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209-127
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM N • WEL COMPLETION OR RECOMPLETION REP AND LOG la. Well Status: Oil ❑ Gas 0 SPLUG 0 Other ❑ Abandoned VI • Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Development 121 Exploratory CI Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 6/21/2016 • / tli is 209-127 • 316-114 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 2/8/2010 50-029-21045-05-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/14/2010 PBU K-07E Surface: 2041'FNL,473'FWL,Sec.04,T11N,R14E,UM • 9 KB 54.66 Ref Elevations 17. Field/Pool(s): Top of Productive Interval: 943 FSL,1370'FWL,Sec.33,T12N,R14E,UM GL 26.21 . BF 27.91 PRUDHOE BAY,PRUDHOE OIL • Total Depth: 1310'FNL,1218'FWL,Sec.33,T12N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 9212'/8385' ADL 028303&028300 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 670744• y- 5975163 • Zone - ASP 4 - 10301'/9008' • 95-001 TPI: x- 671565 y- 5978167 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 671403 y- 5978530 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No H 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) . 9232'/8405' 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,GR/CCL/CNL RECEIVED 23. JUL 19 2016 CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECOF !OGC i✓_ AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20"x 30" Insulated Conductor 31' 111' 31' 111' 36" 8 cu yds Concrete 13-3/8" 72# L-80 30' 2700' 30' 2700' 17-1/2" 3264 cu ft PF'E',465 cu ft PF II 9-5/8" 47# L-80 27' 6992' 27' 6279' 12-1/4" 2119 cu ft Class'G',133 cu ft PF'C' 7" 26# L-80 6803' 9189' 6139' 8363' 8-1/2" 527 cu ft Class'G' 4-1/2" 12.6# L-80 9036' 9232' 8211' 8405' 6-1/8" 280 cu ft Class'G' 3-3/16'x2-7/8" 6.2#/6.16# L-80 9330' 10300' 8498' 9007' 4-1/8" 76 cu ft Class'G' 180' 24. Open to production or injection? Yes 0 No El 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2",12.6#,L-80 9040' 9011'/8186' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. COMPLETION Was hydraulic fracturing used during completion? Yes 0 No PI • Per 20 information 25.283(i)(2)attach electronic and printed scoNED SEF 3 a 1616 �.2►FLi rF RIF lED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LA.. 9330' Cut and Pull 3-1/2"x 3-3/16"Liner 9212' 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 ..► Row Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate ".' Form 10-407 Revised 11/2015 ��j�/' //// CONTINUED ON PAGE 2 Submit ORIGINAL only / lell� V 7"L SS 3 / L RBDMS LL f1n .,✓`b 7.;.i,, V J-._ ZZ 1016 28. CORE DATA • Conventional Core(s) Yes 0 No ® • Sidewall Cores 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 MC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost-Top Well Tested? Yes 0 No RI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9781' 8712' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit-Zone 4 9274' 8447' CGL-Zone 3 9373' 8532' Base of CGL-Zone 2C 9480' 8589' 23SB-Zone 2B 9568' 8626' 22TS 9672' 8668' 21TS-Zone 2A 9781' 8712' Zone 1B 9908' 8766' 21 TS-Zone 2A(Fault) 10017' 8826' Zone 1B 10157' 8918' TDF-Zone l A 10219' 8957' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Browning,Zachary H Email: Zachary.Browning@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: '/I /{6 1 � 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 MC 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 MC 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 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • K-07E Well History (Pre-Rig Sidetrack) 'OSPIVIIWY ***WELL SHUT-IN ON ARRIVAL'`**(SLB ELINE -TUBING CUT) INTIAL T/I/O = 2400/0/0 PSI RIH W/2.5"JET CUTTER& CUT 3-3/16" LINER @ 9330' MD - GOOD INDICATION AT SURFACE OF CUT AND VERIFIED ONCE AT SURFACE TIED INTO MEMORY COMPENSATED NEUTRON LOG DATED 18-fEB-2010 3/1/2016 FINAL T/I/O =2400/0/0 CTU#9 1.75" CT Objective: Prep for CTD sidetrack, Catch and release liner 3/11/2016 MIRU, MU RIH w/4" G-Spear. CTU#9 1.75" CT Objective: Prep for CTD sidetrack, Catch and release liner MIRU, MU RIH w/4" G-Spear. Latch deployment sleeve at 9,150' perform 10 jar cycles and liner came free. Pull liner up hole to 9,050', pu wt was --1.5k higher. RIH to 9,148' and 3/11/2016 pumped off fish, pick up was clean and wt dropped. POOH. CTU#9 1.75" CT Objective: Prep for CTD sidetrack, Catch and release liner 3/12/2016 RDMO T/I/0=2450/0/0. Pre Nordic 2. Set 6" "J"TWC#421 @ 142". TWC LTT (Pass), Install CTD TS#07, PT to 5000 psi. (Pass), PT Tree cap to 500 psi. (Pass), ***Job Complete*** 6/12/2016 See log. Final WHP's TWC/0/0. T/I/O=TWC/0/0. Remove tree cap from TS-07 