chelsi Subject: Parker Drilling 272 BOP Test 3-28-13 Attachments: Accumulator system test 3-28-13.pdf; Parker 272 test chart 3-28-13.pdf; Parker 272 BOP Test 3-27-13.xls; Parker 272 3-27-13 BOPE Test order.docx; ATT00001.txt Please see attached BOP test documentation for Parker Rig 272. Bop Test 3-28-13. Regards, David Johnston JR.Rig Manager AADU Rig 272 Parker Drilling Prudhoe Bay,AK.99743 Office (907)659-8378 hi PARKER ©RILMJNO COMPANY 1 leiNiter z7z -F- ,3� Pi-12-1-2-1410 3/V6/13 I MR p5 M•rio, „ 30 fir' t ' `!S \\ /.;044g0 ' *11';*. '.,44 N' 1 -;1'$ 4S . ,• . \\ //a�I lA 1/'��ow ` s, N„, .S err` '40 ix :....... .. III/1 4043, �At ����I �; � �•. S1 /,,,/, 73,4 \ ".off; �� \1e��� 1� i 4 ihalli \e” -." 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Close: Choke#1, 2, 3, 4 & 15, K#4, dart 4" valve, & Annular Preventer. Open: Everything else. 2. Close: Choke#5 & 6, HCR Kill, HT-38 FOSV#1, & Upper 2 7/8" x 5 1/2" VBR Pipe rams. Open: Choke#2, K#4,Annular Preventer, &4" Dart Valve 3. Close: Choke#7, 8 &9, & Manual Kill. Open: Choke#5 & 6, & HCR Kill. Rig down 4" Dart & HT-38 FOSV #1; then rig up and fill, HT-38 FOSV#2, &Topdrive 4. Close: Choke#10, 11 & 12, &Topdrive Upper IBOP. Open: Choke#7, 8 &9 5. Close: Choke#13, & Topdrive Lower IBOP. Open: Choke#12, &Topdrive upper IBOP. 6. Close: Choke#14, & HT-38 FOSV#2. Open: Choke#13, &Topdrive Lower IBOP 7. Close: Super Choke "A" and manual choke "B". 1500psi. Open: Choke#10. Open choke#14. 8. Close: HCR Choke. Open: Choke super choke "A" Manual Choke "B". 9. Close: Manual Choke Open: HCR Choke 10. Close: Lower 2 7/8" x 5 1/2" VBR Pipe rams. Open: Upper 2 7/8" x 5 1/2" VBR Pipe rams. Function tested all BOP Components from secondary remote panel located in Rig Managers office. Ensure Test Joint,is out of hole when functioning Blind/Shear Rams 11. Close: Blind/Shear rams, Choke#10, 11 & 14. R/U test hose to top of choke manifold above#15. Open: Choke#15, & Manual Choke. • Parker rig 272 p' ?'Z«io BOPE Test Order 03-28-13 Closing Times for BOP Components: Annular Preventer= 35 sec. Upper Pipe rams = 16 sec. Blind/Shear rams = 30 sec. Lower Pipe Rams = 20 sec. HCR Choke = 2 sec. HCR Kill = 2 sec. Accumulator Test: Time/Pressure System Pressure = 2950 psi Pressure after Closure = 1780 psi 200 psi Attained = 29 sec. Full Pressure Attained = 109 sec. Nitrogen Bottle Average = 14ea. = 2052 psi Average Electric pump kick on pressure = 2650 psi Electric pump kick off pressure = 3000 psi Air pump kick on pressure = 2350 psi Air pump kick off pressure = 2850 psi F-i 3i3 z1z14-10 3-2-1- /3 ACCUMULATOR SYSTEM TEST 1. Record Accumulator pressure. 2.Turn Electric and Air pump off. 3. Close all manual valves at Accumulator i, < t ' : / At this time record the pressure in the back up nitrogen bottles. Record the bottle pressure average. 4. Record Accumulator Pressure. 5. Start Electric pump and stop watch. 6.When a 200 psi increase on the Accumulator is reached,Record the time it took then start the Air Pump. 7. When the pumps shut off and the Accumulator is at the final PSI Record the time. Accumulator System Test Date: 3-27-13 Well# F-13B 1. Record Accumulator PSI 0,2 9 co 2. Turn off Elec. & Air pumps 3. Close(Not Blinds) Valves. (CK Nitrogen) ✓ 4. Record Accumulator PSI /leo 5. Start stop watch and Elect. Pump - 6.Time @ 200 PSI gain. Start air pump ;y g cce-c 7.Time @ final PSI / 5'0 Se Back Up Bottles Bottle#1 /t{5-6 Bottle#8 20 rtzi Bottle#2 2.00o Bottle#9 21.43 Bottle#3 2.24'" Bottle#10 21 o 0 Bottle#4 42 (o o Bottle#11 L o?s' Bottle#5 2„2.0 o Bottle#12 2/co Bottle#6 .g c-o Bottle#13 .i o.o Bottle#7 2.4 o Bottle#14 7 60 Bottle Pressure Average= b SI .-7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim.regq(c�alaska.gov AOGCC.Inspectors(a�alaska.gov phoebe.brooksna alaska.gov Contractor: Parker _ Rig No.: 272 DATE: 3/28/13 Rig Rep.: David Johnston Rig Phone: 907-659-8378 Rig Fax: Operator: BP Op. Phone: 907-659-8378 Op. Fax: Rep.: Brett Anderson E-Mail rig272srmgr©parkerdrilling.com Well Name: PBU F-13B PTD# 2121410 - Operation: DrIg: X Workover: Explor.: Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: 250/3500 • Annular: 250/3500 - Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P • Well Sign P Upper Kelly 1 P Housekeeping: P • Drl. Rig P - Lower Kelly 1 P PTD On Location P - Hazard Sec. P _ Ball Type 2 P Standing Order Posted P Misc NA Inside BOP 1 P . FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P • P - Annular Preventer 1 13 3/8 P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5 1/2 P " Flow Indicator P P #2 Rams 1 Blind/Shear P • Meth Gas Detector P - P #3 Rams 1 2 7/8 x 5 1/2 P . H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8 P • Inside Reel valves 0 NA HCR Valves 2 3 1/8 P - Kill Line Valves 2 3 1/8, 2 1/8 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 2950 • P • CHOKE MANIFOLD: Pressure After Closure 1780 ' P Quantity Test Result 200 psi Attained 29 " P No. Valves 15 P • Full Pressure Attained 109 . P • Manual Chokes 1 P Blind Switch Covers: All stations Yes . Hydraulic Chokes 1 P • Nitgn. Bottles (avg): 14 ea. 2052 psi CH Misc 0 NA ACC Misc NA Test Results Number of Failures: 0 " Test Time: 6.0 - Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Test with 4"test joints, Function all components from LER, Rig Managers office and Koomey Unit, All test Pass 24 HOUR NOTICE GIVEN YES X NO - Waived By Lou Grimaldi Date 3/26/13 Time 1800 hrs Witness Test start 3/28/13 0001 'Finish 3/28/13 0600 Form 10-424 (Revised 03/2013) Parker 272 BOP Test 3-27-13.xls PrD2,2 -/4 ) Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Tuesday, February 19, 2013 3:51 PM To: 'Mammadov, Famil' Cc: Regg, James B(DOA) Subject: RE: BOP Pressure Test on Parker 272; F-13B(PTD 212-141) Famil, Thank you for the stump test procedure. We have reviewed the procedure and you have approval to perform the first BOPE pressure test to 5000 psi on the stump. Please document on the BOP test report that a stump test to 5000 psi has been performed. Also note that the 3500 psi BOP test is required on Well F-13B once rigged up on the wellhead and on a 7-day test cycle as indicated in the PTD. Thanx, Victoria From: Mammadov, Famil f mailto:famil.mammadov@bp.com] Sent: Monday, February 18, 2013 6:54 AM To: Ferguson,Victoria L(DOA) Subject: RE: BOP Pressure Test on Parker 272; F-13B(PTD 212-141) Victoria, Please find attached. Regards Famil From: Ferguson, Victoria L(DOA)fmailto:victoria.ferguson@alaska.govl Sent: Friday, February 15, 2013 2:15 PM To: Mammadov, Famil Cc: Schwartz, Guy L(DOA); Regg, James B(DOA) Subject: RE: BOP Pressure Test on Parker 272; F-13B(PTD 212-141) Famil, Could you please send a procedure for the BOP stump test? Thanx, Victoria From: Ferguson, Victoria L (DOA) Sent: Friday, February 15, 2013 12:51 PM To: 'famil.mammadov@bp.com' Cc: Schwartz, Guy L (DOA); Regg,James B (DOA) Subject: BOP Pressure Test on Parker 272; F-13B(PTD 212-141) Famil, 1 You have approval to perform the first BOPE pressure test to 5000 psi on the stump. Please document on the BOP test report that a stump test to 5000 psi has been performed. Also note that the 3500 psi BOP test is required on Well F-13B on a 7-day test cycle as indicated on the PTD. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 victoria_ferquson o(�alaska qov From: Schwartz, Guy L(DOA) Sent: Friday, February 15, 2013 11:15 AM To: Ferguson, Victoria L(DOA) Subject: RN: BOP Pressure Test on Parker 272 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Mammadov, Famil [maiito:famil.mammadov©bp.com] Sent: Friday, February 15, 2013 10:07 AM To: Schwartz, Guy L(DOA) Subject: RE: BOP Pressure Test on Parker 272 Guy, Can you please confirm if we are allowed to perform the first BOPE pressure test to 5,000 psi on the stump instead of over the well? Ideally,we would like to avoid exposing any wellhead equipment to maximum pressure rating of 5K. We will be testing BOPE to 3,500 psi on 7 day cycle once we rig up over the first well. Regards Famil From: Schwartz, Guy L(DOA) [mailto:guy.schwartz_@alaska.gov] Sent:Thursday, February 07, 2013 9:13 AM To: Mammadov, Famil Subject: RE: BOP Pressure Test on Parker 272 Famil, The BOP test pressure (5000 psi) refers only to the BOP ram test. The annular need only be tested to 50% of its working pressure or 2500 psi per 20 AAC 25.035 (e)(10(A) Guy Schwartz Senior Petroleum Engineer AOGCC 2 793-1226 (office) 444-3433 (cell) From: Mammadov, Famil [mailto:famil.mammadov(abp.com] Sent: Thursday, February 07, 2013 8:58 AM To: Schwartz, Guy L(DOA) Subject: FW: BOP Pressure Test on Parker 272 Guy, The permit to drill for F-13B was there was a comment from you that the BOPE needs to be tested to 5,000 psi. Normally, we try to avoid testing the annular preventer to the pressures in excess of 3,500-4,000 psi. All other BOP equipment will be tested to 5,000 psi. Can you please advise if we can limit test value for the annular preventer to 4,000 psi? Regards Famil From: AK, D&C Rig 272 Well Site Leader Sent: Wednesday, February 06, 2013 5:58 PM To: Mammadov, Famil Cc: Wurdeman, Larry(PRA) Subject: RE: BOP Pressure Test on Parker 272 Hello Famil, Sorry I missed you earlier. Parker would prefer to test the bag to no more than 4000 psi. Sincerely, Doug From: Mammadov, Famil Sent: Wednesday, February 06, 2013 10:13 AM To: AK, D&C Rig 272 Well Site Leader Cc: Wurdeman, Larry(PRA) Subject: BOP Pressure Test on Parker 272 Larry, AOGCC requested that the first BOP test that we will perform should tested to 5,000 psi. I outlined in the plan that it will be tested to 5,000 psi on stump with AOGCC witness on rig. Can you please confirm with Parker if we can actually test the annular preventer to the value of 5000 psi? Regards Famil Mammadov GWO I BP Alaska I Drilling Engineer--NWE Rotary I Mobile:+1 (907)306 7739 I Office:+1 (907)564 4135 email:famil.mammadovcEi bp.com 3 Schwartz, Guy L (DOA) From: Regg,James B (DOA) Sent: Tuesday, February 26, 2013 1:08 PM To: Schwartz, Guy L(DOA); Ferguson, Victoria L(DOA); DOA AOGCC Prudhoe Bay Subject: FW: Parker 272 and 272 accumulator system tests... Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-7934236 From: Daniel, Ryan [mailto:f*yan.Daniel Abp_com] Sent: Tuesday, February 26, 2013 1:03 PM To: Regg, James B (DOA) Cc: Bill, Michael L(Natchiq) Subject: Parker 272 and 272 accumulator system tests... Hello Jim, I have the current information for both rigs now.Technically speaking the pressure switch assemblies engineered by NOV and used in the new Parker rigs are designed to provide more consistent switching. However the design of the switch precludes individual upper and lower adjustable set points(older rigs have these).These new switches have a single set point and a mechanical spring that controls the operating range. Parker can only adjust operating point,while holding the range.The consequence being the upper limit(off) point is pushed above 3000psi working pressure if the lower setpoint is raised.This is demonstrated in the data below. In addition, it is recognized that the secondary(Air)system requires a lower set point then the primary(electric) system to prevent needless pump cycling. Summary Both rig systems are compliant with the current language in API RP 53 in my opinion.Agreed, initially P273 was too low at 1900psi switch-on for the air system.The use of language such as"approximately"90%,and not differentiating between Primary and Secondary systems (until Standard 53 is implement in the Regulations) means this is subjective. Importantly,and demonstrated by the data below again which we can re test and have AOGCC witness demonstrates that the BOP Accumulator systems are 100%operational and safe. Points to discuss at 2pm • The real question pending is the interpretation of language in the current API RP 53 pertaining to the secondary pump switch on point(which is not specified),and any operating"risk"this poses to continued rig operations. • BP and Parker have raised the issue with the OEM vendor, NOV.An engineering solution to provide independent upper and lower set points for the new systems has been requested.This will take time to approve, MoC and implement. 1 .• Determination whether a letter seeking variance from the language in API RP 53 clause 12.4.5 to define the word" approximately" 90%for the secondary system is required. My opinion is that having the secondary system at 78-80%meets the intent of approximately,with the primary system being 90%. Thanks and Rgds Ryan Rig Parker 272 Pressure set %of WP comments points Electric Pump 2700 switch on 90% (Primary) 2950 switch off 98% Air Pump 2400 switch on 80% Initially 2400, Rig (Secondary have since increased this set point to 2650 but it has raised the stop point to 3150. Recommend leaving it at 2400 2950 Switch off 98% Rig Parker 273 Pressure set %of WP comments points Electric Pump 2825 switch on 94% (Primary) 3100 switch off 103% Air Pump 2350 switch on 78% Initially 1900, (Secondary adjusted by rig post 2/19 test 3000 switch off 100% WO Alaska Region Wells Integrity and Compliance BP Exploration Alaska 900 E Benson Blvd Anchorage Alaska Tel +1 907 564 54M 2 Mo't +1 907 748 1140 ryan danieI by corn 3 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Friday, February 15, 2013 12:51 PM To: 'famil.mammadov@bp.com' Cc: Schwartz, Guy L(DOA); Regg, James B (DOA) Subject: BOP Pressure Test on Parker 272; F-13B(PTD 212-141) Famil, You have approval to perform the first BOPE pressure test to 5000 psi on the stump. Please document on the BOP test report that a stump test to 5000 psi has been performed. Also note that the 3500 psi BOP test is required on Well F-13B on a 7-day test cycle as indicated on the PTD. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria ferquson(a�alaska qov From: Schwartz, Guy L(DOA) Sent: Friday, February 15, 2013 11:15 AM To: Ferguson, Victoria L(DOA) Subject: FW: BOP Pressure Test on Parker 272 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Mammadov, Famil f mailto:famil.mammadov@bp.com] Sent: Friday, February 15, 2013 10:07 AM To: Schwartz, Guy L(DOA) Subject: RE: BOP Pressure Test on Parker 272 Guy, Can you please confirm if we are allowed to perform the first BOPE pressure test to 5,000 psi on the stump instead of over the well? Ideally, we would like to avoid exposing any wellhead equipment to maximum pressure rating of 5K. We will be testing BOPE to 3,500 psi on 7 day cycle once we rig up over the first well. Regards Famil 1 From: Schwartz, Guy L(DOA)f mailto:guy.schwartz()alaska.govl Sent: Thursday, February 07, 2013 9:13 AM To: Mammadov, Famil Subject: RE: BOP Pressure Test on Parker 272 Famil, The BOP test pressure (5000 psi) refers only to the BOP ram test. The annular need only be tested to 50% of its working pressure or 2500 psi per 20 MC 25.035 (e)(10(A) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Mammadov, Famil [mailto:famil.mammadov@bp.com] Sent: Thursday, February 07, 2013 8:58 AM To: Schwartz, Guy L(DOA) Subject: FW: BOP Pressure Test on Parker 272 Guy, The permit to drill for F-13B was there was a comment from you that the BOPE needs to be tested to 5,000 psi. Normally,we try to avoid testing the annular preventer to the pressures in excess of 3,500-4,000 psi. All other BOP equipment will be tested to 5,000 psi. Can you please advise if we can limit test value for the annular preventer to 4,000 psi? Regards Famil From: AK, D&C Rig 272 Well Site Leader Sent: Wednesday, February 06, 2013 5:58 PM To: Mammadov, Famil Cc: Wurdeman, Larry (PRA) Subject: RE: BOP Pressure Test on Parker 272 Hello Famil, Sorry I missed you earlier. Parker would prefer to test the bag to no more than 4000 psi. Sincerely, Doug From: Mammadov, Famil Sent: Wednesday, February 06, 2013 10:13 AM To: AK, D&C Rig 272 Well Site Leader Cc: Wurdeman, Larry(PRA) Subject: BOP Pressure Test on Parker 272 Larry, AOGCC requested that the first BOP test that we will perform should tested to 5,000 psi. I outlined in the plan that it will be tested to 5,000 psi on stump with AOGCC witness on rig. 2 • Can you please confirm with Parker if we can actually test the annular preventer to the value of 5000 psi? Regards Famil Mammadov GWO I BP Alaska I Drilling Engineer—NWE Rotary I Mobile:+1(907)306 7739 I Office:+1(907)564 4135 email:famil.mammadov(ii)bp.com 3 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, February 04, 2013 9:52 AM To: 'Mammadov, Famil' Subject: RE: F-13B Well BOP Test Cycle ( PTD 212-141) Famil, Change to FIT of 11.6 ppg is approved ... I will update well file and place this email as documentation. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Mammadov, Famil [mailto:famil.mammadov@bp.com] Sent: Monday, February 04, 2013 9:45 AM To: Schwartz, Guy L(DOA) Subject: RE: F-13B Well BOP Test Cycle Guy, Thanks for quick response. I was just going over the drilling program for F-13B and noticed a point where it doesn't match with the submitted permit. On page 10 of the permit I mentioned that we will perform LOT test to min 12.2 ppg. However,the decision was made to make an FIT type of test in order to avoid fracturing shales across the window exit. Required FIT value is 11.6 ppg for satisfying Kick Tolerance criteria per BP policy. Regards, Famil From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, January 31, 2013 2:41 PM To: Mammadov, Famil Cc: Egbejimba, Uchenna 3; Schultz, Mikel; AK, D&C Rig 272 Well Site Leader; Regg, James B (DOA) Subject: RE: F-13B Well BOP Test Cycle The first well F-13B for this rig should have a 7 day BOP cycle. Thank you for catching that... Also, an inspector will be out there for the first BOP test and to do a full rig inspection. We will not waive witness... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Mammadov, Famil 1mailto:famil.mammadov©bp.com] Sent: Thursday, January 31, 2013 2:21 PM To: Schwartz, Guy L (DOA) Cc: Egbejimba, Uchenna 3; Schultz, Mikel; AK, D&C Rig 272 Well Site Leader 2/4/2013 Page 2 of 2 Subject: F-13B Well BOP Test Cycle Guy, The PTD (212-141) for F-13B - 1st Well on Parker 272 Rig DOES NOT dictate the requirement for a 7 day BOP test cycle for the entire RST. Please confirm if the requirement for a 7 day BOP test cycle will be required for F-13B - 1st Well on Parker 272 Rig as well as an inspection of the rig (Parker 272) by an AOGCC inspector before operations commence on F-13B. Thanks, Famil Mammadov G WO I BP Alaska I Drilling Engineer—NWE Rotary I Mobile:+1 (907)306 7736 I Office:+1 (907)564 4135 email:famil.mammadoviibp.com 2/4/2013 • 8, OF O �//7 s,, THE STATE Alaska Oil and Gas .41 - -�'� °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 FALA6�P' Main: 907.279.1433 Fax: 907.276.7542 John Egbejimba 1 Engineering Team Leader ( �,' 14 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-13B Sundry Number: 313-160 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 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, Cathy P oerster Chair DATED this it day of April, 2013. Encl. STATE OF ALASKA x`,�s.—'.., ,. -i L 1— ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL +(.1)86Z 20 AAC 25.280 >� 1. Type of Request: ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well IS Change Approved Program • ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 212-141 - 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-20434-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU F-13B Will planned perforations require a Spacing Exception? 0YesNo 9. Property Designatior 10.Field/Pool(s): ADL 028280 ' Prudhoe Bay/Prudhoe Bay, 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)' 9071' -8753' 9071' -8753' 8640', 8140'(TOC) Unknown Casing Length Size MD TVD Burst Collapse Structural _ Conductor 110' 20"x 30" 110' 110' Surface 2665' 13-3/8" _ 2665' 2665' 4930 2670 Intermediate 7575' 9-5/8" 7575' 7453' 6870 4760 Production Liner 1558' 7" 7400'-8958' 7278'--8812' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft). None None None Packers and SSSV Type: None Packers and SSSV None MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation March 29,2013 • . IN Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 3/29/2013 • 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: Victoria Ferguson ❑WAG 0 SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Famil Mammadov,564-4135 Printed Name: Jo Alp gbejimba Title: Engineering Team Leader Email: Famil.Mammadov@bp.com Signature: ' - •J S 4,-, 444 Phone: 564-5859 Date. 3/ 617a01.3 / Commission Use Only Conditions of approval: Notify Commission so t at a representative may witness Sundry I �'/ �o // Number: 61 ❑Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: J2 U/" 71--e, f J�-eU Y' S i �d FtBr MS APR 12 10131 Spacing Exception Required? 0 Yes 0/NO Subsequent Form Required: /0 - 4'O APPROVED BY // 2 Approd .72,6„6.)74._________ COMMISSIONER THE COMMISSION Date: - t____,)'/ -l Form 1104 - i -d � AL Approved application is valid for 12 months from the date of approval Submit In Duplicate IQ r/ b BP Exploration Alaska Inc. F-13B Well Operations Program Parker 272 Ivishak Sidetrack Well Classification: Conventional High GOR Well: Yes Yes requires implementation of the "Rio Operations on High GOR Ivishak and Gas Pad Iniection Wells"SOP AFE Number: X3-0128W-C AFE Amount: $15.426 MM AFE Days: 66.30 Estimated Spud: 20-Feb-13 Prepared By: Famil Mammadov Deviations ETP Summary eMOC# Expires On GP 10-45 Temporary Pipework and Lubricator Pressure Test Acceptance Criteria. ADW-DEV-6345 07/01/2013 GP 10-10 Use of Hammer-Union Valve Connections from Different Manufacturers. ADW-DEV-7064 03/31/2013 GP 10-60 Open Surface Casing Shoe for Freeze Protection. ADW-DEV-7445 11/30/2013 Recommend Famil Mammadov Date: Drilling Engineer /1 // /10 0"'t 7/37/ lit Agree Jo bejimbaDate: ETL 1/e.(;6- !/3/ Agree a Schultz Date: WTL . 9 4 i z0/3 Agree Steve Rossberg D te: D&C Operations Man ger Decide LQA• nff12.. Date: D&C Engineering Manager - OR./0 to/ 3 . Program Amendment Record Rev ID/ Date Author Description Sec Page Ops Note A 01/16/2013 FM Original draft submitted to John Egbejimba for approval. B 01/18/2013 FM Revisions as per Egbejimba's comments, submitted to Mike Schultz for approval. C 01/31/2013 FM Revisions as per Schultz's comments, submitted to Steve Rossberg (James Willingham)for approval. D 02/05/2013 FM Revisions as per Willingham's comments, submitted to Carl Mountford for approval. E 02/06/2013 FM Revisions as per Mountford's comments. 0.0 02/06/2013 FM CONVERSION FROM Rev. "E"TO THE OFFICIAL APPROVED WELLPLAN 1.0 03/29/2013 FM Revisions as per eMOC#: ADW-MOC-8784 NOTES FOR REV ID/OPS NOTE COLUMN: A-Z denotes the changes which were made before the program was signed Version 0.0 is the official signed version Ops Notes will be numbered (ex: 1, 2, 3....) Well: F-13B Version: 1.0 2 Operations Program Contacts List Town Team Name Office Mobile Home John Egbejimba 5859 980-7096 344-9631 Mary Endacott 4388 440-0186 Famil Mammadov 4135 306-7739 Jorge Cubas 4971 832-623-9728 Takahiro Kosaka 5994 575-8588 Jacob Thompson 5579 947-9485 854-4377 John Rose 5271 748-5223 243-8813 Rahul Madarapu 4147 748-0997 _ Dave Johnson 4171 632-5806 _ Ken Allen 4366 748-3907 344-3883 Lowell Anderson 5562 244-4254 696-1294 Kris Honas 4841 268-0891 929-4388 Abby Warren 5720 240-9293 688-2895 Hyatt,Trevor 4627 223-3087 696-1294 Ryan Ciolkosz 5977 244-4257 306-5626 Zachary Browning 4664 208-301-2214 Mike Schultz 4896 240-8075 622-9355 Steve Rossberg 5637 240-8069 345-7634 Carl Mountford 4148 440-4308 222-6126 Conference Call 1-866-685-4852 Conference Code: 7427814387 Leader Pin: 2021545 New Well Delivery Name Position Office Mobile Home Stephen Crumley Geologist 564-4078 441-1479 Rachael Moore Geophysicist 564-5802 280-7184 Ryan Rupert NWD PE 564-4238 301-1736 Nisha Singh-Lee RE 564-4961 _ Carl Lundgren NWD TL 564-4334 440-8298 North Slope Operations NS PHONE ACCESS 564-5292 wait 1-xxxx or 1-907-659-xxxx Video Conference IP 161.99.111.106 Well Site Leader Rig office:659-8379 Camp office:659-4611 Rig Manager 659-8378 Mud Engineer 659-8487 Geologist 659-8392 MWD/DD 659-5892 Safety/HSE 659-5851 Superintendent Alan Madsen / John Rall Office:659-4618 Harmony:2156 ADW HSE Advisor 4650/659-0234 ADW Field Engineer 4653 BP Stores 4003 AOGCC Inspector 659-3607 Tool Service 4634/4636 Well Plan Distribution Mike Schultz(1 hard/1 electronic) schultzm@be.com John Egbejimba(1 hard/1 electronic) egbejiuj@bp.com Famil Mammadov (1 hard/1 electronic) famil.mammadovPbp.com Parker 272 WSL(1 hard/1 electronic) AKDCRig272WellSiteLeader@bp.com Rotary Superintendent(1 hard/1 electronic) NSUADW DrlciFieldSuperintendentna bo.com This list is the minimum distribution list for the wellplan and operational notes Invoice Cost Codes: PR5 INVOICE Cost Code Legacy Cost Code for CMMS;Aviation;Billeting X3-01 28W-C:PREPOST 000013141 X3-0128W-C:D R I LL 000013142 Well: F-13B Version: 1.0 3 Operations Program Table of Contents 1. Scope of Work 6 1.1. Well Summary 6 1.2. Objectives 6 1.3. Operational Overview 6 1.4. Performance Targets 7 2. Critical Issues 8 2.1. Key Risks and Mitigation Strategy 8 2.2. Pore Pressure and Fracture Gradient Prediction 9 2.3. Well Control 9 3. Well Status 10 3.1. Integrity Testing 10 3.2. Existing Well Equipment 10 3.3. Current Well Status 11 4. Detailed Operations Procedures 12 4.1. Set Whipstock/ Mill Window 12 4.2. Drill 81/2" Intermediate Hole 16 4.3. Run & Cement 7" Intermediate Liner 20 4.4. Drill 6%" Production Hole 26 4.5. Run & Cement 41/2" Production Liner 31 4.6. Perforate 41/2" Production Liner (Contingency) 36 4.7. Run 41/2" Completion 38 4.8. ND/NU Release Rig 41 5. Post Well Requirements 43 Attachments A. Existing Wellbore Information A.1. Schematic A.2. Wellhead Schematic A.3. Tubing Tally A.4. Directional Survey B. Contractors Recommendation B.1. Directional Program/Survey Program B.2. Mud Program B.3. Cementing Programs B.4. Baker Hughes Liner Hanger Procedures and Drawings Well: F-13B Version: 1.0 4 Operations Program C. Proposed Wellbore C.1. Pressure Testing Table C.2. PPFG Chart C.3. Schematic D. Regulatory D.1. Sundry D.2. Permit to Drill E. Casing Pick Strategy F. New Well Delivery SOR Well:F-13B Version: 1.0 5 Operations Program 1 . Scope of Work 1.1. Well Summary F-13B will be the first well spudded from Parker 272 rig. The parent F-13A well is no longer a competitive producer due to high GOR, and there are no remaining well work options. The F-13B PB1 hole has been P&A'ed with a cement plug in preparation for another rotary sidetrack from the 9%" casing. The proposed sidetrack well F-13B will access Zone 2C/3 reserves in the north- • western GDWFI area of F-pad. This well will be a conventional 2 string Ivishak RST kicking-off from uncemented section of 9%" casing from the CM3 at - 6617' MD. An 81/2" hole will then be drilled to the TSAG target as the 7" casing point at -9077' MD where a 7"drilling liner will be run and fully cemented to 150' back into the 9%" casing. From there, a standard 6%" hole will be drilled to deliver the planned Zone 2C well to a final well TD at -9,622' MD where a 41/2" chrome production liner will be run and fully cemented. 1.2. Objectives The primary and overarching objective is to conduct operations in a way that deliver safe and compliant wells Specific Well Objective Definition of Success 1 Drill and complete a high angle slant Successfully complete F-13B RST allowing well (<60 deg to maintain wireline for future wellbore utility (sidetracks), e-line accessibility) through the Ivishak accessibility and future perforation in the Sag Zone 2C. Well should be positioned River. to the west of the current F-22 location 2 Obtain good quality logs to identify Successfully run GR/Res/NeuDen MWD log the PGOC and POWC in the block. in the production hole. 1.3. Operational Overview • P&A F-13B PB1 hole. • Set whipstock and mill window. • Drill 81" intermediate interval to - 9,077' MD. • Run 7" drilling Liner and cement. • Drill 6W production hole to TD at - 9622' MD. • Run 41/2"solid liner and cement. • Run 41/2" Completion. • ND/NU/ Rig Release. Well: F-13B Version: 1.0 6 Operations Program 1.4. Performance Targets AFE/Performance Time & Cost vs. Depth Plots Time vs Depth Plot Cost vs Depth Plot 0 ft YAAA11\AUAAra - 0 ft- MIRU I --Actual Time - I MIRU I +-Actual Cost I -r•AFE Time -.-AFE 100011 - 1000 ft -n-Target et Time -it- -.-Target Cost rg 2000 ft - 2000 ft rDecomplete well 1 [Decomplete Well 3000 ft 3000 ft 4000 ft NOTE The target time for this 1st Parker 272 well is 4000 ft NOTE The target cost forth lst Parker 271 well Is equal to the AFE dme equal to the AFEtIme a 5000 ft : 3 5000ft 91 n • • 13 6000 ftWhlpstockz 600011 I Whipstock x Departure m Departure 0 ••7000 ft Whipstockl m 700011 Whipstock1 2 Departure - 2 Departure Drill 2nd Hole I -- ADM!2nd&InHole 8000 ft 1st 61/r'Hole 11 8000 ft I Drill lot&1/2 Hole Run 2nd 7'Uner _ I Run 2nd 7 liner 9000 t - I Run 1st 7"Uner II 9000 11- Run 1st T Uner _.- -------' —.RIDrill 2nd 6-h r Hole I Drill 2nd 61/8'Hole I I Grill in 6l/8"Nale I Drill 1st 61/8"Hole 10000 ft i 10000 ft - - - Run 4-1/2"Uner/Run Completlon/RDMO I Run 4-1/2 Uner/Run Completion/RDMO IT 1100011- ...__.__ -____-L__ I 11000 ft , . 0 5 10 15 20 25 90 95 40 45 50 55 60 65 70 $0 MM $2 MM $4 MM $6 MM $8 MM $10 MM $12 MM $14 MM $16 MM Well Time Since Accepting Rig(days) Well Cost Since Accepting Rig($) Fig. 1: Projected time and cost graphs *Key Performance Drivers • 101 well on a new Rig. o SAFETY is first priority to avoid HSE EVENTS! o Understand risks and ensure barriers are in place. o Adhere to all rig procedures - Do what is written or change what is written and then 'do that". • Successful P&A work. • Successful window exit from the 9%" casing to ensure a leak off test sufficient to drill 81/2" hole to top of Sag River. • Successful placement of the 7" liner shoe just into the top of Sag River with good zonal isolation. • Successful drilling of the 6W production hole Well: F-13B Version: 1.0 7 Operations Program 2. Critical Issues 1. Well Risk Classificiation: This well is classified as a High GOR Ivishak well. 2. H2S: F-Pad is an H2S Pad. Personal H2S monitor is required at all times while working outside the areas monitored by stationary fixed monitors. 3. Surface and Anti-Collision Issues: 3.1. Close Approach - All wells pass major risk for the planned F-13B trajectory 4. New Technology, Tools, and/or Design Features: F-13B does not have any new technology involved with the project. 5. Well Control: The WSL will ensure a plan is in place at all times to deal with all Non- shearable equipment across BOPE. Several operations throughout the course of this well include situations in which non-shearable equipment will be placed across the BOP stack. It is critical that a proper plan of action be developed and agreed upon for each of these unique situations. 6. AOGCC PTD Requirements for 1st Well on Parker 272: The PTD (212-141)for this well dictates the requirement for a 7 day BOP test cycle for this entire RST as well as an inspection of the rig (P-272) by an AOGCC inspector "before operations commence". 7. Defeated Emergency Alarm Systems: On a daily basis, the Parker System Equipment Defeat Log will be attached to the OpenWells daily drilling report. This log will included all emergency system alarms that have been "defeated". 2.1. Key Risks and Mitigation Strategy 1. Well Control /Communications: 151 well on new rig Adhere to D1-D6 well control drill requirements 2. Wellbore Breathing (81/2" intermediate hole section): There is a possibility for losses and wellbore breathing in the weak Colville mudstones while drilling with relatively higher mud weight through the Kingak. If breathing is initially suspected shut in the well, make contacts, and agree plan forward. 3. Lost Circulation: Subnormal pore pressure in the Sag Maintain recommended inclination across Kingak Monitor and maintain low ECD using good drilling and hole cleaning practices Minimize footage drilled into Sag by using GR at bit and holding a casing point pick meeting 4. Well Barriers: CRT-AK-10-10 - During well construction and maintenance activities, operations shall be conducted with one active barrier and one contingent barrier installed to address critical operational risks and contain the well. This wellplan details all barriers as required for all NU/ND operations. Where this symbol appears in the Program , it relates to one of these Critical Issues and/or Key Risks. STOP and think before proceeding! Well: F-13B Version: 1.0 8 Operations Program 2.2. Pore Pressure and Fracture Gradient Prediction Pore Pressure Sand Frac Gradients Shale Frac Gradients Most Likely Depth Minimum Most Likely Most Likely Brumfield Overburden Formation Minimum Most Likely (tvdss) (ppg) (Pin) (PPM(ppg) (ppg) (PP9) (PIN) (PPg) (PP9) Cr'C PR=0.33 PR=0.33 PR=0.42 Brumfield WS1 5763 8.4 8.7 9.0 12.8 13.2 15.3 16.0 17.8 CM3 5994 9.4 9.7 9.8 13.4 13.7 15.6 16.3 17.9 /6.7-p CM2 6808 9.6 9.8 9.9 13.6 13.9 15.9 16.6 18.2 /0. [7 CM1 7142 9.6 9.8 9.9 13.7 14.0 15.9 16.7 18.3 THRZ 7173 9.6 9.7 10.2 13.7 13.9 15.9 16.7 18.3 TKNG/LCU 7364 9.6 9.7 9.9 13.7 14.0 16.0 16.7 18.4 _ /p,6 TJF 7635 9.6 9.7 9.9 13.8 14.0 16.0 16.8 18.4 TJE 7793 9.6 9.7 9.9 13.8 14.0 16.0 16.8 18.5 TJD 8044 9.6 9.7 9.9 13.8 14.0 16.1 16.9 18.5 TJC 8297 9.6 9.7 9.9 13.8 14.1 16.1 16.9 18.6 TJB 8445 9.6 9.7 9.9 13.8 14.1 16.1 17.0 18.6 TJA 8533 9.6 9.7 9.9 13.8 14.1 16.2 17.0 18.6 8633 9.6 9.7 9.9 13.9 14.1 16.2 17,0 18.6 / TSGR 8634 5.7 6.0 7.6 12.2 15.1 15.9 18.6 l t) tO 8679 5.7 6.0 7.6 12.2 15.2 15.9 18.6 �gQ TSHU 8680 5.7 7.8 9.9 13.1 15.6 16.4 18.6 Oj.C.