and installed tapped blind flange. Torqued 6/13/2016 and PT'd to API specs. RDMOSEE LOG FOR DETAILS. Final T/I/O=TWC/0/0. T/I/O =TWC/15/0. Temp = SI. WHPs (Pre CTD). No AL. Wellhouse, scaffolding &floor has been removed, flowline is disconnected. Unable to reach swab to check valve 6/15/2016 position. • • North America-ALASKA-BP Page 1 Eva- Operation NORDICCommon Well Name:K-07 AFE No , Event Type:RE-ENTER-ONSHORE(RON) I Start Date:6/17/2016 End Date:6/25/2016 X3-017T2-C:(3,407,475.00) Project:Prudhoe Bay [Site:PB K Pad -1 Rig Name/No.:NORDIC 2 1 Spud Date/Time:11/19/1983 12:00:00AM Rig Release:6/28/2016 Rig Contractor: 00 Active datum:K-07F(§54.66usft(above Mean Sea Level) .._ Date 1 From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations ' (hr) (usft) 6/17/2016 10:00 - 11:301.50 MOB P 1 PRE :PJSM WITH ALL RIG MOVING PARTICIPANTS. j -DRILL SITE OPERATOR NOTIFIED OF INTENT TO MOVE OFF OF WELL. -DRILL SITE OPERATOR WAIVED !WITNESSING. -EMPHASIS ON COMMUNICATION AND AWARENESS. -AGREED ON SIGNAL TO BE USED TO STOP i MOVEMENT OF THE RIG. CHOCKS IN PLACE TO PREVENT RIG FROM 1 I MOVING BACKWARD TOWARDS THE WELL. j ! 1-ESD SWITCH IS OPERABLE AND TESTED 1 1 PRIOR TO MOVEMENT. TOOLPUSHER MANNING ESD SWITCH. -RADIO COMMUNICATION VERIFIED WITH 1 ALL RIG MOVING HANDS. VERIFIED ALL VALVES ON WELLHEAD 1 !CLOSED IN. 1 -JACK RIG UP AND MOVE SLOWLY OFF OF I WELL. 11:30 - 00:00 ( 12.50 MOB 1 P PRE COMMENCE MOVING RIG FROM DS 14 TO K PAD VIA OXBOW ROAD. -GOOD PRE JOB WITH SECURITY PRIOR TO 1 1 EXITING DS 14. 19:00 AOGCC BRIAN BIXBY DISCUSS BY j I I 1 'PHONE THE NEED TO CALL ONCE SHELL TEST COMPLETE -MOVE RIG DOWN OXBOW TO WEST DOCK I I-MOVING DOWN K-PAD ROAD AT REPORT (TIME 6/18/2016 00:00 - 02:00 2.00 1 MOB P PRE 'CONTINUE MOVE TO K-PAD ARRIVE ON LOCATION. 02:00 - 03:00 1.00 MOB PPRE ,SET RIG MATS. CLOSE AND LOCKOUT K-10 1 1 VALVES. 1-VERIFY IA/OA BELOW 50# PJSM WITH 1 CREW. ASSIGN SPOTTER POSITIONS TEST I ! I TESD 1 1-DRILL SITE OPERATOR NOTIFIED OF INTENT,CHALKS IN PLACE. I AGREED UPON SIGNAL FOR STOPPING RIG. �-MOVE RIG OVER WELL -ACCEPT RIG AT 03:00 03:00 - 04:00 1.00 MOB P PRE I OPEN ALL VALVES ON TREE. 0#PRESSURE ION WELL. 1INSTALLTRANSDUCER ON WING. MONITOR j I FOR THERMAL PERFORM LTT. PASSED. 04:00 - 07:00 3.00 BOPSUR ! P PRE 1 NIPPLE DOWN TREE CAP FLANGE, PREPARE 1 TO NIPPLE UP BOPE RIG UP ANCILLARY EQUIPMENT 107:00 - 10:30 3.50 I BOPSUR 1 P PRE j PJSM. 7 1/16"X 5M BOPE. 1-FUNCTION TEST,OK. 10:30 - 13:00 2.50 BOPSUR 1 N SFAL 1 PRE 1 PJSM.RIG UP TO TEST BOPE. 1 1-ATTEMPT TO PERFORM SHELL TEST. 1- REPAIR LEAKING DOOR SEAL. I -ATTEMPT TEST,VBR DOOR SEAL ODS LEAKING. REPLACE SAME. Printed 7/5/2016 11:00:37AM *AII depths reported in Drillers Depths* • • • North America-ALASKA-BP Page 2614, Operation Summary Report Common Well Name K-07 AFE No Event Type.RE-ENTER-ONSHORE(RON) Start Date:6/17/2016 End Date:6/25/2016 X3-017T2-C:(3,407,475 00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 2 Spud Date/Time:11/19/1983 12:00:OOAM Rig Release:6/28/2016 1 Rig Contractor:NORDIC CALISTA i UWI:500292104500 Active datum:K-07F @54.66usft(above Mean Sea Level) Date From-To Hrs Task Code . NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 16:00 3.00 BOPSUR 1 N RREP PRE REATTEMPT SHELL TEST. -MM-3 LEAKING AND 2 3/8"RAM DOOR SEAL I, LEAKING. I -REPLACE MM-3 VALVE TRIM AND 2 3/8" LOWER RAM DOOR SEAL. -ATTEMPT SHELL TEST. 1 -CHART RECORDER FAILED,VBR DOOR SEAL LEAKING. I -REPLACE CHART RECORDER AND DOOR SEAT 116:00 - 00:00 8.00 BOPSUR P PRE PERFORM SHELL TEST ON BOPE. 1 -TEST 250/5000 PSI,5-10 MIN EACH,GOOD TEST. 1TEST BOPE AS PER BP AND AOGCC STATE REQUIREMENTS. STATE REP BRIAN BIXBY WITNESSING I I TESTS. 1-AOGCC GIVEN 40 HOUR NOTICE PRIOR TO TESTING -PERFORMING ACCUMULATOR DRAW DOWN :AT REPORT TIME. 6/19/2016 00:00 - 01:30 1.50 BOPSUR P PRE BOPE TEST W/AOGCC BRIAN BIXBY 01:30 - 02:45 r 1.25 BOPSUR i P ( PRE IPICKUP INJECTOR. VERIFY E-LINE BOOTED. STAB INJECTOR, LINE UP TO REVERSE CIRCULATE. 1 CLOSE INNER REEL VALVE, START TESTING IRV /PACKOFFS. PASSED PRESSURE TEST HIGH PRESSURE FILTERS TO 4700#. GOOD TEST 02:45 - 03.20 0.58 BOPSURI P PRE VALVE CREW TORQUEING TREE BOLTS 03:20 04:20 1.00 BOPSUR I P 1 PRE PULL TEST PLUG. I PJSM,BRING BPV LUBRICATOR TO FLOOR 04 20 - 05:00 0.67 BOPSUR P I PRE PERFORM FIRE RIG EVACUATION DRILL 05:00 - 07:30 2.50 BOPSUR 1 P I PRE PJSM.PRESSURE TEST BPV LUBRICATOR -PRESSURE TEST LUBRICATOR @ 250/3500 1 PSI,5 MIN EACH/CHARTED 07:30 08:00 0.50 BOPSUR PIi PRE PERFORM RIG EVACUATION DRILL. DRILL SITE OPERATOR NOTIFIED OF INTENT. -SIMULATE FIRE IN THE ENGINE ROOM GOING OUT OF CONTROL. I -ALL HANDS TO MUSTER AREA IN 1 MIN 30 1 SECONDS. -HEAD COUNT,ALL HANDS ACCOUNTED FOR.INCLUDING TRUCK DRIVERS. -GOOD AAR.WIND DIRECTION NOTED. I -NO GAPS.(1)SUGGESTION THAT WE PARK OUR TRUCKS NEXT TO THE MUSTER AREA Printed 7/5/2016 11:00:37AM *AII depths reported in Drillers Depths* • • • North America-ALASKA-BP Page 3 ottS Operation Summary Report Common Well Name:K-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/17/2016 1 End Date:6/25/2016 X3-017T2-C:(3,407,475.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 2 Spud Date/Time:11/19/1983 12:00:00AM 1 Rig Release:6/28/2016 Rig Contractor.NORDIC CALISTA I UWI:500292104500 Active datum:K-07F @54.66usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase ! Description of Operations (hr) I (usft) 08:00 - 10:00 2.00 BOPSUR ! P PRE PJSM.PULL TWC VALVE. I- NOTIFY DRILL SITE OPERATOR AND PBOC OF INTENT TO BLEED GAS. 1 1 -TUBING PRESSURE @ 2380 PSI. I-PERFORM LEAK TIGHT TEST ON SWAB 1 VALVE W/WELL BORE PRESSURE. 1-GOODTEST.CLOSE MASTER VALVE AND OPEN SWAB. -BLEED GAS TO TIGER TANK AND CLOSE IN. I NO PRESSURE BUILDING. 1 1-MASTER VALVE AND SWAB VALVE TESTED IAND CLOSED IN. 1 I I-BLEED ALL PRESSURE TO TIGER TANK AND PULL TWC TO FLOOR. 1 BREAK OFF LUBRICATOR AND INSTALL NIGHT CAP. ,-LOAD OUT LUBRICATOR AND TOOLS. 10:00 - 11:30 1.50 I DHB P i F PRE I R}SM.REVIEW PRESSURE CROSS CHECK II ' LIST. 1DOUBLE ChIECK VALVE ALIGNMENT. 1-BULLHEAD(5)BBLS MEOH FOLLOWED BY ! 1250 BBLS 8.4 PPG SLICK KCL. {-BRING RATE UP TO 7 BPM/2400 PSI ICP. -PRESSURE STEADILY DROPPING.80 BBLS AWAY,7 BPM/50 PSI. 1-PRESSURE STEADILY INCREASE AFTER 175 BBLS AWAY. I -FINAL CIRCULATING PRESSURE=245 PSI @ 17 BPM.WELL ON SIGNIFICANT VACUUM. -BLEED 0/A DOWN TO 450 PSI,1/2 BBL BLED BACK,ALL FLUID. 11:30 - 12:00 0.50 DHB I P PRE ESTABLISH LOSS RATE.INITIAL LOSS RATE= 1300 BPH. 1 j -CONTINUE TO MONITOR.LOSS RATE IDROPPED AND STABILIZED @ 180 BPH. -CONSULT ODE AND SUPERINTENDENT.OPT I TO PUMP HI VIS PILL. 12:00 13:30 1.50 DHB P DECOMP PJSM.MONITOR LOSS RATE W/MIXING HI VIS PILL. 1 -MIXING(80)BBLS 120,000 LSRV POWER VIS PILL. I I I i -LOSS RATE=2.5 BPM OR 150 BPH. 13:30 - 14:30 1.00 DHB P I DECOMP PJSM.ESTABLISH PARAMETERS. ( REFERENCE PRESSURE CROSS CHECK LIST. -DOUBLE CHECK VALVE ALIGNMENT. ! 1-BULLHEAD 80 BBLS HI VIS PILL,(2 PPB POWER VIS/POWER VIS L). ICP=4 BPM/ I I j1 (220 PSI. 1 1-W/80 BBLS AWAY,4 BPM/385 PSI.CHASE W/8.4 PPG SLICK KCL. -W/140 BBLS AWAY,DROP RATE TO 2 BPM @ 180 PSI. I 1-147 AWAY,2 BPM/280 PSI.PUMP ANOTHER 8 BBLS,2 BPM/300 PSI FCP. 14:30 - 15:00 I 0.50 DHB j P DECOMP MONITOR LOSS RATE.INITIAL LOSS RATE 30 -35 BPH. I -LOSS RATE DROPS TO 15 BPH IN 30 MIN OF i I MONITORING. ODE AND SUPERINTENDENT INFORMED. DECISION MADE TO GO FISH LINER. Printed 7/5/2016 11:00:37AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 4 cits Operation Summary Report Common Well Name:K-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) ; Start Date:6/17/2016 End Date:6/25/2016 X3-017T2-C:(3,407,475.00) Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 2 Spud Date/Time:11/19/1983 12:00:00AM Rig Release:6/28/2016 Rig Contractor.NORDIC CALISTA I UWI:500292104500 Active datum:K-07F©54.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations - (hr)- ;... (usft) 115:00 - 16:00 1.00 FISH P DECOMP I CONTINUE FILLING HOLE ACROSS THE TOP, LOSS RATE 10-12 BPH. -MAKE UP BAKER SLIP TYPE COIL CONNECTOR. 1-PULL TEST TO 35K,GOOD,PRESSURE TEST TO 3500 PSI,NO GOOD. ' !-LEAKING AROUND"0"RING AT TOP OF hCONNECTOR. REMOVE AND RECUT PIPE.TOTAL PIPE CUT 1 (10')AND(6')OF E LINE. I-MAKE UP BAKER SLIP TYPE COIL (CONNECTOR. I I-PULL TEST TO 35K AND PRESSURE TEST@ • 300/4000 PSI,OK. 16:00 - 16:45 0.75 FISH I N I SFAL 1 DECOMP I PULL TEST TO 35K,GOOD,PRESSURE TEST TO 3500 PSI,NO GOOD. -LEAKING AROUND"0"RING AT TOP OF (CONNECTOR. -REMOVE AND RECUT PIPE.TOTAL PIPE CUT (10')AND(6')OF E LINE. l-MAKE UPBAKER SLIP TYPE COIL CONNECTOR. 16:45 - 17:15 j 0.50 FISH P DECOMP IPJSM.PULL TEST CONECTOR TO 35K,OK. I PRESSURE TEST TO 3500 PSI,GOOD. t-PIPE AREA REPLACE WHERE COIL CONNECTOR WAS ORIGINALLY MADE UP TO I !HAD SOME WEAR. f-LEAK WAS A SLOW DRIP.ROOT CAUSE, CONNECTOR MADE UP ON SLIGHTLY WORN I;PIPE. 17:15 - 18:30 1.25 FISH P DECOMP I PJSM.PUMP 3/4"BALL THRU COIL, _ DISPLACING WATER OUT OF COIL. 118:30 - 19:00 ! 0.50 1 FISH � P DECOMP 'PUMPING ACROSS THE TOP.65 BPM IN /.58 BPM OUT(4.2 BPH) i !WELL STATIC. MAKE UP FISHING BHA PJSM FOR MGS USAGE. RIH 19:00 - 21:15 2.25 FISH P DECOMP 1 RIH TAKING RETURNS THROUGH MGS 0.75 BPM IN /1.05 BPM OUT(8-10 BPH LOSS ,RATE) _ _ 18.35 PPG IN /8.37 PPG OUT 21:15 - 22:10 0.92 FISH P DECOMP I WEIGHT CHECK 45K 450#@ 1.18 BPM. LATCH UPAT9177' SAW PRESSURE F INDICATION WHEN STINGING IN. 1 SHUT PUMPS DOWN. PICKUP LINER.PU 1 WEIGHT NOW 48K. SET LINER BACK DOWN. START CIRCULATING 2.6 BPM IN/2.17 BPM I OUT(LOSING-26 BPH) 1597#CIRCULATING I 1 PRESSURE. 