-_ 8752 5.7 7.8 9.9 ✓ 13.1 15.6 16.4 18.6 C' TSAD 8753 6.8 7.0 7.8 • 12.4 12.7 15.4 16.2 18.6 d 45SB 8758 6.8 7.0 7.8 12.4 12.7 15.4 16.2 18.6 42SB 8824 6.8 7.0 7.8 12.4 12.7 15.4 16.2 18.6 TCGL 8875 6.8 7.0 7.8 12.4 12.7 15.4 16.2 18.6 PGOC 8920 6.8 7.0 7.8 12.4 12.7 15.4 16.2 18.7 BCGL 8942 6.8 7.0 7.8 12.4 12.7 15.4 16.2 18.7 POWC 8970 6.8 7.0 7.8 12.5 12.8 15.5 16.2 18.7 23SB 8998 6.8 7.0 7.8 12.5 12.8 15.5 16.2 18.7 22TS 9056 6.8 7.0 7.8 12.5 12.8 15.5 16.2 18.7 2.3. Well Control 4e;, 81" Intermediate Interval ��- �- 9. Maximum anticipated BHP 2694 psi @ 8634'TVDSS (6.0 ppg EMW) / Maximum surface 1830 psi (0.10 psi/ft gas gradient to surface) pressure Kick tolerance Infinite with 11.0 ppg MW at min predicted fracture gradient of 13.7 ppg Planned BOP test Rams test to 3500 psi/250 psi. 7 day cycle for BOP test pressure Annular test to 3500 psi/250 psi 9%" Casing Test/7" 3500 psi surface pressure Casing Integrity Test-81/2" hole FIT after drilling 20-50'from middle of window 7" Casing VBRs upper cavity will be changed to 7" rams for the 7"liner 6'/8" Production Interval Maximum anticipated BHP 3296 psi @ 9056'TVDss (7.0 ppg EMW) Maximum surface 2290 psi (0.10 psi/ft gas gradient to surface) pressure Infinite with 8.7 ppg MW at min predicted fracture gradient of 11.9 Kick tolerance ppg Planned BOP test Rams test to 3500 psi/250 psi. 7 day cycle for BOP test pressure Annular test to 3500 psi/250 psi Integrity Test-6%" hole FIT after drilling 20' of new hole 41/2" Production Liner 3500 psi surface pressure Planned completion fluids 8.5 ppg Seawater/6.8 ppg Diesel Well: F-13B Version: 1.0 9 Operations Program 3. Well Status The F-13B well was being executed per eMOC - ADW-MOC-8724. A number of operational incidents occurred since the e-MOC was issued. It was found that 6W hole section was collapsed prior to running the 41/2' liner in hole. The liner string stood up while trying to run to the target depth. Attempts were made to wash / ream liner to bottom with no success. The decision was made to pull the liner to surface and perform a clean-out run. It was discovered that all liner components were left downhole once the running tool was pulled back to surface. The liner was successfully fished to surface and a clean-out BHA was made up. Clean-out operations started on March 26th, 2013. The open hole section was washed and reamed in 5-10ft increments. Two pack-off incidents took place during the clean-out but the string was eventually pulled free in both cases. Clean-out continued until a hard spot was observed at 8990 ft (-32ft below 7in shoe). No progress was being made beyond that depth. Initially, bit balling or twist off was suspected as a result of flat torque observed regardless of drilling parameters applied downhole. A number of nut-plug and dispersant pills were spotted to clean any potential bit balling but no progress was made. Twist off option was tested by reverse circulation and the floats held indicating that the string did not part above the float valve. Only the bit sub and bit were below the float valve. Eventually, the decision was made to pull out of hole and investigate the BHA. Once the clean-out BHA was pulled back to the surface, it was observed that the 6W drill bit (0.61ft), bit sub (2.33 ft), pin end of the float sub and float valve were missing in hole. It is believed that the float valve was released from the float sub while high-rate circulation was performed following the reverse circulation test. It is estimated that the success chance of fishing is low and wouldn't justify the expenses to be committed to a fishing campaign. As a result it is recommended to P&A the existing wellbore and drill another rotary sidetrack above 7"liner. 3.1. Integrity Testing • The estimated TOC on the F-13B PB1 P&A cement job is at 8,140' MD. • After WOC to achieve 500 psi compressive strength, the P&A cement plug will be pressure tested to 2230psi for 30 mins 3.2. Existing Well Equipment Existing Wellhead and Tree Information Casing Head: McEvoy Lower Type S-3. 13%butt x 13%5000 flange top Casing Hanger: McEvoy 12 x 9%SB-3 Tubing Spool: McEvoy 2 Step Conventional. Tubing Hanger: McEvoy 2 Step(5) Seal Hgr. 12 x 7 IJ4S box top and bottom. Tubing Head Adapter: McEvoy(5) Seal Adapter, 13%x7-1/16" Tree: Cameron 7-1/16 x 6% BPV Profile: Cameron Type J Well:F-13B Version: 1.0 10 Operations Program 3.3. Current Well Status 13-3/8" 72# L-80 2680' MD 7" TOL 7399' MD / 7279' TVD 9-5/8" Whipstock Exit 7575' MD / 7453' TVD Estimated TOC 8140' MD Bridge Plug 8640' MD 7" Liner Shoe 8958' MD / 8674' TVD J Collapsed hole 8990' MD / 8697' TVD fi -11 6-1/8" OH (exaggerated) 9071' MD / —8753' TVD Well: F-13B Version: 1.0 11 Operations Program 4. Detailed Operations Procedures 4.1. Set Whipstock / Mill Window Reference Documents: • "Leak-off and Formation Integrity Tests"SOP • "Criteria for Breaking Containment"STP • "Procedure for Replacing Casing Packoffs"SOP • "Whipstock Sidetracks"RP Verify Start-up Checklist: ❑ Perform pre-job safety meeting. Ensure safety valve and cross-overs are on rig floor in the event of unexpected well flow ❑ Ensure Ditch Magnets are installed and close both the manual HCR and kill valves n CONFIRM PATH-FORWARD WORK TO BE DONE USING DIRECTIONAL PLAN P6. Issues and Potential Hazards: • BOP Test interval for this section is 7 days - To comply with state regulations, record mud weights in and out each tour. Ensure VBR's and annular are tested with 4"test joint • EZSV Setting Depth: Have a pre-job planning meeting and make sure all parties understand elevation referencing for setting EZSV • Well positioning: Ensure the ODE receives on a daily basis, the traveling cylinder plots from the directional company. Verify that the survey program is being followed General Overview: A. Drillpipe 4", 14.0#, HT-38, 'S-135' (Adjusted weight: 15.71 ppf) OD: ID: Collapse: Burst: Torsional: _ Tensile: 100% 4" 3.34" 13,800 psi 18,400 psi 29,400 lbs 403,500 lbs 80% 4.875" 2.563" (tool joint) 11,040 psi 14,720 psi 23,520 lbs 322,800 lbs (tool joint) ***Max Recommended MU Torque: 17,700 ft-lbs Fluid Capacity: 0.442 gal/ft ***Recommended MU Torque: 17,700 ft-lbs ***Min Recommended MU Torque: 12,200 ft-lbs Fluid Displacement: 0.240 gal/ft B. BHA: 9%" Bottom Trip Anchor with 41/2" IF box (Baker locked) anchor will set @ - 18K 95/8"Whipstock with 41/2" IF pin 81"Starter Window Mill with 41/2"reg pin (shear screw set for 45,000 lbs.) 8%" Lower Watermelon Mill with 41/2" reg box x 41/2" IF box 6%" Flex Joint with 41/2" IF box x pin 81/2" Full Gauge Upper Watermelon Mill with 41/2" IF box x pin 5" HWDP (1 joint) 61/4" Drill Collar 41/2" IF box x pin 61/4" Dart Sub (with float collar below) 6-3/4" MWD (with XO's as required) 9-12 Joints of 61/4" Drill Collars with 41/2" IF box x pin 15 Joints of 4" HWDP with HT-38 IF box x pin 4" Drill pipe to surface or as necessary for drill pipe management Well: F-13B Version: 1.0 12 Operations Program • C. Milling Fluids Safe Operating Envelope API FI. HTHP FI. Drill Mud Wt. (ppg) PV YP Loss Loss @ 200° MBT pH Solids F or BHCT Min* Preferred** _ Max cP lb/100 ft2 (ml/30min) Mill 10.6 10.7-10.8 11.1 10-25 25- 35 <8.0 < 12 < 20 9 - 10 < 6.0 *The lower limit represents the lower operating limit. " Any mud weight above the Preferred Mud Weight Range, which is listed in the Maximum Operating Range column, needs approval from both the ODE and WSL. D. Kick tolerance: Perform an FIT after drilling 20' of new formation, not to exceed 50' of new formation • A minimum 11.6 ppg EMW will provide an infinite tolerance with the planned 11.0 ppg mud weight in the hole (max pp= 7.6 ppg in Sag River, restricted by MAASP). E. Barriers: Wellbore Cement plug, BOPE, Kill weight fluid F. BOPE Testing requirements: The pipe ram requirements for this phase of the well will include 4" drillpipe. Install a test plug in tubing spool and pressure test to 250 psi low / 3500 psi high for 5 minutes. Change out rams as appropriate and test to 250 psi low / 3500 psi high for 5 minutes. (Reference attached F-13B Pressure Testing Document (#7)). Operation Steps: 1. RU Eline. Per CRT-AK-10-10:8.3.1: No lubricator is required. 2. RIH with EZSV/GR/CCL for 47# 9%" casing and set @ -6,620' MD making sure EZSV is not set across a collar and a collar will not be cut while milling the window. Target a KOP in the LCU. > Wellsite Geo shall use GR to confirm a competent setting "zone" for the EZSV to facilitate an efficient sidetrack process. • EZSV setting depth shall be verified by at least 2 independent elevation calculations > Max hole angle is 25.38 deg @ 4118'MD 3. Pressure test EZSV and 9%" casing to 250 psi for 5 minutes and 3500 psi for 30 minutes to confirm the mechanical integrity of the well leference attached F-13B Pressure Testing Document (#9)). 4. Pick up and RIH with 9%" Baker whipstock "stiff" 3-string mill and lead mill assembly as per above Baker milling BHA (orient as per directional plan). NOTE: This "stiff" milling assembly is designed to improve the potential for an efficient sidetrack into new formation which should minimize the potential for"tracking"the old well. • Fill the drill pipe a minimum of every 20 stands on the trip in the hole with the whipstock assembly. > Avoid sudden starts and stops while running the whipstock. • The RP recommends running in the hole at a maximum of 90-120 seconds per stand taking care not to spud or catch the slips. Ensure running string is stationary prior to insertion of the slips and that slips are removed slowly when releasing the Well: F-13B Version: 1.0 13 Operations Program work string to RIH. These precautions are required to avoid any weakening of the whipstock shear mechanisms and/or to avoid part/preset on the packer. Note : Non-Shearable equipment 5. Orient the whipstock using MWD to 359 deg 6. Set the whipstock at -6620' MD on top of EZSV. Set bottom anchor with 15 - 20k down. PU to verify set. CONFIRM WITH BAKER. Shear off slide with 45k down. PU to verify shear. CONFIRM SHEAR WITH BAKER 7. Fully displace the well to 10.8 ppg LSND milling fluid before milling the window. ➢ Refer to mud program for milling specific mud properties 8. Mill window plus 20-50' of new formation (DO NOT EXCEED 50' OF NEW HOLE BEFORE RUNNING THE PLANNED FIT/LOT). Changes to barriers once milling the window has started Wellbore Kill weight fluid, Wellhead annular valves, Tested BOPE ➢ Use ditch magnets to collect the metal shavings. Clean regularly. ➢ Ensure that the manual valves in front of the 2 HCR are closed prior to milling. ➢ Ensure any personnel working around metal shavings wear proper PPE, including goggles, face shield and Kevlar gloves. ➢ While it is not necessary to weigh the steel cuttings to ensure a proper window has been milled, a close observation of the metal returns is useful in terms of estimating the efficiency of the window milling operation. Cuttings should weigh approximately 200 to 300 lbs. There may or may not be cement behind casing and some of the metal cuttings may fall into the open annulus. • The well records indicate that there is cement behind casing at the planned KOP • Note in OPENWELL report as to whether cement is found behind the 9%" casing at the KOP. • Work the upper mill through the window to confirm the window milling is complete and circulate well clean (circulate a minimum of 11/2 bottoms up). Pump a high-vis super sweep to remove metal shavings and make every effort to remove all of the super sweep pill from the mud system as it is circulated to surface. 9. Pull starter mill into casing above top of whipstock, flow check the well for 10 minutes and conduct an FIT as per "Leak-off and Formation Integrity Tests" SOP to a minimum of 11.6 ppg ➢ Assuming the kick zone is at the top of the Sag River formation with a maximum pore pressure gradient of 7.6 ppg, a minimum FIT of 11.6 ppg provides an infinite kick tolerance and sufficient MAASP with 11.0 ppg mud weight. ➢ **WTL approval is required for a FIT value between 11.0 and 11.6 ppg (insufficient MAASP) **ODE approval is sufficient for a FIT equal to our greater than 11.6 ppg EMW (>50 bbl kick tolerance). 10. POOH and LD milling assembly • Per CRT-AK-10-10: 5.3.7: Flow check well for 10 minutes to confirm no flow: • Before pulling off bottom. ■ Before pulling the BHA through the BOPE. Once out of the hole, inspect mill gauge and record in open wells. Well: F-13B Version: 1.0 14 Operations Program 11. Flush the stack/lines to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. Well:F-13B Version: 1.0 15 Operations Program 4.2. Drill 81/2" Intermediate Hole Reference Documents: • "Directional Surveying and Anti-Collision Management"SOP • "Subsurface Close Proximity"SOP • "Rig Operations on High GOR ivishak and Gas Pad Injection Wells"SOP • "Shale Drilling-Kin_gak and HRZ' RP • "Lost Circulation" RP Verify Start-up Checklist: ❑ Perform pre-job safety meeting. Ensure safety valve and cross-overs are on rig floor in the event of unexpected well flow ❑ Review pore pressure detection plan and fluid management plan with appropriate personnel ❑ Ensure ditch magnets are installed and close the manual HCR and kill valves. Issues and Potential Hazards: • High GOR well-290 bbls of extra fluid volume is required on location at all times. • BOP Test interval for this section is 7 days - To comply with state regulations, record mud weights in and out each tour and ensure BOPE function test are performed and recorded in OpenWells before the 7 day deadline. • Moderate-to-severe gas cut mud-regular monitoring of return fluids for visual indications of high gas content (bubbling) • Potential losses at TSGR - good hole cleaning practices and ECD management plan in place to prevent losses. • Colville breathing -follow well control practices • TSGR depth pick-planned AAR learnings from F-13B PB1 General Overview: • Drillpipe- Drill this interval of the well with 4"drillpipe. 4", 14.0#, HT-38, 'S-135' (Adjusted weight: 15/1 ppf) OD: ID: Collapse: Burst: Torsional: Tensile: 100% 4" 3.34" 13,800 psi 18,400 psi 29,400 lbs 403,500 lbs 80% 4.875" 2.563" (tool joint) 11,040 psi 14,720 psi 23,520 lbs 322,800 lbs (tool joint) ***Max Recommended MU Torque: 17,700 ft-lbs Fluid Capacity: 0.442 gal/ft ***Recommended MU Torque: 17,700 ft-lbs ***Min Recommended MU Torque: 12,200 ft-lbs Fluid Displacement: 0.240 gal/ft • Pumps: 2 x 12-P-160 Mud Pumps/6" liners rated to 4670 psi (max flow-rate at 105 spm at 93% efficiency= -882 gpm) ❑ Bit recommendation: Bit Number Hole Size Running Order/ Depths(MD) TFA Bit Type 1 81/2" Primary/ KOP to TD (TSAG) 0.72 in2 Reed Hycalog (3-13's DTX619M-D6 3-12's) 2 81/2" Back up 0.72 in2 Baker Hughes (3-13's DP606X 3-12's) Well: F-13B Version: 1.0 16 Operations Program > BHA recommendation: BHA# Motor Size and Motor Required Flow Rate RPM Required Doglegs 1 8.5" Baker Hughes Mud Motor, 1.2 deg 500-600 gpm 0.33 rev/gal 4 deg/100' ITEM EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. NO. DESCRIPTION PROVIDER OD OD ID CONN CONN LENGTH LENGTH 18112"PDC TBD 85 412 Reg Pin 23 120 2 6.3,4"Ultra XTreme Motor 8 3/8"UBHS(AK01.2")WIFloal BHI 8 375 7.30 250 4 12 Reg B 4 12 IF B 23.00 24.20 3 6 3.4"NM String Stab wi 8 318"Straight Blades PHI 8.375 6.75 2 81 4121F P 4 1/21F B 5 00 2920 4 6.14"NMCSDP BHI 675 281 4121FP 4121FB 1000 39.20 5 Stop Sub PHI 6.75 2.81 4 112 IF P 6 3/4"T2 B 2.00 41.20 6 Ontrak IGamIRes.Pres'VSS.Sulvevl PHI 675 63/4"T2 P 63/4"T2 B 1684 58.04 7 Modular Stabolizer PHI 6375 6.75 281 6 3/4"T2 P 6 3/4"12 B 3.94 61.98 8 BCPM(Pulsar) PHI 6.75 2.81 6314"T2 P 63/4"128 10.61 7259 9 Stop Sub PHI 6.75 2.8t 63/4"T2 P 4112"IF B 245 75.04 10 NM Downhole Filter Sub PHI 6.75 288 4 112-1F P 4 1/2 IF 8 5.27 80.31 11 6.314"NMCSDP BHI 6.75 2.81 4 1/2"1F P 4 12IF 8 31.00 111.31 12 6.3/4"NMCSDP PHI 6.75 2.81 4 1/2-1F P 4 1/21F13 31.00 142-31 13 6.3/4"NMCSDP PHI 6.75 2.81 4 1/21F P 4 12 IF B 31.00 173.31 14 3 Joints 5"HWDP 149.778/ft Adjusted weight) RIC, 6.625 TJ 5.00 300 4 12"IF P 4 1/2 IF B 93.00 266.31 ,,c 15 Well Commander(WCMD 102) MI 7.00 2025 4 12"IF P 4 121F 8 686 273.17 16 Steel XO BHI 6.75 2 81 4 12"IFP HT3813 2.00 275.17 17 15 Joints 4"HWDPI(28.20;ft Adjusted weight) RIG 4 875 TJ 4.00 2.56 HT38 P HT38 B 465.00 740.17 18 Drilling Jar-Hydraulic illnk 1875 2.25 HT38 P HT38 B 29.80 769.97 19 9 Joints 4"HW DP(28.24#41 Adjusted weight) RIG 4.875 TJ 4.00 2.56 HT38 P 14738 B 279.00 1048.97 20 4"S-135 Drill Pipe(15.620.41 Adjusted welght)I RIG 4.875 TJ 400 3.34 HT38 P HT38 B 7982.01 9030_98 21 Notes and omments Target Flowrale from Drilling Program 550-600 gpm Motor RPM 33 rev/gal Optimize RPM for non-slide mode based on vibration level > Survey/Logging Tool Requirements 81/2°"Section Survey and Logging tool requirements: MWD surveys corrected with IFR+MS and Sag , BHA#1 KOP-TSAG corrections PWD/Dir/GR/Resistivity (real-time) All MWD surveys will be corrected with IFR+MS and Sag corrected. Surveys should be corrected as soon as enough have been collected to start analysis (10-12 is sufficient). Surveys will be "batch"corrected every 10 throughout entire 81/2"interval.All surveys will be Sag corrected. > Drilling Fluids 81/2"Intermediate Hole Section Mud Properties: LSND Depth Safe Operating Envelope PV YP API fl. HTHP pH Drill MBT MD Mud Weight(ppg) Loss FL Solids feet Min" Preferred" Max cP lb/1 00ft2 ml/30 min % • KOP-Section TD 10.6 10.7-10.9 11.2 10-18 18-28 <6 <10 9-10 <6.0% <20 7576- 91 51 m O (-7370' • Sl�D'7v,:„5) A 4.14.(3 *The lower limit represents the lower operating limit. ** Any mud weight above the Preferred Mud Weight Range, which is listed in the Maximum Operating Range column, needs approval from both the ODE and WSL. Well: F-13B Version: 1.0 17 Operations Program Operation Steps: 1. The pipe ram requirements for this phase of the well will include 4" drill pipe. Annular preventer shall be tested with 4"test joint. 2. PU sufficient 4" DP to TD of the 8.5" intermediate hole section if not done already (maximize offline activity for PU of DP) 3. Make up 81/2'drilling assembly with a 1.2°Motor Bend, PWD/DIR/GR/Res and RIH. Note : Non-Shearable equipment • Max doglegs =6 deg/100' (Planned 4 deg/ 100') 4. Close Approach - Using directional plan (P6), all wells pass major risk analysis for the 81/2" intermediate hole (parent wellbore). 