8.39 PPG IN /8.37 PPG OUT 22:10 23:00 0.83 i FISH P i DECOMP 11ST BOTTOMS UP LOST 18 BBLS. 12.59 BPM IN /2.20 BPM OUT 1.8.40 PPG IN /8.36 PPG OUT II � I , 2ND BOTTOMS UP LOST 17 BBLS 2.56 BPM IN /2.25 BPM OUT 18.40 PPG IN /8.37 PPG OUT 23:00 - 23:10 0.17 FISH P DECOMP IPERFORM 10 MIN FLOW CHECK. WELL 1 1 STATIC Printed 7/5/2016 11:00:37AM *AII depths reported in Drillers Depths* ' • • North America-ALASKA-BP Page 59998, Operation Summary Report Common Well Name:K-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:6/17/2016 End Date:6/25/2016 X3-017T2-C:(3,407,475.00) i Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 2 Spud Date/Time:11/19/1983 12:00:00AM Rig Release:6/28/2016 Rig Contractor:NORDIC CALISTA UWI:500292104500 Active datum:K-07F @54.66usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:10 - 00:00 0.83 FISH 1 P i DECOMP ISOLATE COIL. COME ONLINE ACROSS THE 1 TOP HOLDING 200#ON WELL. 11.31 BPM IN/0.76 BPM OUT(-10 BPH) 8.4 PPG IN /8.36 PPG OUT 6/20/2016 08:30 - 09:00 0.50 FISH P DECOMP i PJSM.PRESSURE TEST BUQC 300/4000 PSI, GOOD. -TEST FLOATS,OK. SECURE INJECTOR. j 00:00 - 01:40 1.67 FISH P DECOMP j CONTINUE OUT OF WELL PJSM, DISCUSS LAY DOWN PROCEDURE FOR LINER. j SLOWLY OPEN CHOKE AT 200'. SHUT DOWN � I FOR 10 MIN FLOW CHECK. WELL STATIC., 01:40 03:30 1.83 FISH P DECOMP !LAY DOWN FISHING BHA. RECOVERED -DEPLOYMENT SLEEVE:11.76' -3-1/2"STL PUP JOINT:9.73' 1-2.81"X NIPPLE:1.28' -1 JT 3-1/2"STL JOINT:31.91' XO 3-1/2"STL X 3-3/16"TCII :1.55' _ I-3-3/16"TCII PUP JOINT:9.91' 1 I -3 JOINTS OF 3-3/16"TC II LINER 1-1 PARTIAL JOINT 3-3/16"LINER:16.41' WELL STATIC. 03:30 - 05:10 1.87 I FISH P ( DECOMP STAB INJECTOR. CLOSE SWAB. j I PT QTS 300/3500# REVERSE TO PUMP SLACK BACK. 'OPEN SWAB VALVE. WELL STILL STATIC. POP OFF INJECTOR. INSTALL NIGHT CAP. I CIRCULATE ACROSS TOP WHILE CUTTING PIPE. I 1 105:10 - 06:45 1.58 FISH j- P j DECOMP +PJSM,RIG UP PIPE CUTTER j I -CUT 280'OFCOIL TOACHIEVE 1.8%SLACK 106:45 - 07:15 0.50 FISH P 1 DECOMP 1 PJSM.INSTALL SCHLUMBERGER INTERNAL ! KENDALL COIL CONNECTOR. 1 -PULL TEST @ 35K,PRESSURE TEST @ 300/ 1 I i 14000 PSI,GOOD TESTS. 107:15 - 08:30 1.25I FISH P DECOMP 1 PJSM.STAB ON WELL,PUMP WIRE AHEAD. (1)COIL VOLUME. 1 1-POP OFF WELL.HEAD UP BAKER UQC. 09:00 - 09:45 0.75 FISH P DECOMP PJSM.MAKE UP CLEANOUT BHA W/SMART TOOLS. -PRESSURE TEST UQC @ 300/4000 PSI,OK. ! I I -BIT GAUGES 3.81"GO/3.80"NO GO. 09:45 - 11:30 1.75 FISH P DECOMP RIH W/CLEANOUT BHA. 11 1 -WT CHECK @ 9152',43K UP WT,21K DOWN 1 WT. 1-PUMPING 1 BPM W/RIH,LOSS RATE 1-2 BPH. _ 11:30 - 12:00 0.50 FISH P DECOMP LOG TIE IN F/9150'@ 2.3 FPM. 1 -LOG DOWN TO 9218'.MINUS 18.5' CORRECTION. I 12:00 - 13:30 1.50 I CLEAN I-- P ! DECOMP PJSM..BRING UP PUMP TO 2.59 BPM/1750 I PSI/2.54 BPM OUT. -RIH TO 9242'CORRECTED DEPTH. -HAVE(20)BBLS HI VIS SWEEP COMING OUT 1 AT BIT WHEN @ 9242'. 1-WORK UP TO 9130'AND BACKDOWN TO 1 19242'SEVERAL TIMES. 1-PUMP 2ND 20 BBL SWEEP WHEN 1ST ONE I 1 ;EXITS PIPE. Printed 7/5/2016 11:00:37AM *AII depths reported in Drillers Depths* S • North America-ALASKA-BP Page 6 Operation Summary Report Common Well Name:K-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) i Start Date:6/17/2016 ', End Date:6/25/2016 X3-01712-C:(3,407,475.00) I I I Project:Prudhoe Bay Site:PB K Pad Rig Name/No.:NORDIC 2 1 Spud Date/Time:11/19/1983 12:00:00AM Rig Release:6/28/2016 Rig Contractor:NORDIC CALISTA UWI:500292104500 Active datum:K-07F @54.66usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase I Description of Operations (hr) 1 (usft) 1 13:30 - 15:00 1.50 I CLEAN P 1 DECOMP I OPEN EDC.FLOW CHECK,10 MIN,WELL !STATIC,SLIGHT LOSSES. 1-BRING ON PUMP @ 4 BPM/2700 PSI.WELL 1 HEAD PRESSURE @ 65 PSI. I-LOSS RATE 2 BPH. -6.4 PPG KCL IN AND OUT. I-POOH W/CLEANOUT BHA. FLOW CHECK W/BHAAT SURFACE,WELL 1 BORE STATIC. -8.4 PPG KCL IN AND OUT. 15:00 - 15:50 0.83 STWHIP 1 P WEXIT I PJSM.STAND BACK INJECTOR.LAY DOWN I 1 ( I 'CLEAN OUT BHA. 1-PICK UP WHIPSTOCK BHA.. I-STAB INJECTOR ONTO WELL @ 15:50 HRS. 15:50 - 16:15 0.42 STWHIP P j WEXIT 1TEST QTS,300/4000 PSI QTS. 1 -OPEN EDC,FILL LINES,ZERO OUT I COUNTER ON HORSES HEAD. 16:15 - 18:45 2.50 I STWHIP P WEXIT ;PJSM.RIH W/WHIPSTOCK ASSEMBLY,EDC I I OPEN. 1-RIH @ 60 FPM,PUMPING.5 BPM @ 130 PSI/ 1 �.75 BPM OUT RATE. 118:45 - 19:15 0.50 1 STWHIP P WEXIT -TIE INTO SAG-19' 119:15 - 20:15 1.00 STW-tIP N ( DPRB 9,232.00 WEXIT `LOGGED CCL FROM 9150'TO SET DEPTH. I DIDN'T WORK. 1 LOGGED TWICE MORE. FINALLY GOT 1 WORKING. RESTARTED PROGRAMS. CCL !WORKING NOW 20:15 - 20:55 0.67 STWHIP I P WEXIT 1 LOGGED SUCCESSFUL CCL FROM 9150'TO 1 SET DEPTH. 