5. The mud weight guidelines for this interval for this interval of the well are as follows: • Kingak shale stability of 10.5-10.6 ppg per polar plot; 10.8 ppg from F-13B PB-1 experience. • Pore pressures: max gradient in this interval is 10.2 ppg ➢ Mud Weight Strategy - Kick-off with 10.8 ppg LSND mud drill the 81/2" intermediate hole to the TSGR liner point with the 10.8 ppg mud maintaining close awareness for potential WBS issues across Kingak/ HRZ. 6. Obtain initial ECD benchmark readings with PWD tool prior to drilling the intermediate hole and calculate adjustment factor to the clean-hole ECD model 7. Drill ahead to TD at the top of Sag River at -9,031' MD. > Faults: There are no expected fault crossing for this section of the well Drilling Practices: • Target drilling flow rate of 500-600 gpm with 3-12 and 3-13 Nozzles (TFA = 0.72), while drilling to the 81" hole TD. • Ensure that the directional driller is updating the traveling cylinder plot per BP directional guidelines and sent to the town ODE each day. After each survey is taken, the as-drilled position of the well will be marked on the anti-collision diagram. (4.10 BP Directional Survey Handbook). r Follow all Baker Hughes RPM/ Flow rate limits ➢ Minimize the potential for wellbore breathing in Colville by keeping the hole clean and minimizing surge/swab pressures per Baroid wellsite modelling. ➢ In the event of lost circulation, make notification to the WTL for any losses above "seepage" rate(>20 bbl/hr). • Refer to Mud Program LCM decision tree for actions > For the TSGR pick, Geology should be keeping good measurements on the previous isopachs and monitoring the LWD data to better identify the possibility of the Sag River coming in high. Ensure close communication exists with the onsite geologist, the town geologist and the well site team. The TSAG casing point is CRITICAL. On approach to the TSAG casing point, circulate bottoms up to observe cuttings as necessary/required by the Wellsite Geologist. This interval TD will be -5- 10' MD into the top of the Sag per the Wellsite Geologist as detailed in the "TSAG Casing Pick PLAN" attached to this wellplan. Ensure lessons learned from F-13B PB1 are transferred to the operational plan Well: F-13B Version: 1.0 18 Operations Program (NOTE: There should be no directional work required when drilling into TSAG. Consider the use of the automatic driller to hold drilling parameters constant while drilling into TSAG.A drilling break could indicate the TSAG pick) Suggested Drilling Parameters for PDC Bit: ➢ Window to TSGR: Flow rate range -500-600 gpm. • CM3 to Top of Sag River: WOB range to be maintained 10-20 Klbs. Higher WOB should reduce the bits drop tendency. Do not exceed 25 Klbs WOB. Drill Pipe RPM to optimize directional objectives. ECD hardline should be 1 ppg over clean hole ECD in shales. • Ensure ECD is maintained at less than 12.2 ppg 100 ft prior reaching expected TD • ROP should be limited based upon ECD/PWD trends as required. • Where possible maximize RPM (with-in the above specs) to improve hole cleaning Connection Practices: • Back-ream full stand at drilling rate, this may be reduced as dictated by down-hole conditions, however, begin the back-ream process earlier rather than later in response moving the cuttings load away from the BHA prior to connections. Ream down at 75%drilling flow rate to reduce the surge effect. 8. POOH and LD 81/2" Drilling assembly ➢ At TD obtain the BHCT from the MWD and give it to the SLB Cementers. • Circulate as required to clean-up the hole to a 0.3 ppg above calculated ECD or a minimum of 3x BU prior to the planned wiper trip. ➢ Flow check well for 10 minutes to confirm no flow: / • Before pulling off bottom. • After pulling into the casing window • Before pulling the BHA through the BOPE. Note: Drill pipe must be drifted to pass Pump Down Plug for 7" liner. Minimum required drift size= 2.400"for 7"liner ➢ Take Pick-Up, Slack-Off, rotating weight and Torque values, at TD and report in OpenWells. ➢ Roll pumps at -1-2 bpm while POH to the window at 3 min/stand to eliminate the swab potential while POH. ➢ With the bit inside the window, RIH to bottom pumps off if possible, however wash down the last stand to bottom. Note all hole problems in OPENWELLS. ➢ Circulate the hole clean with a minimum of 3 BU (continue as required) at 120 RPM at 500-600 gpm stroking a full 90' stand and pump a combination low vis/high vis sweep if necessary. ➢ Roll pumps at -1-2 bpm while POH to the window at 3 min/stand to eliminate the swab potential while POH. ➢ With the bit inside the window and when ready to TOH, record in OpenWells the number of bottoms up,final Pick Up, Slack Off, Rotation weights and Torque values. ➢ At surface, LD drilling BHA record any BHA balling, abnormal wear or any other issues in OpenWells Well:F-13B Version: 1.0 19 Operations Program 4.3. Run & Cement 7" Intermediate Liner Reference Documents: • GP 10-60 Zonal Isolation • Schlumberger Cement Program • Baker Liner Hanger Data • "Running and Cementing a Drilling Liner"-RP Verify Start-up Checklist: ❑ Perform pre-job safety meeting. ❑ Verify final CemCade has been received and that thickening time is as planned Issues and Potential Hazards: • High GOR well—290 bbls of extra fluid volume on location will be a requirement for this interval of the well. • BOP Test interval for this section is 7 days - To comply with state regulations, record mud weights in and out each tour and ensure BOPE function test are performed and recorded in OpenWells before the 7 day deadline • Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab / surge pressure could initiate instability problems. • Plan on 150' of liner lap with this liner. • Lessons Learned from parker 273, Well 02-12D: Drill pipe crossovers must be drifted to pass Pump Down Plug for 7" liner. Minimum required drift size = 2.400". General Overview: A. Liner/Casing Information 7",26#, L-80,VT HC Collapse Burst Tensile ID Make-up Torque 100% 5410 psi 7240 psi 604,000 lb 6.276" 11,950 ft/lbs 80% 4328 psi 5792 psi 483,200 lb 6.151"drift MUL 4.776" **The liner will be - 2618' long, -65 joints of VT HC is needed (including contingency). B. Drillpipe Information 4", 14.0#, HT-38, 'S-135' (Adjusted weight: 15.71 ppf) OD: ID: Collapse: Burst: Torsional: Tensile: 100% 4" 3.34" 13,800 psi 18,400 psi 29,400 lbs 403,500 lbs 80% 4.875" 2.563" (tool joint) 11,040 psi 14,720 psi 23,520 lbs 322,800 lbs (tool joint) ***Max Recommended MU Torque: 17,700 ft-lbs Fluid Capacity: 0.442 gal/ft ***Recommended MU Torque: 17,700 ft-lbs ***Min Recommended MU Torque: 12,200 ft-lbs Fluid Displacement: 0.240 gal/ft C. Cement Basis Casing Size 7" 26#, L-80 Vam Top HC Intermediate Liner Basis: Tail: 882' of annular length +30%excess + 85' shoe track. Tail TOC at 8149' MD Total Cement Volume: Spacer 30 bbls of Viscosified Spacer (Mud Push XT) Tail 29.1 bbls, 163.7 cuft, 141.1 sks 15.8 lb/gal Class G + adds— 1.16 cuft/sk Well: F-13B Version: 1.0 20 Operations Program Operation Steps: 1. The pipe RAM requirements for this phase of the well will include 4"drillpipe and 7" liner. 2. Change upper VBR's to 7" casing rams and test 250 psi / 3500 psi, 5 min low / 5 min high (Reference attached F-13B Pressure i esting Document (#7)) NOTE: While changing-out the upper rams, circulate the across the top of the well below the blind rams using the choke and kill lines to make sure the hole stays full. Changes to barriers to change out rams: Wellbore Closed blind/shear rams, Kill weight fluid Changes to barriers once 7"rams are installed: Wellbore BOPE, Kill weight fluid 3. Ensure safety valve to this 7"VT HC drilling liner is on the floor. 4. Run 7"26#, L-80 VT HC intermediate liner 150'to the 95/8"window as table below: Nom Item lb/ft Material Thread Notes Size 7" HES Float Shoe 26 L-80 BTC Baker-Lock 7" 40'Joint 26 L-80 BTC Baker-Lock 7" HES Float Collar 26 L-80 BTC Baker-Lock 7" 40'Joint 26 L-80 BTC Baker-Lock 7" BHI Landing Collar 26 L-80 BTC Baker-Lock 7" 40'Joints as needed 26 L-80 VT HC Jet Lube Seal Guard 7" Baker Flexlock Hanger Baker ZXPN Liner Top Packer with Place at 150' above 7" 10' tie back sleeve the 95/"window Baker HRD-E Running Tool & 7" Hydraulic Pusher Tool 4" 4" DP to surface 15.71 S-135 HT-38 Note : Non-Shearable equipment / ;> ➢ Thread Compound: Jet Lube Seal Guard thread compound on Vam-Top threads and MU per recommendation ➢ Centralization: • Place 1 centralizer per joint in open hole section to TOC: o Utilize 8"OMD rigid centralizers o Depending on hole conditions, the decision may be made to modify centralization plan. Discuss with the ODE prior to running ➢ MU shoe track (baker-lok the shoe joints) and check floats • Float check procedure: Pump through/fill shoe track with mud/brine to ensure pump-thru capability. PU shoe track and drain fluid level thru the floats into well. Run shoe track back into well and visually confirm no back-flow into the shoe track ➢ Will run ZXPN Liner with Flexlock hanger- Verify that the setting procedure used for each component matches the type of component run. ➢ Break circulation after liner is fully made up and note weight of liner in mud. Well: F-13B Version: 1.0 21 Operations Program ➢ Note the following liner running procedures • Stage pumps up at all times to minimize the potential to break-down the formation • Record up and down weights and compare against I-center broomstick plot. • Real-time modeling will be prepared by the mud engineer to support the swab and surge requirement. • RIH at no greater than 60 fpm to minimize swab and surge pressures (-11.5 ppg EMW surge RIH dry) • Record Pick-Up and Slack-Off weights every 10 joints. If there is any deviation from the planned trends, then stop, slowly bring up the pumps and circulate the well bore clean. • Fill liner every 10 joints and then drillpipe every 20 stands while the liner in cased hole ➢ At the XO point for drillpipe, make up the liner assembly and then circulate at 3 bpm for 5 min. LD casing tools and begin to RIH on drillpipe at '-1'-2'/sec run rate if allowed. ➢ Circulate bottoms up before running into the open hole • Do not exceed 7 bpm • Limit circulating pressure to 1500 psi • Ensure mud is in good condition prior running liner into open hole • Continue circulation if mud parameters dictate • NOTE: As this is a low angle hole toward the 81/2' TD (-24 deg), be prepared to wash the liner down the last 30' to bottom. If washing down is required bring pumps on in 1 bbl increments and wash down slowly. If working the pipe is required do it slowly to not swab the shales in. ➢ The planned setting depth for this 7" liner will be -5' MD into the top of the Sag. Tag-up on bottom, then PU -2' off-bottom in preparation for the cementing this liner. Do not reciprocate the 7" shoe out of the top Sag after the initial landing of this casing into the top of the Sag. ➢ When liner reaches bottom, stage pumps up to -5 bpm in 1/2-1 bpm increments allowing the pressures to stabilize at each flow-rate before increasing the rate to the next level. Circulate until the returns are clean, ramp up to full cementing rate of 6bpm as per attached Schlumberger CemCADE and continue circulating, minimum 3 annular volumes,watch for potential packing off. ➢ Adjust rheology mud rheology to a 15-18 YP while conditioning mud for the cement job. 5. Rig up cementers and have a PJSM with all involved parties ➢ Pressure test all cement lines to 250 psi low and 4500 psi high for 5 minutes (Reference attached F-13B Pressure Testing Document (#12)) ➢ This 7"drilling liner will be cemented using the volumes as stated above ➢ Do not exceed 6 BPM (or the minimum hanger setting pressure (1500 psi per Baker procedure) while circulating hole prior to cement job 6. Before cement job: Review the CemCADE with the Schlumberger cementing representative Cement Analysis: The field blend tests slurry testing shall be conducted with as-drilled well conditions. The cement analysis results shall be received before pumping the cement job. The WSL shall verify that the cement slurry testing conforms to the requirements for the job type state in the table below: Tail Cement Job Requirements: Well:F-13B Version: 1.0 22 Operations Program Thickening Time: TBC Fluid Loss: <80 ml Free Fluid: Zero or trace Testing Requirements: Job Type Slurry Pump Compressive Operating API Fluid Rheology BP Settlement Time Strength Free Water Loss Test Intermediate Tail Yes Yes Yes No Yes No 7. Verification of annulus cement for this liner cement job will be achieved by estimated lift pressure. Confirmed design and execution should meet all the requirements for the "Lift Pressure Estimate of TOC method"verification techniques outlined in Table 2 and Section 8.4.2 of GP 10-60. WSL shall be familiar with these job requirements and shall verify that the operational recording/procedural requirements for using this verification method are communicated to cementing contractor personnel and implemented during execution. 8. Cement as per recommended practice at volumes specified Y Pump the cement job per the most current SLB plan, see the attached plan > Confirm all volumes associated with the cement job > Reciprocate using pipe stretch, ensure that the shoe never picks up out of the Sag (the shoe should be 2-10' into the SAG so there is some footage available to move pipe if necessary) Y Report any circulation or job issues in Open Wells • NOTE: Watch pump rates and follow pumping schedule (do not try to "catch" up to cement). > Drop DP dart and displace cement with 10.8 ppg LSND mud using cement unit Y Reduce pump rate according to the SLB Cementing Program prior latching dart in liner wiper plug and before bumping the plug Y Do not over displace more than 1/2 the shoe track volume (-1.5 bbls) 9. Take following steps to set the liner hanger(per Baker procedures) > Designed hanger setting pressure - 2800 psi Y Confirm hanger set Y Pick up to the high circulation point, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. Watch for cement returns and record the estimated volume in the OpenWells morning report Hydraulic Design for Liner Hanger Setting Procedure BHI Description No. Pins -15%(psi) Nominal(psi) +15%(psi) psi/screw Solo Plug 2 821.1 966 1110.9 483 LNR HNGR 7 2040 2500 2760 400 HRD-E 7 2832.2 3332 3831.8 476 Rotating Dog Sub 9 37,485 lbs 44,100 lbs 50,715 lbs 4,900 lbs/screw NOTE:Pressure could change depending on well conditions 10. Release running tool, set liner top packer and circulate above liner top packer. Y Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Well: F-13B Version: 1.0 23 Operations Program Note: If the HRD-E tool cannot be pulled after hydraulic release sequence, the following mechanical back up release procedure should be followed. This requires left hand torque to shear a set of shear pins in the housing. With the HRD-E running tool in the neutral position apply sufficient left hand torque to shear the secondary release pins. Work string up and down as necessary to get torque down to HRD-E running tool. Apply secondary set down weight at the tool to shear secondary release mechanism. Rotate back to the right and apply 15k ft-lb to ensure Drill Pipe did not back off during the releasing sequence. Pick up to release HRD-E tool ➢ Bleed pressure to zero to check float equipment. ➢ Pick up, verify setting tools is released, and expose setting dogs, establish rotation at 15-20 RPM ➢ Slack off 50k lbs minimum downhole to set LTP ➢ RD cementing head/equipment as required. ➢ Pressure up drill pipe to 500 psi and pick up to remove the RS pack off bushing from the RS nipple. Bump up pressure as required to maintain 500 psi DPP while moving pipe until the pressure drops rapidly; indicating the pack off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at the liner top). ➢ Immediately with the loss of pressure and before DPP reaches zero initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. ➢ Pick up to the high-rate circulation point above the Tieback Extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. Watch for cement returns and record the estimated volume in the OpenWells morning report. ➢ Verification that the liner top packer received the required setting force will be performed by inspecting the rotating dog sub once POOH ➢ Report any circulation or job issues in Open Wells. 11. POOH and inspect and LD liner running tools ➢ Per CRT-AK-10-10: 5.3.7: Flow check well for 10 minutes to confirm no flow: • Before pulling off bottom. • Before pulling the BHA through the BOPE. ➢ Record type, volume, density, if there was any losses or cementing problems, and whether cement reached surface in detail in OPENWELLS. Also, report lift pressures, whether the actual lift pressure was within 15% of the predicted lift pressure in the CemCade provided by SLB, and estimated TOC based on the pressure 12. If the cement job on this 7" liner goes per plan and without major losses, the estimated TOC will be based upon lift pressures and/or verification of cement being circulated out of the liner top and recorded in Open Wells. NOTE: Record type, volume, density, if there was any losses or cementing problems, and whether cement reached surface in detail in OPENWELLS. Also, report lift pressures, whether the actual lift pressure was within 15% of the predicted lift pressure in the CemCade provided by SLB, and estimated TOC based on the pressure. 