1 j COLLARS CAME IN 4'HIGH OFF TIE IN LOG. 120:55 - 21:15 0.33 STWHIP P WEXIT I DISCUSSED WITH ODE. !SHIFTED SET DEPTH TO 9211.2'TOWS AND 1 1 19227'BOWS ORIENTED 60°ROHS CLOSE EDC. PRESSURE UP AND SET I WHIPSTOCK I STACK 4K ON WHIPSTOCK. GOOD. PICK 1 1 OFF CLEAN j 110 MIN FLOW CHECK. WELL STATIC 21:15 - 23:30 1 2.25 STWHIP P ( WEXIT START SWAPPING WELL TO 9.5 PPG MUD HOLE SWAPPED. START PULLING OUT OF HOLE. I PJSM FOR SWAPPING BHA 23:30 - 00:00 1 0.50 STWHIP P 1 WEXIT IAT 200' 10 MIN FLOW CHECK. WELL STATIC 1 1 ITAGUP I I INJECTOR OFF 23:55 1 BREAK DOWN WHIPSTOCK BHA. BLOW 1 F I DOWN TOOLS. 4 6/21/2016 100 :00 - 00:35 1 0.58 STWHIP 1 P WEXIT ,CONTINUE PICKING UP BHA. 100:35 - 01:00 I 0.42 STWHIP 1 P WEXIT j INJECTOR ON 1 PT QTS 300#/3800# OPEN EDC.TEST TOOLS 101:00 - 02:45 1.75 STWHIP P 1 WEXIT RIH 0.80 BPM IN/ 1.21 BPM OUT(82 FPM) 19.44 PPG IN /9.46 PPG OUT 11A/OA=786#/89# Printed 7/5/2016 11:00:37AM *AII depths reported in Drillers Depths* S ! North America-ALASKA-BP Page Operation Summary Report Common Well Name:K-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/17/2016 End Date:6/25/2016 X3-017T2-C:(3,407,475.00) Project:Prudhoe Bay I Site:PB K Pad Rig Name/No.:NORDIC 2 Spud Date/Time:11/19/1983 12:00:00AM 'Rig Release:6/28/2016 Rig Contractor:NORDIC CALISTA I UWI:500292104500 Active datum:K-07F @54.66usft(above Mean Sea Level) Date From-To 1 Hrs Task Code i NPT 1 NPT Depth I Phase 1 Description of Operations (hr) (usft) 02:45 03:00 0.25 STWHIP PWEXIT 'COME OFFLINE. 1 NO FORMATION TIE IN I I DRY TAG AT 9230'UNCORRECTED. CORRECT TOP TO CORRECTED SET DEPTH OF 9211' PICK UP FREE SPIN 2780#@ 2.81 BPM BRING PUMPS ON. CREEP IN. ( ik 03:00 - 06:00 3.00 STWHIP P WEXIT 1 START MILLING WINDOW AT 9212.2' � K U1� 42.82 BPMIN/2.81 BPM OUT I 9.51 PPG IN/9.44 PPG OUT CIRC PRESSURE 2908#/1K DOWN ,TIME MILLING AT 1'FPH 06:00 13:30 7.50 STWHIPWEXIT �CONTINUE TO MILL WINDOWAS PER 1 I PROGRAM. -SLOW RATE TO 2.7 BPM/2740 PSI. -2.71 IN/2.67 OUT,10.48 PPG ECD. '-10-50 PSI MOTOR WORK AFTER EACH TENTH. TIME MILL TO 9221.2'.NO STALLS AT ALL ,SINCE COMMENCEMENT OF MILLING. I-NO REAL LOSSES, 13:30 - 14:50 1.33 STWHIP P WEXIT CONTINUE TO MILL WINDOWAS PER • 1 PROGRAM. 2.73 BPM IN @ 2690 PSI,2,71 OUT. 1-I/A 850 PSI,0/A 545 PSI.MILL TO 9222.5' 1 14:50 - 15:45 0.92 - STWHIP P WEXIT 1 COMMENCE MILLING IN OPEN HOLE AS WOB ALLOWS. 1 ;SAMPLE FROM 9222'SHOWS FORMATION 15:45 - 17:00 1.25 STWHIP P WEXIT !STARTING TO SEE SOME LOSSES-0.2 BPM DRILLED-0.5'MORE AND LOSSES INCREASED TO 0.5 BPM 17:00 - 17:10 0.17 STWHIP P- WEXIT I RAT HOLE MILLED PUMP 20 BBL LOW&HIGH VIS PILL 1117:10 - 18:50 1.67 STWHIP P I WEXIT START REAMING PASSES. PERFORM 3 SLOW UP/DOWN PASSES. BOTTOMS UP SAMPLE SHOWS 30% I FORMATION. FINAL DOWN PASS TAG BOTTOM AT 9232.2 I FT. 1 DRY DRIFT PAST BOTTOM OF WINDOW IS 1 CLEAN,NO WEIGHT CHANGE. 18:50 20:15 1.42 STWHIP P 1 WEXIT 'PICK UP SLOWLY FOR DYNAMIC FLOW CHECK,GOOD. 0.33/0.186PMIN/OUT. I OPEN EDC,PUMP 3.1/2.3 BPM WHILE POOH. 20:15 - 21:20 1.08 STWHIP P j WEXIT WHILE POOH,CONDUCT PJSM FOR CHANGING OUT BHA. TRIP SHEET IS-12 BBLS TO THIS POINT. 'TAG STRIPPER PUMPING HARD THEN RUN IN I FOR FLOWCHECK. 10 MIN PUMPS OFF FLOWCHECK IS GOOD, 1 I NO FLOW. FILL WELL WITH 0.3 BBLS THEN TAG UP, REMOVE INJECTOR. INJECTOR OFF AT 20:55. LAY DOWN MILLING BHA,MILL AND REAMER ' I 3.80"GO,3.79"NO-GO. BREAK DOWN MILLING BHAAND CLEAR RIG I FLOOR. Printed 7/5/2016 11:00:37AM *All depths reported in Drillers Depths* TREE 6-3/8"CNV FLS • SillY NOTES:PREVIOUS WELLBORES NOT WETUATORTADR= BA= BAKERC McEVOY ACTUATOR K�0 7 E --- '-- - -- SHOWN ON THIS DIAGRAM. OKB.ELEV= 63.21' REF ELEV= 54.66' BF ELEV= 27.91' KOP 9325' ' ' 2014' —14-1/2"HES X NP,ID=3.813" Max Angle= 67°@ 9634' Datum MD= 10061' 2604' 9-5/8"DV COLLAR u- -- S Datum TVD= 8800'SS GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80,ID=12.347" H 2709' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3295 3292 10 MMG-M DMY RK 0 01/16/16 3 6012 5555 43 MMG-M DMY RK 0 01/16/16 TOP OF 7'LNR —I 6803' 1 2 7836 7037 15 KBG-2LS DMY INT 0 12/06/99 9-5/8"X 7"BKR ZXP PKR H 6803' 1 8888 8064 8 KBG-2LS DMY INT 0 12/06/99 w/TISK SLV ID=6.313" 9-5/8"X 7"BKR HMC HGR,ID=6.250" —I 6816' / 9-5/8"CSG,47#,L-80,ID=8.681" —1 6992' i-- Minimum ID =2.387" @ 10279' I I 8997' —14-1/2"HES X NIP,ID=3.813" 3-3/16" X 2-7/8" Z M9011' H 7"X 4-1/2"HES TNT PKR,O=3.875" ' 9028' H4-1/2"HES XN NIP-MILLED OUT 01/21/05,ID=3.80" 9036' —17'x 5"BKR ZXP PKR,ID=4.375" H 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" 9040' —Z' 9040' —{4-1/2"WLEG,ID=3.958" 9050' H7"X 5"BKR HMC HGR,ID=4.375" 9058' H5"X 4-1/2"XO,ID=4.00 7"LNR,26#,L-80 BTC-M, H 9189' —All .0383 bpf,ID=6.276" 