13. Change the 7" rams back to 2%" x 51/2' VBR's and test 250 psi low / and 3500 psi high. (Reference attached F-13B Pressure Testing Document (#7)). NOTE: While changing-out the upper rams, circulate the across the top of the well below the blind rams using the choke and kill lines to make sure the hole stays full. Changes to barriers to change out rams: Wellbore I Closed blind/shear rams, Kill weight fluid Well:F-13B Version: 1.0 24 Operations Program Changes to barriers once 7"rams are installed: Wellbore I BOPE, Kill weight fluid 14. Allow sufficient cement setting time (500 psi tail compressive strength) for the pressure test. Pressure test the 7" Liner to 250 low for 5 min and 3500 psi high for 30 min (Reference attached F-13 Pressure Testing Document (#13)) THIS SHOULD BE CONSIDERED A CRITICAL STOP POINT IN THE WELL ✓ TO CONFIRM THE RESULTS OF THE 7" LINER INTEGRITY. DO NOT PROCEED WITH ANY PATH-FORWARD OPERATIONS WITHOUT WTL AUTHORIZATION. Well:F-13B Version: 1.0 25 Operations Program 4.4. Drill 61/8" Production Hole Reference Documents: • "Leak-off and Formation Integrity Tests"SOP • "Directional Surveying and Anti-Collision Management"SOP • "Rig Operations on High GOR/vishak and Gas Pad Injection Wells"SOP • "The Shublik Phenomenon"-RP Verify Start-up Checklist: ❑ Perform pre-job safety meeting. Ensure safety valve and cross-overs are on rig floor in the event of unexpected well flow Issues and Potential Hazards: • High GOR well: 290 bbls of extra fluid volume on location will be a requirement for this interval of the well. • BOP Test interval for this section is 7 days: To comply with state regulations, record mud weights in and out each tour and ensure BORE function test are performed and recorded in OpenWells before the 7 day deadline. • Directional plan: potential inability to achieve high DLS in high concentration of conglomerate/chert drilling. Moderate DLS planned incorporated into well trajectory • Lost Circulation: target circles are designed to maintain 200' standoff from major east/west faults and 100' standoff from smaller faults mapped near the TSGR casnig point. Lost circulation is considered moderate risk. • A negative pressure test on the 7" liner top will be required prior to drilling out the shoe. • Conglomerate/chert drilling: high risk of excessive bit wear may result BHA additional trips General Overview: A. Drillpipe - Use 4" drillpipe to drill this interval of the well. Utilize Parker 272's ability to build stands off-line to provide sufficient drillpipe to TD the well at -9,622' MD. 4", 14.0#, HT-38, 'S-135' (Adjusted weight: 15.71 ppf) OD: ID: Collapse: Burst: Torsional: Tensile: 100% 4" 3.34" 13,800 psi 18,400 psi 29,400 lbs 403,500 lbs 80% 4.875" 2.563" (tool joint) 11,040 psi 14,720 psi 23,520 lbs 322,800 lbs (tool joint) ***Max Recommended MU Torque: 17,700 ft-lbs Fluid Capacity: 0.442 gal/ft ***Recommended MU Torque: 17,700 ft-lbs ***Min Recommended MU Torque: 12,200 ft-lbs Fluid Displacement: 0.240 gal/ft B. Pumps: 2 12-P-160 Mud Pumps with 6" liners rated to 4670 psi (max flow-rate at 105 spm at 93% efficiency= -882 gpm) C. Bit Recommendations Bit Hole Size Depths(MD) TFA(in2) Bit Type Number 61/e" 9035—9622 ft MD 0.383 Baker Hughes 6 1/8"VM-R18DVH 2 61/8" Back up 1 0.383 Smith 6.125" XR20 Well: F-13B Version: 1.0 26 Operations Program D. BHA Recommendation BHA# Motor Size and Motor Required Flow Rate RPM Required Doglegs 1 43/4"BH Ultra X-treme Mud Motor, 1.5 deg 250-300 gpm 40-90 6.38 deg/ 0.33 rev/gal 100' ITEM EQUIP. GAUGE BODY BODY DOWN UP UNIT ACCUM. NO. DESCRIPTION PROVIDER OD OD ID CONN CONN LENGTH LENGTH 1 6 1.8"Tncone HCC 6.125 3 1i2 Reg 1.02 1.02 2 4 314"Ultra X-frame LS 6"1361-15(1.5 AKO wiFloat) BHI 6.000 4.75 3 12"Reg B 3 112"IF B _ 22.00 23.02_ 3 6"NM Strang Stab BHI 6.000 4.75 2.25 3 1.2"IF P 31/2'IF B _ 5.73 28.75 4 4 3/4'NMCSDP BHI 4.75 2.25 3 1/2'IF P 3 117 IF B 10.00 38.75 5 NM Stop Sub BHI 4.75 2.25 3 1.2"IF P 4 34"T213 1.44 40.19_ 6 Ontrak(GamiResPres.VSS.ISurvey) BHI 4.75 2 a8 4 34"T2 P 4 34'T2 B 19.97 60.16 7 6'Mod Stab BHI 4 75 2.81 4 34'T2 P 4 34'T2 B 3.22 63.38 8 BCPM(Pulsed BHI 4.75 3.00 4 34"T2 P 4 3.4'T2 B 10.97 74.35 9 SDN(Density NeutorniCaliper) BHI 4.75 2.38 4 3/4"T2 P 4 34"T213 1721 91.56 10 NM Stop Sub BIM 4.75 2 75 3 1.2"IF P 3 1/2"IF B 2.84 94.40 11 NM Filter Sub 8141 4.75 2.75 3 12 IF P 3 112"IF B 5.67 100.07 12 4 3.4'NMCSDP BHI 4.75 2.25 3 I 2"IF P 3 1/2"IF B 31.00 131.07 13 4 314"NMCSDP BHI 4.75 2.25 3 12"IF P 3 1/T IF B 31.00 162.07 14 4 34'NMCSDP BHI 4.75 2.25 3 1 2"IF P 3 VT IF B 31.00 193.07 15 Well Commander iWCMD 101) ^.:. 5.00 1.66 31`2"IFP 317 IF B 5.89 198.96 16 Steel XO _ BHI 4.75 2.81 3 1.7 IF P HT38 B 3.00 201.96 17 18 Joints 4"HWDP(28.244/ft Adjusted weight) RIG 4 375 TJ 4.00 2.56 HT38 P HT38 B 558.00 759.96 18 Drilling Jar-Hydraulic 1111.1k 4-875 2.25 HT38 P HT38 B 29.80 789.76 19 6 Joints 4'HWDP(28.24k/ft Adjusted weight) RIG 4.375 Ti 4.00 2.56 HT38 P HT38 B 186.00 975.76 20 4"S-135 DnII Pipe (15.62k/ft Adjusted weight) RIG 4.775 TJ 4.00 3.34 HT38 P HT38 B 8774.24 9750.00 21 - - - - 1 .1otes and Comments Target Flowrate from Dulling Program 250-300 gpm Max required Dogleg per plan 6.38 deg Motor RPM.49 rewgal E. Survey/ Logging Tool Requirements 6%"Section Survey and Logging tool requirements: MWD surveys corrected with IFR+MS and SAG corrected Open Hole Dir/GR/Res/Neu/Den (Real-Time/Recorded) e All MWD surveys will be corrected with IFR+MS and Sag Corrected. Surveys should be corrected as soon as enough have been collected to start analysis. Surveys will be "batch" corrected every 10 throughout entire 61A"interval. F. Drilling Fluids 6%" Production Hole Section Mud Properties: DIF Depth Safe Operating Envelope PV YP API fl. LSRV pH Drill MBT MD Mud Weight(p g) Loss Solids feet Min* Preferred** Max cP Ib/100ft2 ml/30 min Cp 15K- 9059'-Section TD 8.5 8.5-8.8 9.0 <12 15-25 <10 40K 9.5-11 <3% <4 "The lower limit represents the lower operating limit. " Any mud weight above the Preferred Mud Weight Range, which is listed in the Maximum Operating Range column, needs approval from both the ODE and WSL. Operation Steps: Well: F-13B Version: 1.0 27 Operations Program 1. The pipe ram requirements for this phase of the well will include 4"drillpipe. 2. Make up the 6%" 1.5°Motor Bend with Dir/GR/RES/NEU/DEN and RIH. Note : Non-Shearable equipment ➢ An insert bit with a 43/4' motor fitted with a kick pad and 1.5° bend should be used to successfully drill through this interval. 3. Displace the well to 8.5 ppg solids free DIF PRIOR to drilling out shoe track. 4. Conduct negative test on the 7" liner lap with the well displaced to the 8.5 ppg DIF drilling fluid (monitor well for 30 minutes for flow). (Reference attached F-13B Pressure Testing Document (#14)) THIS SHOULD BE CONSIDERED A CRITICAL STOP POINT IN THE WELL TO CONFIRM THE RESULTS OF THE 7" LINER CEMENT JOB. DO NOT PROCEED WITH ANY PATH- FORWARD OPERATIONS WITHOUT WTL AUTHORIZATION. 5. IF not previously done so, pressure test the 7" liner/well to 3500 psi for 30 min. (Reference attached F-13 Pressure Testing Document (#13)). THIS SHOULD BE CONSIDERED A CRITICAL STOP POINT IN THE WELL TO CONFIRM THE RESULTS OF THE 7" LINER INTEGRITY. DO NOT PROCEED WITH ANY PATH- FORWARD OPERATIONS WITHOUT WTL AUTHORIZATION. 6. Drill out the 7"shoe track and 20'-50' of open-hole. Changes to barriers once drilled out Wellbore I BOPE, Kill weight fluid 7. Perform a FIT as per the "Leak-off and Formation Integrity Tests" SOP. A minimum of 9.0 ppg EMW is required to satisfy the Kick Tolerance requirements for the well, however, a 9.8 ppg FIT should be targeted to satisfy the ECD management concerns for drilling this interval of the well. ■ An 9.0 ppg EMW FIT will provide an infinite kick tolerance assuming a maximum pore pressure gradient of 7.8 ppg, and the planned 8.5 ppg MW (ODE approval is required for this FIT value). ■ A 9.8 ppg EMW FIT will be required to provide effective ECD management. 8. Drill to TD at 9,622' MD ➢ All off-set wells pass major risk as they relate to the proximity of this planned well. ➢ Faults: Target circles are designed to maintain 200' standoff from major east/west faults and 100' standoff from smaller faults mapped near the TSGR casing point. ➢ Ensure that the directional driller is updating the traveling cylinder plot per BP directional guidelines and sent to the town ODE each day. After each survey is taken, the as-drilled position of the well will be marked on the anti-collision diagram. (4.10 BP Directional Survey Handbook). Well:F-13B Version: 1.0 28 Operations Program ➢ The lost circulation potential for this well has been categorized as "moderate"; follow the lost circulation decision tree provided in the MI mud section if lost circulation occurs • Do not exceed rotating hours limit on bit/ BHA (to be specified per actual tools run in hole) • Monitor drilling parameters closely for indications of bit wear in chert / conglomerate formations. • Connection Practices: Back-ream full stand at drilling rate (this may be reduced as we get deeper in the well) as required/allowed. Ream down with 100 rpm and 75% drilling flow rate to reduce surge effects 9. POOH and LD drilling assembly ➢ Circulate the hole clean (2-3 BU) and POOH to lay down the build assembly ➢ At TD give the BHCT to Schumberger for cement design ➢ Flow check well for 10 minutes to confirm no flow: ➢ Before pulling off bottom. ➢ After pulling into the casing window/shoe. ➢ Before pulling the BHA through the BOPE. ➢ Record in OpenWells the number of bottoms up, final slack off, rotation weights and torque values again prior to POOH ➢ If deemed necessary by the ODE, spot a clean liner running pill as per the mud companies recommendations in attached mud program on final TOH if no back- reaming is required/planned ➢ Function Well Commander open and circulate at maximum flowrate once bit pulled 1 stand above 7" liner top. POOH Strategy: ➢ If backreaming is necessary or if significant MAD-pass work is required: ➢ Condition mud and circulate at least 2-3 bottoms up to clean up hole at -250 gpm and max RPM to clean-up the well ➢ Mad-pass/back-ream to the 7" shoe as required. ■ MAD Pass speed (1 data point per foot) - 600 ft/hr (confirm mad pass requirements and strategy with Geos and Baker Hughes). ■ Back-reaming speed - 1000 ft/hour based upon hole conditions. • If hole appears in good condition: continue to pull inside the 9%" cased hole and circulate the hole clean at max GPM and -60 RPM and TOH for the production liner. If hole appears in bad or questionable: run back to bottom from the 7" shoe and circulate the hole clean at 250 gpm at 100 RPM (2-3 bottoms up or until shakers clean up) and TOH on elevators back to the 7" shoe if possible. If there is signs of packing-off while tripping, RIH 3 stands and circulate to clean up the hole. Back-ream as necessary. NOTE: once back-reaming has started do not stop until to the shoe. • If hole appears in good condition: once inside the 9%" cased circulate the hole clean at max GPM and -60 RPM and TOH for the production liner. ➢ If trip out of hole was troublesome, contact ODE / WTL to discuss forward strategy ➢ If hole conditions look good or there is little need for MAD-pass work at TD: ➢ Circulate the hole clean with at least 2-3 bottoms up at -250 gpm at max RPM to clean-up the well. Well: F-13B Version: 1.0 29 Operations Program > TOH on elevators back to the 7"shoe if possible. ➢ If there is signs of tight hole while tripping, RIH 3 stands and circulate to clean up the hole. Backream as necessary. NOTE: once backreaming has started do not stop until to the shoe ➢ If trip out of hole was troublesome, contact superintendent to discuss forward strategy > Pull back inside 9%" cased hole and circulate hole clean at max rate and 60 RPM Note: Drill pipe must be drifted before drop the plug for 41" liner cementing. Min required drift size=2,000" ➢ Once at surface, LD the 6W drilling assembly, record any BHA balling, abnormal wear, etc. in OpenWells Well: F-13B Version: 1.0 30 Operations Program 4.5. Run & Cement 41/2" Production Liner Reference Documents: • GP 10-60 Zonal Isolation • Schlumberger Cement Program Verify Start-up Checklist: ❑ Perform pre-job safety meeting. Issues and Potential Hazards: • High GOR well —290 bbls of extra fluid volume on location will be a requirement for this interval of the well. • BOP Test interval for this section is 7 days - To comply with state regulations, record mud weights in and out each tour and ensure BOPE function test are performed and recorded in OpenWells before the 7 day deadline. If contingency perforating operation will be performed then ensure that last pre-perforation BOP test includes 2-7/8" test joint both for VBR's and the annular preventer. • Review Lab field blend report and send to ODE. Field blend values should be within the acceptable ranges • Differential sticking is potentially a problem if lost circulation occurs or if the liner is left stationary across permeable formations. Proper liner centralization and keeping the pipe moving will facilitate minimizing the potential for differential sticking. • A detailed rig procedure will be required to ensure there is a plan in place to accurately track all fluid volume through this interval of the well (bbls in versus bbls out). General Overview: A. Liner/Casing Information 41/2",12.6#,13CR-85,VT Collapse Burst Tensile ID Make-up Torque 100% 7,500 psi 8,430 psi 288,000 lbs 3.958 Min - 4000 80% 6,000 psi 6,744 psi 230,400 lbs 3.833(drift) Max - 4880 B. Drillpipe Information 4", 14.0#, HT-38, 'S-135' (Adjusted weight: 15.71 ppf) OD: ID: Collapse: Burst: Torsional: Tensile: 100% 4" 3.34" 13,800 psi 18,400 psi 29,400 lbs 403,500 lbs 80% 4.875" 2.563" (tool joint) 11,040 psi 14,720 psi 23,520 lbs 322,800 lbs (tool joint) ***Max Recommended MU Torque: 17,700 ft-lbs Fluid Capacity: 0.442 gal/ft ***Recommended MU Torque: 17,700 ft-lbs ***Min Recommended MU Torque: 12,200 ft-lbs Fluid Displacement:0.240 gal/ft C. Cement Basis Casing Size: 41" 12.6#, 13CR-80, VT Production Liner Basis: Lead: None Tail: Volume of open hole+30%excess+85' shoe track+ 150' 41/2"x7" liner lap+200' of 7"x4" DP excess or 25 bbls of cement whichevers greater. Tail TOC: 8881' at TOL (excess cement will be circulated out.) LTotal Cement Spacer 25 bbls of Viscosified, weighted Spacer (Mud Push II) olume: Lead N/A Tail 25 bbls, 140 cuft, 120 sks 15.8 lb/gal Class G + adds— 1.17 cuft/sk Temp BHST=203°F, BHCT 150°F TBD by Baker Hughes MWD Well: F-13B Version: 1.0 31 Operations Program Operation Steps: 1. The pipe ram requirements for this phase of the well will include 4" drillpipe and 41/2" liner. VBR tests will include both 4" and 4.5" test joints and the annular preventer shall include 4" test join. 2. RU to run liner. THIS SHOULD BE CONSIDERED A CRITICAL STOP POINT TO CONFIRM THE 7" LINER WBE ACCEPTANCE FORM HAS BEEN APPROVED. DO NOT PROCEED WITHOUT ODE AUTHORIZATION. 3. Ensure safety valve to this 41/2"VT production liner is on the floor. 4. MU and RIH with the following proposed liner configuration (Torque turn all connections): Nom Size Item lb/ft Material Thread Notes 41" Float Shoe 12.6 13CR VT Baker-Lock 41/2" 40'Joint 12.6 13CR VT Baker-Lock 41" Float Collar 12.6 13CR VT Baker-Lock 41/2" 40'Joint 12.6 13CR VT Baker-Lock 41/2" Insert Landing Collar 12.6 13CR VT Baker-Lock 41/2' 40'Joints as needed 12.6 13CR VT 5.0" Crossover Sub 5.0" X 41/2" 15.00 13Cr-80 VT HT 5.0" Baker Flexlock DG Hanger(5"x7") 15.00 13Cr-80 VT HT 5.0" Baker RS Nipple 15.00 13Cr-80 VT HT Baker ZXP Liner Top Packer with 5.0" 10'Tieback Sleeve 15.00 13Cr-80 VT HT Baker HRD-E running tool and Rotating Packer Setting Dog Sub - Rotary 5.0" RS Packoff and Solo Plug System N/A Conn. 4" 4" 14 ppf HT-40 DP 15.71 S-135 HT38 Note : Non-Shearable equipment t '. • Sufficient 41/2" liner will be run to extend -150' into the 7"shoe y Thread Compound: Jet Lube Seal Guard thread compound on Vam-Top threads and MU per recommendation • Centralization: • Run 1 OMD hydro-form centralizer on joint #1 locked-down -5' above the liner shoe. • Run 1 OMD hydro-form centralizer on joint#2 locked-down at mid-joint. • Run 2 OMD hydro-form centralizers per joint from joint#3 up with a stop-ring (set screw torque to -30 lbs) in between except for 50' above and below the 7"shoe. Well: F-13B Version: 1.0 32 Operations Program Liner Running Procedure ➢ Check to see if floats are holding. (Float Check Procedure: Pump through/fill shoe track with mud/brine to ensure pump-thru capability. PU shoe track and drain fluid level thru the floats into well. Run shoe track back into well and visually confirm no back-flow into the shoe track.) ➢ Break circulation after liner is fully picked up and note weight of liner in mud. ➢ Keep liner full while running in hole(on the "fly"/top-off every 10th joint). ➢ Monitor pick up and slack-off weights while running in hole. Record hanging weight, PU and SO weights every 10 joints and 5 stands. Maximum pull at the liner is 80% of the pipe yield. ➢ RIH with liner on DP no faster than 1 minute per stand (90-100 ft/min) to 7" shoe. Watch displacement carefully and adjust running speed accordingly. • Screw into every 10 stands and fill pipe while lowering to the floor • Pick up and set down slowly in and out of slips • Circulate 1.5 drill pipe and liner volumes at the 7" shoe prior to going into open hole. Stage pumps up to a max of 6 BPM if no losses are seen. Do not exceed 1500 psi circulating pressure (confirm with Baker procedure). • Obtain up and down weights of liner before entering the open hole. ➢ Run in open hole at optimum speed • Use real time swab/surge modeling for optimizing tripping speed • Monitor fluid returns and adjust running speed as required to minimize/eliminate losses. • Record up and down weights and compare against I-center broomstick plot. • If liner run has been troublesome, contact ODE/Superintendent immediately. • If hole conditions have been good, run last stand to within 30' of bottom. Space out cement head on last joint down, allowing adequate height for reciprocation. • Tag up on bottom and pull back up to position the shoe 2' off bottom. ➢ Position the liner hanger/packer assembly ±150-ft above the intermediate casing shoe such that the hanger/packer is not set at the previous casing float or landing collar. ➢ Stage pump rates up slowly to 6 BPM allowing pressures and drag trends to stabilize at each pump rate increase and circulate a minimum of 10 open hole x 41/2' liner volumes at the desired cementing rate. Reciprocate string during all circulation and cementing operations if hole conditions permit, discuss with ODE repercussions of sticking liner off bottom. Restrict reciprocation to 15 ft strokes each way. • Do not exceed circulation pressure of 1500 psi 5. Rig up cementers and have a PJSM with all involved parties ➢ Pressure test all cement lines to 250 psi low and 4500 psi high for 5 minutes (Reference attached F-13B Pressure Testing Document(#15)) ➢ This 41" drilling liner will be cemented using the volumes as stated above in the general overview ➢ Do not exceed 6 BPM (or 70% of the minimum hanger setting pressure, -1500 psi per Baker procedure) while circulating hole prior to cement job Well: F-13B Version: 1.0 33 Operations Program 6. Before cement job: Review the CemCADE with the Schlumberger cementing representative Cement Analysis: The field blend tests slurry testing shall be conducted with as-drilled well conditions. The cement analysis results shall be received before pumping the cement job. The WSL shall verify that the cement slurry testing conforms to the requirements for the job type state in the table below: Tail Cement Job Requirements: Thickening Time: TBC Fluid Loss: <50 ml Free Fluid: Zero or trace Testing Requirements: Job Type Slurry Pump Compressive Operating API Fluid Rheology BP Settlement Time Strength Free Water Loss Test Production Liner Tail Yes Yes Yes Yes Yes Yes 7. Cement as per recommended practice at volumes specified ➢ Pump the cement job per the most current SLB plan ➢ This will be a single stage cement job (confirm all volumes associated with cement job). ➢ LCM will be considered if lost circulation potential jeopardizes the potential success of this cement job. ➢ Reciprocate the liner -20' strokes at 2 sec/ft during the cement job to help with mud displacement. ➢ NOTE: Cement as per SLB pump schedule to ensure ECD's do not exceed frac gradient. Watch pump rates and follow pumping schedule (do not try to "catch" up to cement). ➢ A hi-vis perforation pill will be spotted in the 41/2"liner as per mud program. • Kick-out the drillpipe dart with the perf pill. • This high viscosity pill is designed to minimize fluid loss to the perforations and/or "sanding" in the guns after perforating the well. • The volume of this pill should equal the liner volume plus -20 bbls (confirm with mud engineer). ➢ Report any circulation or job issues in OPENWELLS. ➢ -2 bbls before calculated plug bump, slow pump rate down to 1/2 bpm ➢ Continue pumping until wiper plug bumps, but do not over displace by more than 1/2 the shoe track volume 8. Follow the steps of the Baker procedure to set the packer and circ out the excess cement with the HRD-E running tool (CONFIRM WITH BAKER) ➢ Pressure up to 2800 psi over to set the liner hanger ➢ Slack off total liner weight plus 50k downhole to confirm hanger set ➢ Increase pressure to release HRD-E running tool ➢ Bleed pressure to zero to check float equipment Well:F-13B Version: 1.0 34 Operations Program ➢ Pick up and expose setting dogs on top of Tieback Sleeve. ➢ Rotate slowly(10-20 rpm) and slack off 30K lbs minimum downhole to set ZXP ➢ Pressure up drill pipe to 500 psi and pick up to remove the RS pack off bushing from the RS nipple. Bump up pressure as required to maintain 500 psi DPP while moving pipe until the pressure drops rapidly, indicating the pack off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at the liner top). Hydraulic Design for Liner Hanger Setting Procedure BHI Description No. Pins -15% Nominal 15% psi/screw Solo Plug 2 1118.6 1,316 1513.4 654 LNR HNGR 7 2168 2550 2933 364 HRD-E 8 2808.4 3304 3799.6 413 Rotating Dog Sub 6 24,990 lbs 29400 lbs 33,810 lbs 4,900 lbs/screw ➢ Immediately with the loss of pressure and before DPP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. ➢ Pick up to high circulation point, mark pipe for reciprocation, do not retag the liner top and circulate the well clean. Watch for cement returns and estimate the volume on the morning reports. ➢ If plugs do not bump, refer to BOT service personnel for secondary releasing procedure (left hand release for HR tool). • Circulate out excess cement off of liner top and estimate and report the volume in OPENWELLS ➢ Increase pump rate, reciprocate and continue circulation at maximum rate until all excess cement returns (a minimum of 2 BU is required). ➢ Following circulation of all excess cement from the well, displace the well bore, above the liner hanger, to clean seawater. 9. POOH racking back drill pipe as necessary. LD running tool assembly + excess DP ➢ Verify the liner top packer received the required force by inspecting the rotating dog sub Flow check well for 10 minutes to confirm no flow: • Before pulling off bottom. • Before pulling the BHA through the BOPE. 10. Test casing and liner 250 psi low/3500 psi high for 30 minutes. Do not test until cement has a minimum of 1,000 psi compressive stress. (NOTES: If wait time is required to get the 1000 psi compressive strength, move forward with running the perf guns into the hole and the liner can be tested with the perf guns on depth - CONFIRM WITH ODE.) (Reference attached F-13B Pressure Testing Document (#16)) THIS SHOULD BE CONSIDERED A CRITICAL STOP POINT IN THE WELL TO CONFIRM THE RESULTS OF THE 41/2" LINER. Changes to barriers once 41/2" liner is pressure tested: Wellbore BOPE, Cemented/tested liner, Kill weight fluid Well: F-13B Version: 1.0 35 Operations Program 4.6. Perforate 41/2" Production Liner (Contingency) Note: The base plan is to perform perforation during post rig operations. Perforation will be performed with the rig if post rig operations will delay putting well on production. Verify Start-up Checklist: ❑ Perform pre-job safety meeting. Reference Documents: • "Drill Pipe Conveyed Perforating"RP Issues and Potential Hazards: • High GOR well—290 bbls of extra fluid volume on location will be a requirement for this interval of the well. • BOP Test interval for this section is 7 days -To comply with state regulations, record mud weights in and out each tour and ensure BOPE function tests are performed and recorded in OpenWells before the 7 day deadline • The well will be perforated overbalanced. Expect to lose fluid to the formation after perforating. Be prepared with LCM if necessary. • Schlumberger's 2'/" 2906 Power Jet guns, loaded with 6 spf (60 degree phasing) will be utilized to perforate this well. Initial planning requests approximately 300' of perforations. Exact perforation depths will be provided and confirmed by ODE/PE/Geo after reviewing the LWD logs. • A detailed rig procedure will be required to ensure there is a plan in place to accurately track all fluid volume through this interval of the well (bbls in versus bbls out). Operation Steps: 1. The pipe ram requirements for this phase of the well will include 4"and 2'/e"drillpipe. 2. Test VBR's and annular preventer with a 2'/8"test joint if not done already. ➢ Test rams to 250 psi low / 3500 psi high for 5 minutes. (Reference attached F-13B Pressure Testing Document(#7)) 3. RIH with the perforating assembly as follows: (Confirm with SLB) > TCP bullnose 2.88" HSD • TCP 2.88" 2906 Power Jet High Shot Density Guns (length as determined by feet of perfs desired) ➢ TCP"eFire" Electronic Firing Head, Length— 12.67' ➢ TCP Long Shot Debris Sub—Length 1.74' ➢ Baker Disconnect with %"seat—Length 11.50' • 2%" PAC drillpipe to extend from top shot to above 41/2" liner top > XO—2%" PAC drillpipe x 4"HT38 DP • 4" HT38 DP to surface Note : Non-Shearable equipment 4. Space-out guns by tagging the landing collar and then spacing out on the up stroke, or running a no-go for the liner top packer. Well:F-13B Version: 1.0 36 Operations Program 5. IF the production liner has not been tested, pressure test the liner at this time to 3500 psi for 30 minutes (assuming 1000 psi compressive strength on the cement). (Reference attached F-13B Pressure Testing Document (#16)) 6. Perforate the well per Schlumberger procedure: • Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. ➢ An electronic firing head will be utilized, ensure that all Schlumberger procedures for arming and firing the guns are followed. • A 21" hydraulic disconnect will be run above the firing head as a contingency for fishing purposes. Changes to barriers once perforated: Wellbore BOPE, Kill weight fluid 7. Immediately after firing guns, POOH while keeping hole full to get guns above top shot:: ➢ This will minimize sticking problems from possible sanding. ➢ Stop and monitor well for losses above the 41' liner and circulate a BU to clear the annulus if necessary. > Flow check well for 10 minutes to confirm no flow: • Above 41/2" liner. • Before pulling the BHA through the BOPE. 8. POOH, keeping the hole filled with clean seawater (8.5 ppg) while POOH. • Record fluid loss rate. 9. TOH and LD guns, verify all shots have fired: • Hydraulic tubing tongs fitted with 21", 2%"or 31/2"dies may be used and no backups will be used to spin out guns during rig down to minimize trapped pressure issues. • While LD guns non-shearable components will be placed across the BOP stack. Note : Non-Shearable equipment Well:F-13B Version: 1.0 37 Operations Program 4.7. Run 41/2" Completion Reference Documents: • "Completion Design and Running"RP Verify Start-up Checklist: ❑ Perform pre-job safety meeting. Issues and Potential Hazards: • High GOR well —290 bbls of extra fluid volume on location will be a requirement for this interval of the well. • BOP Test interval for this section is 7 days - To comply with state regulations, record mud weights in and out each tour and ensure BOPE function tests are performed and recorded in OpenWells before the 7 day deadline • Post rig e-line perforation: Base plan is to perforate well during post-rig phase. If cannot perf immediately post-rig confirmed, all necessary preparation shall be made for perforating with the rig or e-line on the rig prior running completion string. • Completions fluid: 8.5 ppg seawater will be used as the completion fluid for this phase of the well, ensure that the fluid is heated to 100 deg F. • The WLEG will be positioned 2'-4' above bottom of TBS. General Overview: A. Tubing Information 41/",12.6#, 13CR-85,VT Collapse Burst Tensile ID Make-up Torque 100% 7,500 psi 8,430 psi 288,000 lbs 3.958 Min —4000 80% 6,000 psi 6,744 psi 230,400 lbs 3.833(drift) Opt - 4400 Max - 4880 B. Wellhead Equipment Needed Tubing Spool 13%"5K x 13%"5K PN 2049645-01-01 CAT ID 67827-X *Replacement spool Tubing Hanger 12 x 41/2'TC-ll w/Type "H"back pressure valve profile PN 2221338-02-01 BP CID 282293-X *Same as the existing Tubing Hanger Tubing Head Adapter 13%" 5K x 4-1/16"5K PN 2024164-03 CAT ID 67901-X *Same as the existing Tubing Head Adapter Operation Steps: 1. The pipe ram requirements for this phase of the well will include 41/2'tubing. 1.1.1.Test VBRs and annular preventer with 4.5"test joint if not done already 2. MU and RIH with the 41/2" 12.6#, 13Cr-85, Vam-Top production tubing • The completion , as designed, will be 41/2", 12.6#, 13CR-85, Vamp-Top production tubing string which will sting into the 41/2" production liner tieback sleeve • Run completion a follows: Nom. Item Lb/ft Material Thread Notes Size 41/2" WLEG 12.6 9 Cr VT 41" 10' Pup Joint 12.6 13 Cr VT Well: F-13B Version: 1.0 38 Operations Program Nom. Item Lb/ft Material Thread Notes Size 41/2" "XN" nipple , 3.725" 12.6 13 Cr VT with RHC plug 41" 20' Pup Joint 12.6 13 Cr VT 41/2" 40' Joint 12.6 13 Cr VT 41/2" 10' Pup Joint 12.6 13 Cr VT 41/2" "X" nipple, 3.813" ID 12.6 13 Cr VT 41/2" 20' Pup Joint 12.6 13 Cr VT 41/2" 10' Pup Joint 12.6 13 Cr VT 7"x 41/2' HES TNT packer 12.6 9 Cr VT 41/2" 20' Pup Joint 12.6 13 Cr VT 41/2" 10' Pup Joint 12.6 13 Cr VT 41/2" "X" nipple, 3.813" ID 12.6 9 Cr VT 41/2" 20' Pup Joint 12.6 13 Cr VT 41/2" 40' Joints as needed 12.6 13 Cr VT 41/2" 10' Pup Joint 12.6 13 Cr VT 41" "X" nipple, 3.813" ID 12.6 9 Cr VT Placed at -2000' 41/2' 20' Pup Joint 12.6 13 Cr VT 41/2' 40' Joints as needed to surface 12.6 13 Cr VT 4 GLMs total Use 10' Handling pups. Setting depths to be 4/2' (5)4'/2" x 1" KBG-2 9 Cr advised Note : Non-Shearable equipment • ➢ Thread Compound: Jet Lube Seal Guard thread compound on Vam-Top threads and MU per recommendation ➢ Torque turn all connections ➢ Baker-lock all connections below the packer ➢ Run the completion and space-out the WLEG to be positioned 2' - 4' above the bottom of the liner top TBS. ➢ Land the tubing hanger 3. Once tubing hanger is landed, run in the lock-down screws and torque as recommended by the wellhead representative. 4. With tubing spaced-out and landed, reverse circulate seawater surface to surface at a maximum of 4 bpm with clean seawater and inhibited brine as follows: ➢ Seawater and brine temperature should be maintained in range of 90-120 deg F ➢ Clean seawater on annular side on the tubing side from the WLEG to surface ➢ Clean seawater from the production packer down to the WLEG ➢ Inhibited seawater on the annular side from the GLM/shear valve to the production packer • Clean sweater on the annular side from surface down to the GLM/shear valve • At the end of this displacement continue to reverse in an additional 5 bbls of clean seawater ➢ With the 5 bbls of over-displacement complete, put the fluids back in place by pumping 5 bbls of clean seawater down the tubing to clean the face of the RHC plug before dropping the ball and rod Well: F-13B Version: 1.0 39 Operations Program 5. Drop the ball and rod to RHC plug. 6. Set the packer and then test the tubing to 250 psi low/ 3500 psi high for 5 / 30 minutes at 250 psi low/3500 psi high (Reference attached F-13B Pressure Testing Document (#17)) 7. Slowly bleed tubing pressure to 1500 psi and test the inner annulus and the packer to 250 psi low / and 3500 psi high for 5 / 30 minutes (Reference attached F-13B Pressure Testing Document (#18)) THIS SHOULD BE CONSIDERED A CRITICAL STOP POINT IN THE WELL TO CONFIRM THE RESULTS OF THE 41/2" TUBING INTEGRITY. DO NOT PROCEED WITH ANY PATH-FORWARD OPERATIONS WITHOUT WTL AUTHORIZATION. 8. Bleed all pressure from tubing and increase annulus pressure as required to shear the DCR- 1 valve and confirm 2-way circulation through the valve 9. Install a TWC. Test the TWC to 3500 psi from above for 5 minutes to ensure a proper seat and to 2000 psi 30 minutes from below ➢ (NOTE: the well must be monitored for 1 hour to confirm it is "static" prior to the installation of the TWC. The time spent pressure testing the tubing and IA (2 - 30 minutes tests) can be part of this 1 hour monitoring process assuming the fluid volumes required to pressure up the well and bleed off the well were recorded and volume to pressure-up equals volume to bleed-down). (Reference attached F-13B Pressure Testing Document(#19 &20)) Changes to barriers once tubing and IA are pressure tested: Wellbore BOPE, Kill weight fluid on Ball & Rod IA Production Packer, Kill weight fluid, Annular valves Well: F-13B Version: 1.0 40 Operations Program 4.8. ND/NU Release Rig Reference Documents: • "Pad Inspection"SOP • "Criteria for Breaking Containment'STP • "Rig Handover Form and Well Work Transfer Form Process"SOP • "Rig Move and Initial Rig Placement"SOP Verify Start-up Checklist: Ei Perform pre-job safety meeting. Issues and Potential Hazards: • BOP Test interval for this section is 7 days - To comply with state regulations, record mud weights in and out each tour and ensure BOPE function test are performed and recorded in Open Wells before the 7 day deadline • Diesel will be used to freeze protect the well. The diesel flash point is 100 degrees F. Diesel vapor pressure is -0.1 psia at 100 degrees F. General Overview: A. Outlet configuration a. Single gate valve with a blind flange and a needle valve on 1 side outlet of the IA b. A blind flange with a VR plug on the other side outlet on IA c. Single gate valve with a blind flange and a needle valve on 1 side outlet on the OA d. Blind flange with a VR plug on the other outlet on the OA B. Barriers for RDMO Prior to ND BOPE/NU Tree Tubing Side TWC tested from below to 2000 psi KW fluid on top of ball and rod in RHC profile Inner Annulus Tested production packer (tested to 3500 psi), KW fluid, and casing annulus valve Prior to Rig Move Tubing Side: Tree, KW fluid on top of ball and rod in RHC profile and tested BPV to 2000 psi from below Inner Annulus Tested production packer (tested to 3500 psi), KW fluid, annular valve Operation Steps: 1. Nipple Down the spacer spool and BOPE 2. Nipple up and test the adapter flange and the tree to 250 psi low/5000 psi high for 5 minutes low and 10 minutes high. (Reference attached F-13B Pressure Testing Document (#21)). 3. Rig up and pressure test lubricator 250 psi low/3500 psi high for 5 min on both the low and high test (Reference attached F-13B Pressure Testing Document (#22)). 4. Lubricate out the TWC (Notify WTI Program Lead at 659-5085 for wellhead height and equipment measurements) 5. Reverse circulate through the shear valve in the upper GLM a sufficient volume of diesel to freeze protect the well on both sides of the tubing to 2200' MD. Allow diesel to U-tube from annulus to tubing and equalize. (NOTE: with a static column of 2200' of 6.8 ppg diesel and 8.5 ppg seawater there is a '-375 psi over-balance to the formation) Well: F-13B Version: 1.0 41 Operations Program 6. Rig up and pressure test lubricator 250 psi low/3500 psi high for 5 min on both the low and high test (Reference attached F-13B Pressure Testing Document(#22)). 7. Set a BPV with tested with lubricator and test from below to 250 psi low/3500 psi high for 5 minutes on both tests Reference attached F-13B Pressure Testing Document(#23)) 8. Secure well and RDMO ➢ If annulus pressure is observed on the OA or IA than adhere to rig move SOP • There are no wells requiring surface shut-in in order to move off the well. Care should be taken while moving off the well. Spotters should be employed at all times > Blue Goo: The surface x conductor annulus will be pumped with a treatment of RG2401 (Blue Goo) to inhibit external casing corrosion post rig. Contact the CIC team AT 659-5766 to arrange for treatment 9. Close out the Wellwork Transfer Permit with Operations as per the Rig Handover Form and Well Work Transfer Form Process SOP ➢ The 2nd signed copy goes to the Issuing Authority and the signed off hard copy is taken to the Wells Group for permanent storage Well: F-13B Version: 1.0 42 Operations Program 5. Post Well Requirements 1. Complete a post-rig inspection with the Pad Operator prior to moving the rig. 2. Mail the master copy of the Operations Program into the town engineer along with IADC reports and pressure testing charts. 