4-1/2"WHIPSTOCK(06/20/16) —H 9212' \ MILLOUT WINDOW(K-07E)9233'-9242' 4-1/2"WHIPSTOCK H 9233' 2 RA TAGS — 9242' di 40 9330' -1 JET CUT LNR(03/01/16) PERFORATION SUMMARY twill ` REF LOG: NA 10279' 3-3116"X 2-7/8"XO,ID=2.387" ANGLE AT TOP 11JtF:49°@ 10114' / Note:Refer to Production DB for historical pert date SIZE SPF INTERVAL m/S SHOT SQZ 3-3/16"LNR,6.2#,L-80 TCII, —I 10279' IIN 2" 6 10114-10124 0 05/28/12 .0076 bpf,ID=2.80" 2" 6 10185-10280 0 02/18/10 PBTD —1 10282' 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,ID=2.441" 10300' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/05/83 ORIGINAL COMPLETION 02/17/16 JMG/JMD GLV C/O(01/16/16) WELL: K-07E 12/06/99 RIG SIDETRACK(K-07C) 02/17/16 RCT/JMD PULLED LW(01/18/16) PERMIT No: 2091270 01/21/05 NORDIC 1 CTD(K-07D) 03/02/16 MRD/JMD JET CUT LNR(03/01/16) AR No: 50-029-21045-05 02/20/10 NORDIC 1 CTD SIDETRACK(K-07E) SEC 4,T11N,R14E,2041'FNL&473'FWL 05/07/14 DU/JMD TREE C/O(04/29/14) 10/30/14 LEC/PJC PULL IBP/SLUGGITS BP Exploration(Alaska) V OF T� • • h\����y/��s� THE STATE Alaska Oil and Gas 41,0.---- -.-t--;=-A7.4 o f Conservation Commission . ALAS <:A s � �� 333 West Seventh Avenue l ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ^h.: ....' Main: 907.279.1433 Ode, ":e.,0` Fax: 907.276.7542 www.aogcc.alaska.gov John McMullenMAR 2016 Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-07E Permit to Drill Number: 209-127 Sundry Number: 316-114 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Al'a414-7(4. - Cathy P. Foerster Chair DATED this Z`t'day of February, 2016. RBDMS 1,V FR ( 91i STATE OF ALASKA ' •ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPROV S 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill p • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 209-127 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p- 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-21045-05-00 • 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? RECEIVED������D Will planned perforations require a spacing exception? Yes 111 No IRI PBU K-07E - 9. Property Designation(Lease Number): 10. Field/Pools: FEB 0 J 2016 ADL 028303&028300 PRUDHOE BAY,PRUDHOE OIL , b cla .2 pr 11. PRESENT WELL CONDITION SUMMARY GC� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Jung 119 10301 . 9008 - 10282 - 8996 - 2566 None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 31-111 31-111 1530 520 Surface 2670 13-3/8" 30-2700 30-2700 4930 2670 Intermediate 6965 9-5/8" 27-6992 27-6279 6870 4760 Liner 2386 7" 6803-9189 6139-8363 7240 5410 Liner 196 4-1/2" 9036-9232 8211-8405 8430 7500 Liner 1150 3-1/2"x 3-3/16"x 2-7/8" 9150-10300 8324-9007 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10114-10280 8890-8995 4-1/2"12.6# L-80 25-9040 Packers and SSSV Type: 4-1/2"HES TNT Perm Packer Packers and SSSV MD(ft)and TVD(ft): 9011 /8186 12.Attachments: Proposal Summary 0 Wellbore Schematic Ej 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch lI Exploratory 0 Stratigraphic 0 Development lI - Service ❑ 14.Estimated Date for Commencing Operations: February 25,2016 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL 0 Suspended WI • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Browning,Zachary H be deviated from without prior written approval. Email Zachary.Browning@bp.com Printed Name John M.r u .r• 4 Title Engineering Team Leader / +1 907 564 4711 Date 2/7 4:lr:; Signature / / ' Phone t COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number Plug Integrity ,� ❑ BOP Test i ' Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 I ,0p -rest '[O 3SW pstc, N1..5151 1%-Niz, PQEsfg►f iz,"MST -to 2 (D PStG * k.--Earp RAh.c. Pt.v.k.N►E►r APPct-oveD PER. 20 AAL 25.1%10 wrn 24W PS1 Post Initial Injection MIT Req'd? Yes 0 No 0 J �'tr o� 1...Kr P2ESSv�CL� l e51 Spacing Exception Requiratzed? Yes 0 No r Subsequent Form Required: 13 —401 APPROVED BYTHE Approved by: �� COMMISSIONER COMMISSION Date: 2- -/ , ORIGINAL RBDMS L1. FEB L 6 2016 tgl-Q, 1.12AI.6 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate . • To: Alaska Oil & Gas Conservation Commission From: Zach Browning 0 by CTD Engineer Date: February 3, 2016 Re: K-07E Sundry Approval Request Sundry approval is requested to plug the K-07E perforations as part of the preparation, drilling and completing the proposed K-07F coiled tubing sidetrack. History of K-07E: K-07E was completed as a CTD sidetrack in 2010. Unfortunately the well is no longer competitive ' and has no future wellwork options. The well has passed integrity and is fit for a sidetrack. Proposed plan for K-07F: Drill a through tubing sidetrack with a Nordic Coiled Tubing Drilling rig on or around April 1st, 