3. Email the following to the town engineer • Final Schematic • Completion Tally ➢ Well Handover Form Planned Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install generic GLV design 3. Perform Negative pressure test on the 7" liner top 4. Perforate well (if not done already) 5. ASRC flowback. Well: F-13B Version: 1.0 43 Operations Program 44 f STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL A,' 2.013 20 AAC 25.280 ''' 1. Type of Request: AOGCC ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ®Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 212-141 3 Address: ❑Exploratory 0 Stratigraphic Alaska 99519-6612 Numbe ®Development 0 Service P.O. Box 196612,Anchorage, 6. API 50.0029-229-2 0434-02-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU F-13B• Will planned perforations require a Spacing Exception? 0YesN 9. Property Designatior 10.Field/Pool(s): ADL 028280 Prudhoe Bay%Prudhoe Bay 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). 9071' —8907' 9071' —8907' / None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20"x 30" 110' 0 Surface 2665' 13-3/8" 2665' •.: 4930 2670 Intermediate 7575' 9-5/8" 7575' 6870 4760 Production Liner 1558' 7" 7400'-8958' '% : - 881 7240 5410 I. Perforation Depth MD(ft): Perforation Depth TVD(ft): tubing Si•+: Tubing Grade: Tubing MD(ft): None None 1 • : Packers and SSSV Type: None Packers and SSSV None MD(ft)and ND(ft): 12. Attachments: 1 W.I lass after proposed work: • ®Description Summary of Proposal 0 BOP Sket 0 Detailed Operations Program •` x ploratory 0 Stratigraphic ®Development 0 Service 14 Estimated Date for 15. W. '=tus after proposed work: Commencing Operation. March 21, -,\3 + . C4 O. ❑WINJ ❑WDSPL 0 Plugged 16. Verbal Approval: Date \`��\ V Ga 0 GINJ 0 GSTOR 0 Abandoned JCommission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to th- .e of m nowledge. Contact: Famil Mammadov,564-4135 Printed Name: hn Egbejimba Titl : gineering Team Leader Email: Famil.Mammadov@bp.com v \ Signature: /a/ / Phone: 564-5859 Date: Val/.2_0 0v, Commission Use Only Conditions of approval: Notify C•J; is- • so that a -presentative may witness Sundry Number: � 3 r 1 C/ , ./q ❑Plug Integrity 0 BOP Test 0 Mechanical I egrity Test 0 Location Clearance/ c/ /// Other r RBDMS APR 0 9 20�� f Spacing Exception Required? 0 Yes 0 No Subsequent Form Required: APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: Form 10-4( tree G211 A 4pproved application is valid for 12 months from the date of approval Submit In Duplicate, ,✓5 , I F-13B(PTD#212-141)Shutdown Plan: The original plan for F-13B well was to drill 8-1/2"hole section and set 7" liner shoe 5-10ft into Sag River formation. Reverse drilling break was observed at 8955 ft MD and return cutting samples collected from 8940-8960 ft MD contained up to 100%sand.These indications were interpreted as a formation change from Kingak to TSGR and TD was called at 8960 ft MD. The 7"liner was run and cemented successfully. While drilling through new formation below 7"liner geo samples indicated presence of Kingak shales. Decision was made to continue drilling 6-1/8" hole section until LWD tool was spaced out to verify formations.The logs indicated that top of Sag River formation was at 9015 ft MD,i.e. 65 ft MD deeper than originally thought.Overall,57 ft MD of Kingak shale formation was not isolated by 7"liner. Drilling of production hole section was stopped due to the high risk of shale instability with exisiting 8.5 ppg MW.The decision was made to pull 6- 1/8" BHA out of hole. Having considered multiple different options the decision was made to run and cement 4.5" liner to isolate Kingak Shales.The risk of drilling with existing MW can potentially result in loss of the sidetracked section of the well (with BHA lost in hole). Increasing MW and drilling further represents very high uncertainty of major losses.The proposed plan of isolating Kingak shales and suspending the well by Parker 272 rig is a compromise that would to reduce operational risk and primary SOR objective will be achieved by drilling further into reservoir utilizing a Coil Tubing Drilling rig, anticipated within 1 year.F-13B operations are planned to be suspended by Parker 272 rig after installation of 4.5"liner and upper completion string. Following barriers will be in place prior moving off location: Prior to NO BOPE/NU Tree Tubing Side TWC tested from below to 2000 psi KW fluid on top of ball and rod in RHC profile Inner Annulus Tested production packer(tested to 3500 psi), KW fluid,and casing annulus valve Prior to Rig Move Tubing Side: Tree,KW fluid on top of ball and rod in RHC profile and tested BPV to 2000 psi from below Inner Annulus Tested production packer(tested to 3500 psi), KW fluid,annular valve Regards, Famil Mammadov GWO I BP Alaska I Drilling Engineer—NWE Rotary Mobile:+1(907)306 7739 I Office:+1(907)564 4135 email:famil.mammadov@bp.com PIP 212 Ferguson, Victoria L (DOA) From: Lastufka, Joseph N [Joseph.Lastufka@bp.com] Sent: Friday, March 29, 2013 1:55 PM To: Ferguson, Victoria L(DOA) Subject: F-13B Operations Shutdown Wry1-1-dfraw svp7d'� 3 1 3 - 1411 Victoria, Due to other options,our request for Operations Shutdown can be withdrawn. Please let me know if you have any questions or require any additional information. As always, I appreciate all of your help! Thank you, Joe Lastufka Alaska Wells Technologist Cell: (907) 227-84961 Office: (907) 564-4091 4,N BP Exploration Alaskal900 E.Benson Blvd.1Room: 788D1Anchorage,AK 1 w\�O\� TAT �s7 THE STATE Alaska Oil and Gas °fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFti'b Anchorage, Alaska 99501-3572 ALAS-* Main: 907.279.1433 Fax: 907.276.7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-13B BP Exploration (Alaska), Inc. Permit No: 212-141 Surface Location: 1988' FNL, 2865' FEL, SEC. 02, T11N, R13E, UM Bottomhole Location: 320' FNL, 3774' FEL, SEC. 02, T11N, R13E, UM Dear Mr. Egbejimba: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Chair DATED this / day of October, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALAS OIL AND GAS CONSERVATION COMM, .ON S E f 1 1 2012 PERMIT TO DRILL 20 AAC 25.005 AO CC 1 a Type of work. 1 b. Proposed Well Class: ®Development Oil • ❑Service-Winl ®Single Zone . 1 c. Specify if well is proposed for: ❑Drill 0 Redd! 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑Re-Entry ❑Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 • PBU F-13B - 3. Address. 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 9749' TVD 9182' Prudhoe Bay/Prudhoe Bay . 4a. Location of Well(Governmental Section) 7. Property Designation(Lease Number). Surface. ADL 028280 . 1988' FNL, 2865' FEL, Sec.02,T11N, R13E, UM • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date. 299' FNL, 3818' FEL, Sec.02,T11N, R13E, UM December 15,2012 Total Depth. 9.Acres in Property: 14. Distance to Nearest Property. 320' FNL, 3774' FEL, Sec.02,T11N, R13E, UM 2560 18000' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 63.50' feet 15.Distance to Nearest Well Open Surface x- 651958 • y-5974812• Zone- ASP4 GL Elevation above MSL. feet to Same Pool: 1200' 16.Deviated Wells Kickoff Depth. 7567' feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle. 55 degrees Downhole: 3684 • Surface: 2775• 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8-1/2" 7" 26# L-80 VamTop 1659' 7400' 7278' 9059' 8742' 141 sx Class'G',85 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr80 VamTop 849' _ 8900' 8628' 9749' 9182' (91 sxClass'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft). Effective Depth TVD(ft)- Junk(measured): 10320' 9011' 8027',9776' 10255' 9014' None Casing Length Size Cement Volume MD TVD Conductor/Structural 110' 20"x 30" 8.5 cu yds Permafrost Concrete 110' 110' Surface 2665' 13-3/8" 3813 cu ft Arctic Set II 2665' 2665' Intermediate 8580' 9-5/8" 1164 cu ft Class'G', 130 cu ft Arctic Set I 8580' 8456' Production Liner 638' 7" 408 cu ft Class'G' 8032'-8670' 7910'-8546' Liner 2288' 2-7/8" 18.5 Bbls Class'G' 8028'- 10320' 7906'-9011' Perforation Depth MD(ft). 9400'-9920' Perforation Depth TVD(ft): 9035'-9031' 20.Attachments: 0 Property Plat ®BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval. Commission Representative: Date 22. I hereby certify that the foregoing is true and correct Contact Famil Mammadov,564-4135 Printed Nihn Egbejimba Title Engineering Team Leader UJ Prepared By Name/Number Signature94 €ft4X Phone 564-5859 Date 'lft� JZ Joe Lastufka,564-4091 / Commission Use Only Permit To Drill ' / I Nu r Permit Approv I Date See cover letter for Number =-1 Z t 7 ( 50-029-20434-02-00 I�li l other requirements Conditions of Approval: If box is checked,well may not be used to explore f test,or produce coalbed methane,gas hydrates,or gas contained shales [' Other. .c5-66. r,� f oP (-- (ih.t'' amples Req'd: ❑ es ET/No Mud Log Req'd. �❑YYes El/No R ce HZS Measures: L� es ❑No Directional Survey Req'd. "Yes 0 No C ;saa /5( • —O ) 7I 8o —7.--;sit-- CC4 J BY THE COMMISSION Date (0 --(Z - f2 OBRI1)(Aixcz,L_A_PPROVED I ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit In Duplicate's v To: Alaska Oil & Gas Conservation Commission 4114 From: Famil Mammadov .: b Drilling Engineer Date: September 10, 2012 L Re: F-13B Permit to Drill Z� j Well History: P'r r'°" F-13A is an oil producer well completed in Dec 1996. The initial perforations included Zn 1B and Zn • 2A near the toe. The gas rate steadily rose until reaching maximum GOR in Spring 1999, and then the well began cycling. STP/Borax/MCNL logs were run on 9/8/03. The Borax-CNL showed very little primary cement across the horizontal section from the toe of the well up above the perfs to 9350' MD. The Spinner log showed 43% of the flow coming in below the bottom perfs and past the liner shoe in Zn 2A. In March 2004, a CIBP was set at 9800' to shut off gas entry from the toe. The initial tests showed a decrease in gas rate,but the gas rate quickly returned to previous levels indicating the GSO was unsuccessful. In April 2009, 45' of adperfs were shot midway through the well in the lowest part of the Zn 1B lateral. Unfortunately, production did not change and the well continued to cycle. Currently, F-13A is Operable but shut-in for high GOR. Following pressure test have been performed to verify well integrity PPPOT-T passed 5,000 psi (3/21/12) MIT-IA passed 3,000 psi (5/13/12) MIT-T passed 3,000 psi with plug test at 8,027' MD (5/13/12) Reason for Sidetrack: F-13A is no longer a competitive producer due to high GOR, and there are no remaining well work options. The proposed sidetrack will access Zone 2C/3 reserves in the north-western GDWFI area of F-pad. Sidetrack Plan: Approximately 7700' of existing tubing will have to be cut and retrieved to allow a casing exit from the cemented 9 5/8" casing. An 8 1/2" intermediate hole is proposed to be drilled to the top of Sag River to be then isolated with a 7" 26# L-80 liner. A 6 1/8" hole will then be drilled from the bottom of the 7" targeting Ivishak Zone 2C/3. The production section is to be completed with 4 1/2" liner systems with top of cement planned to top of liner depth. The well will be perforated across Ivishak Zone 2C/3 and • tied to surface with 4-1/2" tubing string. MASP: 2819 psi (7.8 ppg pore pressure at 22TS). Pre-Rig Work: (scheduled to begin November 1, 2012) 1. Pull TTP 2. Perform injectivity test 3. Perform fullbore P&A with 15 bbls of 15.8 ppg Class G cement. Planned TOC at 8,000' MD. 4. D&T Cement. Drift for Jet Cut. 5. Integrity tests: MIT-T to 3,000 psi. MIT-IA to 3,500 psi. MIT-OA to 2,000 psi. 6. Jet cut tubing at 7,700' MD 7. Set BPV (and test) 9.11 Rig Work: (scheduled to begin on December 15, 2012) ?a'f 01 8. MIRU and test BOPE to 250 psi low and 3,500 psi high. :3 L 9. Pull and L/D 7"26# L-80 Tubing 10. Set 9-5/8" EZSV at- 7,545' MD and test to 3,500 psi 11. Set 9-5/8"whipstock and mill 8-1/2"window and 20' rathole with 11.0 ppg mud 12. Circulate well clean and perform FIT test --� �►�•. Fl i s It.'o/� CMS 13. MU and RIH with 8-1/2" Drilling BHA 14. Drill intermediate build section 8-1/2" OH 1,517' (3.5 deg/100 planned) GR/RES /MWD /GR at ,i bit with TD-5' into TSAG-9,060' MD 15. Install 7"rams in upper VBR cavity and pressure test to 3500 psi. 16. Run 7" 26# L-80 liner to TD and position top of liner 150' inside 9 5/8" casing. - I ' 17. Cement 7" liner to 1,500' above shoe with 15.8 ppg Class G cement. 18. Replace 7"rams to VBR 19. MU BHA and RIH to drill 6 1/8"production section. `1.4( - T 20. Drill production section: 6-1/8" OH, 690' (5 deg/100' planned) with GR/RES /MWD/NEU/ V DEN with TD 9,750' MD 21. Run and cement 4-1/2" 13-Cr liner leaving TOL 150' above 7" liner shoe with top of cement at TOL 22. Run 4-1/2" 13 Cr-80 tubing and install over 4-1/2" liner PBR 23. Freeze protect well 24. Set 4 1/2"production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 25. Install TWC and test. 26. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi. 27. RU DSM. Pull TWC. 28. Install a BPV, then the VR plugs in the annulus valves. 29. Secure, rig down and move off. Post-Rig Work: 30. MI/RU slick line. Pull the BPV. 31. E-Line perf well (30' total perforation length in Zone 2). 32. Re-install wellhouse and FL's. 33. Generic GLV's Famil Mammadov Drilling Engineer Office: 907-564-4135 Cell: 907-306-7739 Email: famil.mammadov@bp.com Attachments: Current Well Schematic Pre-Rig Well Schematic Proposed Well Schematic Directional Plan Rig BOP Schematic CC: Well File Sondra Stewman/Joe Lastufka Planned Well Summary et Well F-13B Well Producer Objective Ivishak . • API Number: 500292043401 Current Status Shut-In Estimated Start Date: 12/15/12 Time to Complete: 32 Days Surface Northing Easting Offsets TRS Location 5,974,812 651,958 3291.56' FSL 2864.92' FEL • T11N R13E S2 . TSAG Northing Easting TVDss Offsets TRS 5,976,197 651,470 -8,659 4686.91 FSL 3323.96 FEL T11N R13E S2 Production Northing Easting TVDss Offsets TRS Hole Target Location 5,976,481 650,969 -9,083' 4981.12 FSL 3817.84 FEL ' T11N R13E S2 Planned KOP: 7,567' MD/7,363' TVDSS Planned TD: 9,749' MD/9,100' TVDSS Rig: Parker 272 BF/RT: 34.6'/46.95' RTE: 81.550 Directiona -Schlumberger WP05 KOP: 7567' MD . Maximum Hole Angle: -46° in the 8-1/2" intermediate section -55° in the 6-1/8" production section • Close Approach Wells: All offset wells pass Major Risk Analysis Survey Program: SurveylPlan Program Tool From(ft) To(ft) 1 Sperry-Sun BOSS gyro multi(F-13) BOSS-GYRO 118 05 7518.05 Plan#5 F-13B(Plan F-13B) BOSS-GYRO 7518 05 7551.15 Plan#5 F-138(Plan F-13B) MWD 7551.15 9059.00 Plan#5 F-138(Plan F-13B) MWD+IFR+MS 7551.15 9059.00 Plan#5 F-138(Plan F-13B) MWD 9059.00 9749 37 Plan#5 F-138(Plan F-13B) MWD+IFR+MS 9059.00 9749 37 Nearest Property Line: 18,000' Nearest Well within Pool: 1,200 Formation Tops & Pore Pressure Estimate (SOR) Estimated Depth Fluid Most Likely Minimum Maximum Formation Formation Top Uncertainty Type Pore Pressure Pore Pressure Pore Pressure (TVDss) (+1-TVD ft) (for sands) (EMW ppg) (EMW ppg) (EMW ppg) LCU 7,344.0 0 9.70 9.60 9.90 KOP 7,364.0 0 9.70 9.60 9.90 TJF 7,635.0 10 9.70 9.60 9.90 TJE 7,795.0 10 9.70 9.60 9.90 TJD 8,035.0 30 9.70 9.60 9.90 TJC 8,333.0 30 9.70 9.60 9.90 TJB 8,473.0 40 9.70 9.60 9.90 TJA 8,565.0 40 9.70 9.60 9.90 TSGR 8,660.0 40 oil 6.04 5.66 7.55 TSHU 8,706.0 40 7.78 5.66 9.90 TSAD 8,779.0 40 gas 7.01 6.79 7.84 45SB 8,784.0 40 gas 7.01 6.79 7.84 42SB 8,850.0 40 gas 7.01 6.79 7.84 TCGL 8,901.0 40 gas/oil 7.01 6.79 7.84 BCGL 8,968.0 40 oil 7.01 6.79 7.84 23SB 9,024.0 41 oil/water 7.01 6.79 7.84 22TS 9,082.0 42 oil/water 7.01 6.79 7.84 TD 9,100.0 43 water 7.01 6.79 7.84 Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn. Burst Collapse Length Top Bottom Size Tbg O.D. (psi) (psi) MD/TVDrkb MD/TVDrkb 8-1/2" 7" 26# L-80 VamTop 7,240 5,410 1659' 7400'/7278' 9059' /8742' HC (-150' lap) • 6-1/8" 4'/2" 12.6# 13Cr-80 Vam Top 8,430 7,500 849 8900'/ 8628' 9749' /9181' (-150' lap) Tubing 41/2" 12.6# 13Cr-80 Vam Top 8,430 7,500 8902' surface 8902' /8630' Mud Program Intermediate Section Mud properties for 8 1/2" hole section: Depth Mud weight PV YP API Fl. HTHP Fl. pH Drill MBT (lb/gal) Loss Loss @ solids 200°F or BHCT MD (ft) Min Preferred Max cP lb/100ft` ml/30 min 7545 -9052 10 10.9-11.1) 11.5 10-18 18-28 0-8.0 N/C 9-10 <6.0 <20 Production Section Mud properties for 6 1/8" hole section: Depth Mud weight PV YP API Fl. Low Shear pH MBT (lb/gal) Loss Rate Visc. MD (ft) Min Preferred Max cP Ib/100ft2 ml/30 min cP 9052 -9742 8.4 8.4-8.7 8.8 <12 10-28 <10 >15000 8.0- <4 9.5 Logging Program 8-1/2" Intermediate: Sample Catchers-as required by Geology Drilling: Dir/GR/at-bit-GR/ Res Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers—as required by Geology Drilling: Dir/GR/ Res / Neu / Den Open Hole: None Cased Hole: None Cement Program Casing Size 7" 26#, L-80 Vam Top HC Intermediate Liner Basis: Lead: 1152' of annular length + 30% excess in open hole + 200' of 9-5/8" x 4" DP Lead TOC at 7400' MD (cement at TOL w/excess to be circulated out) Tail: 500' of annular length + 30% excess + 80' shoe track. Tail TOC at—8552' MD Total Cement Spacer 25 bbls of Viscosified Spacer(Mud Push II) Volume: Lead 45.7 bbls, 257 cuft, 141 sks 12.5 lb/gal Extended Class G + adds— 1.82 cuft/sk Tail 17.7 bbls, 99 cuft, 85 sks 15.8 lb/gal Class G + adds— 1.17 cuft/sk Temp BHST= 180° F, BHCT TBD by Schlumberger Casing Size 4.5" 12.6#, 13-Cr-80 Vam Top Production Liner Basis: Lead: None Tail: Open hole volume + 40% excess + 150' of liner lap Tail TOC: 8902' MD (cement at TOL w/excess to be circulated out) l Total Cement Spacer 25 bbls of Viscosified Spacer weighted (Mud Push II) Volume: Lead N/A Tail 19.0 bbls, 107 cuft, 91 sks 15.8 lb/gal Class G + adds— 1.17 cuft/sk Temp BHST= 192° F, BHCT TBD by Schlumberger Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. Close Approach Shut-in Wells: All offset wells pass anti-collision major risk criteria. Hydrogen Sulfide F-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name I-12S Level Reading Date Comments Parent Well(if sidetrack) F-13A 8 ppm 4/8/2012 #1 Closest SHL Well H2S Level F-39 40 ppm 2/24/2012 #2 Closest SHL Well H2S Level F-41 6 ppm 2/15/2012 #1 Closest BHL Well H2S Level F-06A 10 ppm 1/26/2011 • #2 Closest BHL Well H2S Level F-12 6 ppm 6/15/2011 Max.Recorded H2S on Pad/Facility F-24 120 ppm 7/11/2011 Faults F-13B will not intersect any mapped faults . Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- - 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal / Contact the GPB Environmental Advisors (659- 5893)f/guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear ram, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for F-13B will be 7 to 14 days during drilling phase* and 7 V days during de-completion and surface casing work. Intermediate Interval Maximum anticipated BHP 3422 psi @ 8660' TVDSS (7.6 ppg EMW) • Maximum surface pressure 2556 psi (.10 psi/ft gas gradient to surface) Kick tolerance Infinite with 11.0 ppg MW at min predicted fracture gradient of 13.7 ppg Planned BOP test pressure Rams test to 4000 psi/250 psi. Annular test to 4000 psi/250 psi 9-5/8" Casing Test/7" 3500 psi surface pressure Casing Integrity Test—8-1/2" hole FIT after drilling 20' from middle of window 7" Casing VBRs upper cavity will be changed to 7" rams for the 7" liner Production Interval Maximum anticipated BHP 3684 psi © 9082' TVDss (7.8 ppg EMW) . Maximum surface pressure 2775 psi (.10 psi/ft gas gradient to surface) Kick tolerance Infinite with 8.7 ppg MW at min predicted fracture gradient of 11.9 ppg Planned BOP test pressure Rams test to 4000 psi/250 psi. Annular test to 4000 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20' of new hole 4-1/2" Production Liner 3500 psi surface pressure Planned completion fluids 8.5 ppg Seawater/6.8 ppg Diesel * F-13B will be the first well spudded from Parker 272 rig based on current rig schedule. BOP testing frequency is planned to be every 7 days. In case of rig schedule change in a way that other planned wells supersede F-13B then BOP tests will be carried out on a bi-weekly basis PONT THIS NOTICE IN THE DOGHOUSE I. Well Control A. Intermediate Hole - The mud weight selection is based on effective wellbore stabilization across Kingak shales and is well above expected pore pressure gradients. Maximum expected pore pressure exposed in permeable formations is 7.6 ppg (TSGR). B. Production Hole - The Sag River and Ivishak formations in this area are expected to be under-pressured at 5.7— 7.8 ppg EMW. This interval will be drilled with —8.7 ppg reservoir drill-in fluid. II. Lost Circulation/Breathing A. Intermediate Hole — lost circulation is unlikely to occur until exposing Sag River formation. Lowest possible mud weight will be used for preventing losses without compromising WBS issues in Kingak. B. Production Hole — the risk of lost circulation is considered moderate in this hole section. Well trajectory was designed in a way that all mapped faults were outside of 100' radius from the well. III. Kick Tolerance/Integrity Testing A. With the planned mud weights, the kick tolerance for the intermediate section is infinite for both intermediate and production hole sections B. Integrity Testing Test Point Test Depth Test type EMW(Ib/gal) 9-%" window 20'-50'from the 9-%" window LOT 12.2 minimum ►� 7" shoe 20'-50'from the 7" shoe FIT 9.4 minimum IV. Hydrogen Sulfide As F-Pad is considered an H25 site, refer to the ADW "Hydrogen Sulfide" SOP for the appropriate operational guidelines. The H2S reading for parent F-13A well on 4/8/2012 was 8 ppm and the highest recorded H25 on the pad was 120 ppm on F-24. The planned bottom-hole location for F-13B is not near F- 24. V. Faults F-13B well will not intersect any mapped faults. Target circles are designed to maintain 200' standoff from major east/west faults and 100' standoff from smaller faults mapped near the TSGR casing point. VI. Anti-Collision Issues All offset wells pass major risk analysis criteria CONSULT THE F-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION bp 0 Schlumberger F-13B(P5)Proposal Geodetic Report Report Date: August 21.2012-10:07 PM Survey/DLS Computation: Minimum Curvature/Lubineki Client: BP Exploration Alaska Vertical Section Azimuth: 318.183'(True North) • Field: Prudhoe Bay Unit-WOA ■ 6 (�dY Vertical Section Origin: 0.000 ft,0.000 ft Structure/Slot: F-PAD/F-13 gibiii TVD Reference Datum: RKB Well: F-13 pea TVD Reference Elevation: 81.550 ft above MSL- Borehole: F-13B Seabed/Ground Elevation: 34.600 ft above MSL • APIP: 50-029-20434-02 Magnetic Declination: 20.578° Survey Name: F-13B(P5) Total Gravity Field Strength: 1002.6771 mgn(9.8 based) Survey Date: August 21,2012 Total Magnetic Field Strength: 57629.656 nT Tort/AHD/DDI/ERD Ratio: 144.039'/2099.962 ft/5.507/0.229 Magnetic Dip Angle: 81.041• Coordinate Reference System: NAD27 Alaska State Plane,Zone 04,US Feet Declination Date: January 21,2013 Location Lat/Long: N 70'20'17.55222",W 148°48'1.00064" Magnetic Declination Modal: BGGM 2012 Location Grid WE Y/X: N 5974812.000 ftUS,E 651958.000 ftUS North Reference: True North CRS Grid Convergence Angle: 1.1812' Grid Convergence Uaed: 0.0000' Grid Scale Factor: 0.99992823 Total Corr Meg North->True North: 20.5759° Local Coord Referenced To: Well Head Comments (ft) Ingl WW1 True TVDSS TVD VSEC NS EW TF DLS Directional Northing Eluting (ft) r) r) (ft) (ft) (ft) (ft) (ft) (°) r/1o0R)Difficulty Index (ftUS) (ftUS) Tie-In Survey 751805 0.47 37.20 7314.11 7395.66 696.11 846.77 -122.94 37.37M N/A 4.83 5975656.04 651817.94 LCU 7547.04 0.37 37.37 7344.00 7425.55 696.15 846.95 -122.81 37.3951 0.32 4.83 5975856.22 851818.07 Top Whipstock 7551.15 0.36 37.39 7347.21 7428.76 696.15 848.96 -122.79 359.13M 0.32 4.83 5975656.24 651818.08 Base Whipstock 7567.15 2.18 359.13 7363.20 7444.75 696.38 847.31 -122.77 359.13M 12.00 4.84 5975656.58 651818.10 Cry 3.5/100 7587.15 2.19 359.13 7383.19 7464.74 696,94 848.08 "122.78 354.09M 0.00 4.84 5975657.35 651818.07 7600.00 2.59 354.09 7396.03 7477.58 697.35 848.61 -122.81 339.48M 3.50 4.84 5975657.88 651818.03 7700.00 5.95 339.48 7495.74 7577.29 703.89 855.71 -124.86 335.48M 3.50 4.87 5975664.94 651815.83 7800.00 9.41 335.48 7594.83 7676.38 716.37 868.00 -130.07 6.8L 3.50 4.89 5975677.12 651810.38 TJF 7840.81 10.83 334.58 7635.00 771655 723.15 874.50 -133.10 5.911 3.50 4.90 5975883.55 851807.22 7900.00 12.89 333.63 7692.93 7774.48 734.73 885.43 -138.42 4.971 3.50 4.92 5975694.38 651801.68 8000.00 16.38 332.55 7789.67 7871.22 758.90 907.94 -149.88 3.931 3.50 4.95 5975716.65 651789.77 TJE 8005.56 16.57 332.50 779500 7876.55 760.41 909.34 •150.60 3.891 3.50 4.95 5975718.03 851789.01 8100.00 19.87 331.84 7884.69 7966.24 788.80 935.45 -164.40 3.261 3.50 4.98 5975743.85 651774.69 8200.00 23.37 331.34 7977.64 8059.19 824.32 967.84 -181.93 2.81_ 3.50 5.01 5975775.88 651756.51 TJD 8263.02 2557 331.09 8035.00 8116.55 849.53 990.72 -194.50 2.571 3.50 503 5975798.50 851743.48 8300.00 26.86 330.97 8068.17 8149.72 865.32 1005.01 -202.41 2.451 3.50 5.04 5975812.63 651735.28 8400.00 30.36 330.67 8155.95 8237.50 911.64 1046.81 -225.77 2.191. 3.50 5.08 5975853.94 651711.08 8500.00 33.86 330.43 8240.64 8322.19 963.13 1093.08 -251.90 1.991 3.50 5.11 5975899.67 6551684.02 8600.00 37.36 330.23 8321.93 840348 1019.58 1143.66 -280.72 1.831 3.50 5.15 5975949.65 651654.18 TJC 8613.97 37.84 330.20 8333.00 8414.55 1027.85 1151.06 -284.06 1.811 3.50 515 5975958.96 651649.80 8700.00 40.85 330.06 8399.52 8481.07 1080.78 1198.35 -312.12 1.691 3.50 5.18 5976003.69 651621.68 End Cry 8730.02 41.90 330.01 8422.04 8503.59 1100.04 1215.54 -322.03 HS 3.50 5.19 5976020.68 651811.43 Cry 3.5/100 8738.86 41.90 330.01 8428.62 8510.17 1105.78 1220.86 -324.98 74.081 0.00 5.20 5976025.73 651808.37 TJB 8798.77 42.52 327.03 8473.00 8551.55 114509 1254.97 -348.00 71.871 350 522 5976059.81 651586.68 8800.00 42.53 328.97 8473.91 8555.46 1145.91 1255.67 •346.46 71.821 3.50 5.22 5976060.30 651586.20 8900.00 4373 322.15 8546.91 8628.46 1213.51 1311.31 "386.10 68.31L 3.50 5.25 5976115.12 651545.44 TJA 8925.10 44.06 320.98 856500 8646.55 1230.83 1324.95 -395.92 67461 350 526 5976128.53 651534.35 9000.00 45.11 317.56 8618.35 8699.90 1283.32 1364.77 -431.22 65031 3.50 5.29 5976167.64 651499.24 F-138 SGR Tgt 9058.05 46.00 315.00 8659.00 8740.55 1324.76 1394.71 -459.87 HS 150 5.31 5976197.00 651470.00 TSGR 9059.49 40.00 315.00 8060.00 8741.55 132570 139544 -400.00 HS 0.00 5.31 5970197.72 051409.25 7"Casing Point Cry 5/100 9076.95 46.00 315.00 8672.13 8753.68 1338.35 1404.32 -489.48 93.021 0.00 5.31 5976206.42 651460.19 9100.00 45.95 313.40 8688.15 8769.70 1354.91 1415.88 -481.36 91.91 5.00 5.32 5976217.72 651448.08 TSHU 912587 4592 311.81 8706.00 8787.55 137132 1428.34 -494.96 90.861 500 533 5976229.91 651434.24 5200.00 48.00 306.44 875769 8839.24 1426.30 1481.96 -536.44 87.071 5.00 5.36 5976262.68 651392.09 TSAR 9230.70 46.09 304.32 8779.00 8850.55 1448.00 1474.75 -554.46 85591 5.00 537 597627510 65137182 45S8 9237.91 46.12 303.82 8784.00 8865.55 1453.08 1477.67 -558.76 85241 5.00 537 59762277.93 651369.45 End Cry 925331 46.19 302.75 8794.66 8876.21 1463.91 1483,76 -568.04 HS 5.00 5.38 5976283.83 651360.05 Cry 4/100 9280.75 46.19 302.75 8813.86 8895.21 1483.17 1494.47 -584.70 62.251 0.00 5.38 5976294.20 651343.18 9300.00 46.55 301.81 8828.94 8908.49 1496.69 1501.92 •596.48 61.61L 4.00 5.39 5976301.41 651331.25 4258 9333.73 47.21 300.20 885000 8931.55 1520.45 1514.00 -817.58 80.51 4.00 5.40 5976313.86 651309.90 9348.49 47.50 299.50 8860.00 8941.55 1530.87 1520.00 -627.00 15.371 4.00 5.40 5976318.87 651300.38 9400.00 49.49 298.78 8894.13 8975.68 1567.75 1538.78 -660.69 14.891 4.00 5.42 5976336.96 651266.31 7001 9410.62 49.90 298.64 8901.00 8982.55 157547 1542.87 -807.79 14.81 4.00 542 5976340.70 651259.14 9500.00 53.36 297.50 8956.48 9038.03 1642.06 1575.62 -729.62 14.09L 4.00 545 5976372.40 651196.65 BCGL 9519.48 54.12 297.27 8968.00 9049.55 1656.94 1582.85 •743.57 13.961 400 5.46 5976379.34 651182.58 End Cry 9542.20 55.00 297.00 8981.17 9062.72 1674.43 1591.29 -780.04 HS 4.00 5.47 5976387.44 651165.93 2358 9816.87 5500 297.00 9024.00 9105.55 1732.20 1619.06 -814.54 HS 0.00 548 5976414.10 651110.88 22TS 9717.99 55.00 297.00 9082.00 9163.55 1810.43 1658.06 -888.35 HS 0.00 5.50 5976450.20 651038.33 BHL 9749.37 55.00 297.00 9100.00 ' 9181.55 1834.71 1668.33 • -911.25 • 0.00 5.51 5976461.40 65101320 a y Surface:32991,3DFS 2885.1 FEL S2 T11N R13E UM N5974811.0(16(Y1 yyBS1968.0(X) Tie-In:4138 FSL 2987 FEL 2 711N R13EUM 5975856.040 651817.940 BHL:4980 FSL 3775 FEL 2 711N R13EUM 5976461.400 651013.200 Drilling Office 2.6.1120.0 Prudhoe Bay Unit-WOA\F-PAD\F-13\F-13B\F-13B(P5) 9/11/2012 1:32 PM Page 1 of 1 Parker 272 BOPE Schematic PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP m 13 5/8"-5M FLANGED BOTTOM 01/(2) 14" UL2 OPERATOR, UPPER CAVITY C°) ANNULAR BOP: AND (2) 14" PSLK W/BSTR OPERATOR, fiitr�6i SHAFFER LXT 13 5/8"-5M OWER CAVITY 13-5/8" 5M STUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 1 I DRILLING CROSS: 13 5/8"-5M FLANGED TOP - I D I - 13 5/8" SM FLANGED BOTTOM �1"O _- 3 W(2) 3 1/8"-5M SIDE OUTLETS 7 • . r II 8 • H ` ` KILL LINE: ,AY��O1 1 °gY�� 1,�� �p 2-1/16" 5M FLEX HOSE �(��(( . ;[�� ) � - 2-1/16" 5M X 3-1/8" 5M D.S.A. l ��VA ' �I I� Iu � 3-1/8" 5M FLANGED MANUAL GATE VALVE 10. 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE IE riir...., As. • 3 1 I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE _ SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 5M FLEX HOSE 13 5/8"- 5M FLANGED BOTTOM 3-1/8" w/(2) 14" UL2 OPERATOR Current Schematic: TREE' WELLHEAD= MCEVOY F-1 3A 81AFETY NOTES:WELL ANGLE)70'@ 9225'. ACTUATOR= OTIS KB ELEV= 66.50' BF B_EV.= 34.60' KOP= 3400' Datum I 7"OTIS SSSV LANO NIP,ID.5152' I PAD= 9018' Datum TV D= 88C0'SS I I 3-3/8"CSG,72N,L-80,0=12 347" H 2686' III 5inimum ID =2.441"@ 8032' TOP OF 2-7/8" LINER ....... 7978 —19-5/8"SAD BAKER PKR,ID•4.0 7985' —T'X 4-1 r2"xo I 17"TBG,26#,L-80, 0383 bpf ID-6 276' 7978' I IL 13027. 41/2 OTIS X NP,ID=3813" 8027' 4-1/2'XX PLUQ(05/13/ 2) TOP OF LNRH Of P 1 IP i 8032' 1—DEPLOY MENT SLEEV E I I I 8069' —4-1/2'OTIS XN NIP ID=3 725" 1 \ 8092' H4112"BAKER SOS MG TA IL i 9-518"CSG 47L L-80,ID=8 681" — 8680' I---41 I 1 8087 H ELMD TT LOGGED 0921/88 TOP OF WHIPSTOCK —I 8684' I IVIL LOUT ININDOW 6670' RA MARKER 1—• 8871' I —M NVI1444.4if 4\ .• .4044 ..•••• Iktok FEWORATION SLIMMARY ••••••• ...Os. ....... REF LOG SWS BHCS ON 02/21180 01.0.41 9776' CEP(03/16/04),FA LI_93-n-Eu SveAs. ANGLE AT TOP PEW 864 @ 9400' Olt. 41 TIGHT SPOT w/2 29'MILL @ .... • ..il Note Refer to Production DE for historical pert data .0.44441 / 9668'CTMD 03/17/04,TAGGED 4.1444 IMEI SRINTEWAL Opn/Sqz DATE 444404. 4444.1 CORRECTED[ PP-I 04/21/09 il 9400 9510 0 12/06/96 11 9530-9350 t 0 12/06/96 9710-9740 t 0 04/21/09 9760•9775 0 04/21/09 9885- 44.410 ....... 411.41 4404414 A.A.A1AIA 4t• V.114`.1 I' a-4Fri 1 0 2 6 5' '10' .444014 444441 144441 4•.A.A.A.,. 4, irefirs 2418"LNR S'lea,L-80, 00579 bpf,ID=2 441" 10320' 444441 tattOttet 0 I 7'LNR 294 L-80, 0371 bpl.ID.8 184' 9040' DATE REV BY COMMENTS nATE REV BY COMMENTS PRLDHOE BAY UNIT 02128A36 ORIGINAL COMPLETION 06/21/12 DA S/JMD SET 4-1/2"XX PLUG(05113/12) J. F-1 3A 12106156 SIDETRACK(F-13A) PERM-No '1961520 03/0502 RN/TP CORRECTIONS AR kt. 50-029-20434-01 09/08/03 TG/KAK CORRECTIONS SEC Z T11 N,R13E.1998'SNL&2865'WEL 03/19/04 SRBFLP GBP 05/31109 GLNYTLH PENS(04/21/09)&CORRECTIONS BP Exploration(Alaska) Pre-rig Schematic: THEE= 6'CI11V VNBLI-EAD= 14;EV(P! F-13 A Drawing not to scale ACTUATOR= OTIS KB.ELEV= 66.50' BF.ELEV= 34.60' KOP= 3400' Mix Angie= 98 1 9880 0 2097' -7'OTIS SSSV LAN)NP,D=5.962' Datum MD= 9018' Datum TVD= 8800'SS 13-3/8'CSG,724,L-80,D=12.347' —i 2666' Minimum ID =2441"@ 8032' k. ,(,� TOP OF 2-7/8" LINER -77°P• (A �L- 7'TBG,264,L-80, 0383 bpi,ID=6.276' — 7978" O-, 7978' —9-5/W SAB BAKER PKR D=4.0" 7985' -{7"X 4-1/2"X0 Banned TOC — 8000' ' 8027' —14-112"0115 X NP,ID=3.813' 1 TOP OF 7"LN2 H 8032' 8032' —DEFLOY MENT SLEEVE .A I% 8059' F14.1/2'OTIS XII NP,D=3.725" Estimated TOC OF 2-7l8'LNR — 8384' � � _ 8092' —4-1/2'BAKER SOS TBG TAL 9-5/8"CSG,474,L-80,D=8.881' — 8680' TOP OF WFPSTOCK H 8684' I t'�'11�� MLLOIJf WP/DOW 8670' RA MARKER --I 8671' I • ' FERFORA1CN SUMMARY .11++�1"111� REF LOG:SWS BRCS ON 02/21/80 11111011111111 1111114 Nk illi ANGLE AT TOP PERE:86 0 9400' 111111111111114 44. 44 9778' —CEP(03/18/04);MILLED THRt1 Note:Refer to Production DB for historical pert data 1111144 1111111 TIGHTSPOTw!2.29"MLL r SIZE SPF INTERVAL Opn/Sgz DATE 11111111111111 )p 2' 4 9400-9510 0 12/06/96 11 1111 �' 9668'CIM)03/17/04;TAGGED 2' 4 9530-9650 0 12/06/96 11111"111001 1 1111111 �t COR TED DEPTH 04/21/09 1111114 ii 2' 6 9710-9740 0 04/21/09 111111♦ 1111111 2' 6 9760-9775 0 04/21/09 11111111111114 k\ 2' 4 9885-9920 C 12/06/96 4141111 rr�>A\ +1�1�1�1�1�1�1 FBTO 10266• •I*, 11i1ii4i4i4i1 11111111 �1�1�1�1444 2-7/8'LW,8.184,L-80,.00579 bpi,D=2.441" H 10320' 444444444444444 7'LN2,290,L-80, 0371 bpi,D=8.184' H 9040' •••••••• DATE . REV BY COMMENTS DATE REV BY ' C OMM3ITS PRIDHOE BAY UNIT 02/28/80ORIGINAL COMPLETION WELL: F-13A 12/06/96 SIDETRACK(P-13A) PERMIT No:1961520 03/05/02 RWTP CORRECTIONS API No: 50-029-20434-01 09/08!03-TG/KAK CORRECTIONS SEC 2,T11 N,R13E,1998 SNL 8 2865'VYEL 03/18/04 SRB/TLP CEP 05/31/09 GLM/TLH PERFS(04121/09)&CORRECTIONS BP Bcploration(Alaska) F-13B Proposed Schematic: TREE= 6"CM/ GAS LET MANS VtiEt_U-EAD= kbEVOY ACTUATOR= OTIS F-1 3BST MD 1VD DEV TYPE FORT GATE 4 KB ELEV= 86.50' Proposed P hn 3 I3F BEV= 34.60' 2 KOP= 7545' 1 Max An*= Datum MD= Datum TVD= SS K.711 'SSSV kipple,113.813" —2000' 13418 CSO.724,L-80,It)=12,34r — 2665' —All L 4-112Minimum ID=3.725" I U 4112"XN-Nipple _ mop 0 TOP OF 7"LNR H 7400' ri__Li 19 5/8"WHESTOCK EXIT — 7545' 1 " / 7978' —9-5/8*SAB BAKER PKR,0=4 0" 2^'A V"..''' Thew —r X 4-1/2"X0 8-1/2"hole I i 4-1/2"X-NE D""3,813—'-,_ 0 I 110 M 7"x 4 1/2"PKR — 8792' Arr i I ie 4-1/7 X-NP,123.813—."-; 2 2 I L 1 4-1/7 XN-NppD3 725--'3e-,2 9-5/8"CSG,474,L-80,10=8 681' 8680' le,I = A i 4-112"TBG,12.64,13-0-,113- 958" —wgz2 Lk. 7'LNR 284.L 80,VAM TOP I-C 0062' **vv*,• ve 46c" .44.14041 4001.4 6-1/8" hole **4••••• 4.44.001 4..0144 4-1/2"LNR,1264,13-o--9742' *4444444 'a.4.444.08.44 .1111111Ri, 5.Th alkii NIwitt: 2-7/8"LNR,6 164,L-80,.00579 bpf,I)=2.441' H 10320' I DATE REV BY CCAO/ENTS DATE Rs/BY cOMIENTS, PRLOHOE BAY UNIT 02/28180 ORIGINAL COMPLETION 05/16/12 RRM Built F-13B proposed WELL: F-138 12/06/96 SIDETRACK(F-13A) FERAIT No 03/05/02 RN/TP CORRT1ONS API* 50-029-20434-XX 09/08/03 TG/KAK CORRE-CT1ONS SEC2,T11N,R13E,1998SN_&2865'VVEL 03/18/04 SFE/TLP CUP 05/31/09 GLIN1111 PERFS(04/21/09)&CORRECTIONS BP Bcp1oration(Alaska) F-13B Drilling Hazards and Contingencies OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME (Fa F-/3,3 PTD# 7—I Z 7(// Development Service Exploratory Stratigraphic Test Non- nventional Well / FIELD: ,�14_, l POOL: u4L , 6/7. Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 III „ u) ' 0)) a y CO N a c A O • a E O O v. 3: c o O' a 3, ai, a. 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