2016. A cut and pull of the K-07E CTD liner is planned in open hole and the K-07F sidetrack will exit from the existing 4-1/2" liner (from the K-07C completion). It is planned to re-use the K-07E window and set an open hole anchored billet in the parent wellbore. The planned billet kicks-off is in Zone 4, builds through the conglomerates and will land and target reserves in Zone 1A south of the grandparent well. The proposed sidetrack is a -3000' horizontal Ivishak Zone 1 producer to be completed with a 3-1/4" x 2-7/8" L-80 solid liner, cemented in place and selectively perforated. This Sundry covers plugging the existing K-07E perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). L 24co Ps% -TEST +►� `Z'1��b The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin February 25th, 2016) 1. E Cut Liner 2. C Catch and Verify Liner Released 3. V Pre-CTD tree work. Set TWC. Rig Work(scheduled to begin April 1st, 2016) 711' 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,566 psi). %.7‘ S vv-7��� 2. Pull Liner and perform Clean-out Run. 3. Set OH Billet(Contingency to set Whipstock and mill 3.80"window) 4. KO Billet and Drill build: 4.25" OH, 470' (26 deg DLS planned). 5. Drill Lateral: 4.25" OH, 2390' (12 deg DLS planned) 6. Run 3-1/4" x 2-7/8" L-80 liner leaving TOL at-9200' MD. /VC w 7. Pump primary cement job: 35 bbls, 15.8 ppg Class G, TOC at-9200' MD.* 8. Perform liner lap test. -tvp 24w i'Sl P J D 9. Perforate -1000' based on log interpretation. 10. Freeze protect well to a min 2,200' TVDss. 11. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) • S Post-Rig Work: 1. 0: Re-install wellhouse, and flowline. 2. V: Tree work as necessary. 3. S: Set kickoff GLVs / MRPM / and set liner top packer if liner lap test fails.* Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 !IEE= • 6-3/8"CNV FLS V ELLLI AD= IuIoEVOY • S OTES:PREVIOUS WELLBORES NOT ACTUATOR= BAKER C v7 LJSED PROPO0 7 SHOWN ON THIS DIAGRAM. OKB.ELEV= 6321' BF.ELEV_ 27.91' KOP= 9325 Max Angle= 67"@ 9634' ' r 2014' --I4-1/2"HES X NP,D=3.813" m M) [ tu = 10061' Datum TVD= 8800'SS 2604' -19-5/8"DV COLLAR GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" -1 2709' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3295 3292 10 14/MG-M DOME RK 16 03/04/10 3 6012 5555 43 MMG-M SO RK 20 03/04/10 TOP OF 7'LNR H 6803' 4 i 2 7836 7037 15 KBG-2LS DMY INT 0 12/06/99 9-5/8"X 7"BKR ZXP PKR - 6803' 1 8888 8064 8 KBG-2LS DMY INT 0 12/06/99 w/T1EBKSLV,D=6.313" 9-518"X 7"BKR HMC HGR,D=6.250" -I 6816' 9-5/8"CSG,47#,L-80,D=8.681" -1 6992' I-- Minimum ID=XXX"@ XXX' I II 8997' -14-1/2"HES X NP,D=3.813" S �I 9011' H7"X 4-1/2"HES TNT PKR,D=3.875" ' 9028' H 4-1/2"HES XN NP-MILLED OUT 01121/05,ID=3.80" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 9040' 9036' -17'x 5"BKR ZXP PKR,D=4.375" 9040' H4-1/2"WLEG,ID=3.958" 9050' -I 7"X 5"BKR HMC HGR,D=4.375" 9058' --1 X 4-1/2"XO,ID=4.00 7"LIAR,26#,L-80 BTC-M, H 9189' .__Al _0383 bpf,ID=6.276" 9210' -13.70"DEPLOY SLV,ID=3.00" 9223' H3-1/2"X 3-3/16"XO,D=2.786" 4-1/2"WHIPSTOCK - 9233' MLLOUr WKNDOW(K-07E)9233'-9242' 2 RA TAGS 9242' N ` 3.625"Open Hole Aluminum Bilet 9315' PERFORATION SUMMARY ---"N- ` — XXX -13-3/16"X 2-7/8"XO,ID=2.387" REF LOG: NA / ANGLE AT TOP FERE:XX"@ XXX' Note:Refer to Production DB for historical pert date 33!16 Ting at - 9330' SIZE SFF INTERVAL in/F SHOT SOZ 3-3/16"LNR,6.2#,L-80 TCN, XXX .0076 bpf,ID=2.80" PBTD H 12135' 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" 12175' DATE REV BY COI MBJTS DATE REV BY C0ttV NTS PRUDHOEBAY WET 12/05/83 ORIGINAL COMPLETION 03/10/10 CHUM) DAG DRAFT CORRECTIONS WELL: K-07E 12/06/99 RIG SIDETRACK(K-07C) 06/04/12 RM+JMD SET IBP,SLUGGITS,PERFS(05/28-31/' PERMIT No:'2091270 01/21/05 NORDIC 1 CTD(K-0713) 06/17/12 RRD/PJC BR SLUGGITS DEPTH CORRECTIONS AR No: 50-029-21045-05 02/20/10 NORDIC 1 CTD SIDETRACK(K-07E) 05/07/14 DU/JFuD TREE C/O(04/29/14) SEC 4,T11N,R14E,2041'FM_&473'FW 03/04/10 DAV/PJC GLV GO 10/30/14 LEO PJC PULL BP/SLUGGITS 03/06/10 PJC DRLG I-10 CORRECTIONS BP Exploration(Alaska) TREE= ' 6-3/8"CNV FLS ,V4H1-FAD= nAcEVOY • S TES:PREVIOUS WELLBORES NOT ACTUATOR= BAKERC K-07 E SHOWN ON THS DIAGRAM. ................... .................... OKB.ELEV= 63.21' BF ELEV= 27.91' I KOP= 9325' Max Angle= 67"Q 9634' ■ 2014' H4-1/2"HES X NP,D=3.813' II Daturn_MD= 10061' Datum TVD= 8800'SS 2604' 9-5/8"DV COLLAR GAS LFT MANDRELS 13-3/8'CSG,72#,L-80,ID=12.347" —I 2709' ST MD ND DEV TYPE VLV LATCH FORT DATE 4 3295 3292 10 MMG-M DOME RK 16 03/04/10 3 6012 5555 43 M1G-M SO RK 20 03/04/10 TOP OFT LNR H 6803' j 2 7836 7037 15 KBG 2L5 DM'( PIT 0 12/06/99 9-5/8"X 7"BKR ZXP PKR --i 6803` f 1 8888 8064 8 KBG 2LS DRAY PIT 0 12/06/99 w/11E8KSW,D=6.313" 9-5/8"X 7"BKR FRAC HGR,13=6.250" I— 6816' 9-5/8"CSG,47#,L-80,13=8.681' —i 6992' H Minimum ID =2.36" @ 9150' 1 1 8997' —j4-1/2"FES X fes?D=3.813" 4-1/2" KB LNR TOP PACKER Z N 9011' I—{7"X 4-1/2'FES TNT PKR,D=3.875" I IILS 9028' H4-1/2"FES XN h1P-NR.LED OUT 01121/05,D=3.80' 4-112'TBG,12.6#,L-80,.0152 bpf,D=3.958" H 9040' 9036' -17'x 5'BKR ZXP PKR,D=4.375' 9040• H4-1/2"WLEG,D=3.958" 9050' Hr X 5"BKR FSAC HGR,D=4.375' 9058' 1H5-X 4-1/2"XO,ID=4.00 9150' --14-1/2'KB PKR,D=2.36" 9155' H3.70"DEPLOY SLV,D=3.00- 9176' I-3-1/2"OTISXNP,D=2.812" 7"LNR,26#,L-80 BTC-M, H 9189' fA lib. 9210' I—I3-1/2'X 3-3/16'XO,D=2.786' .0383 bpf,D=6.276' 4-112"WHPSTOCK —I 9233' 44 N6.LOUT WNDOW(K-07E)9233'-9242' ``4 2 RA TAGS --1 9242' a •". ` PERFORATION SUMMARY N.! REF LOG: NA --IIli 10279' H3-3/16'X 2-718"XO,D=2.387' ANGLE AT TOP PERF:49"©10114' Note:Refer to Roduction DB for historical perf date SIZE SPF INTERVAL m/E SHOT SOZ 3-3/16"LNR,62#,L-80 TC*, 10279' 2 6 10114-10124 0 05/28/12 .0076 bpf,13=2.80' 2' 6 10185-10280 0 02/18/10 PBTD —I 10282' 2-7/8"LNR,6.16#,L-80 SIL,.0058 bpi,D=2.441" H 10300' DATE REV BY COMFITS DATE REV BY CONVENTS PRUDHOE BAY UNIT 12/05/83 ORIGINAL COMPLETION 03/10/10 CWJND DRLG DRAFT CORRECTIONS WELL: K-07E 12/06/99 RIG SIDETRACK(K-07C) 06/04/12 RMJJM) SET BP,SLUGGITS,PERES(05/28-31/ FT :"2091270 01/21/05 NORDIC 1 CTD(K-07D) 06/17/12 RRIY PJC BR SLUGGITS DEPTH CORRECTIONS AR No: 50-029-21045-05 02/20/10 NORDIC 1 CTDSIDETRACK(K-07E) 05/07/14 DU/JMD TREE C/O(04/29/14) SEC 4,T11N,R14E,2041'FM.&473'FWL 03/04/10 DAV/PJC GLV C/O 10/30/14 LEC/PJC RILL BR SLUGGITS 03/06/10 PJC DRLG HO CORRECTIONS BP Exploration(Alaska) • • I- a I. — n a I. x ' $ g sf : 1 sirEM g u u s 0 I I' f- . IE 1 u ii ■ I l u 1 d c —gra s20.2 H m A G a K O m 1 Q m I 4 i s I l $ 6 11 o ff I a. Ii : a--w 1 w I O ;11 b I b Iu 111 Il III t I c a 'r /r r m <Z I = a m fI� 11111 °- ill a I U7 g I �� 1 I € III 1t1 Z o I UO 0 ,ti Q Oil lir i m 111 111 J _ II. zi b E o O J H �p U I f LL W K" C • • re ry • • Iil - I IC ler ,.. L J ♦ 1 E LIJ !I, ! II: = . - a a' V • IIJ a a F CL 11 I LLI 0 I s U 2 r b 66 @ 041 QL to r 1- co ii 1 U_ ' • 8 1 . 0 m Im �, _ _ I cm 1111111 Z a i v 1 d III a c N 9 ow n ". MI 6 Ifl m e 1 11- I®1 41 I 11 1 11111 • 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 At 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 f 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) o(Sl;- 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. r \r I cA ,/, 0 cc - C P� � 1�_ to U JO 4 m a CD (J11 a U c� .:11-0 co Y N� a a o l' a Y -C C 00 H >• co 0 O a U a E • 0 W a c ° O O H Q @ Y (o > a Q C 0 Uj 0 (0 (0 (O a7 (O CO LO (o O v E CO L u y_, F — O 0 A to R (0 m (0 O v, s c C is H z ? ' ? z E " (o 2 Vl F M O O H N th H 4 -0 Q > cn Z Q N C (o a Q a Q • _ L1- C13 7 a }' (o : 0 0 0 0 0 0 0 0 (a a U _C LT a -.I J J J J J J J Y W W W W Will Will cM c (0 O F LL LL LL LL LL LL LL LL 7 a E a L" O QJ J J J J J J J '-' a 0 C a � CO 1- aQQQQQ QQ 0_ _0 C O 0 z z z z z z z z a) -0 •� LL LL LL LL LL LL LL LL v C a . O Ea a OO COZ v0 a Ur. 0 c o _0 c sa cy P. a) a .-, .. COO 21 ° . V vOQ _c U > 11.4> H H x L. i+ L'. i.. O nix O (A 0 0 J O i Q II w - .ti- 0. _52J _j iL 15 CO C F w ca U "" wr 0 W al 8 m > z alt ro . II �: S s!� a ea — �}~. z; V▪ N 0:1 � d J O O O O 0 _1 _1 p 2 � CD6) � � . za � U 2 E E t"......."11r\...,..."..III 4! Li) . >- >- >- >- >- >- >- ,, Q Q Q Q Q Q Q ,° 2 m m m m CO N CO CO < a! W W W W 2 W W Z 0 0 0 O O Q O O 0 2 2 2 2 2 ) 2 2 -J00000000 a W > > > > > C. > > 0 LL 0' 0_ 0: W W 0: 0: a o 0 0 0 0 0 r0 C Lt1 V X (0 o a. N U 0 0 0 Co p o 0 0 0 0 0 0 o p o i 0 0 0 0 C, 0 0 0 `n • O l.J co co co V CO N N — Ql CC) 0 in in 0• 0 0 0 0 O 0 0 m a W U U Mt OD • LL r9 a `0 CC 2 O O o 0 0 0 O 0 U (() 0) O) 1() O O M rco Q XO f-- P 4 a h M '- M (0 CO 0 h (0 N (0 N 0 0 M M 0 N NN NN N N N N N Co g NNNNNNNN C Q1 O 0 0 O O O O O c O N O 0 0 0 0 0 0 0 (0 C In (0 u) in N N (0 N a+ - m MD o: .-1 . •o G a w Cin Cn E v •m o CO b g , 7, U rn N Q Q W 0 T Csi N M a C ! N (''> M M N M r E N U K I a Q N 4 4Y Y a o E z ai s v .IP▪ .0 r" c c ((D U d Bei I f_ H m • • 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 by direct inspection of the file. p2O - la 7 Well History File Identifier Organizing (done) ❑ Two -sided II 111111 111 111 ❑ Rescan Needed 11 111111 III I RES N DIGITAL DATA OVERSIZED (Scannable) Colo Items: ❑ Diskettes, No. ❑Maps: reyscale Items: ( ' 4 Other, No/Type:CP I\10. 1, ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: r Li Other:: . BY: Date: Y /s/ Project Proofing III 111111 II III I BY: 41g, Date: 11 6111 /s/ lir.f Scanning Preparat ion cl. x 30 = 60 + 7 = TOTAL PAGES (Q7 (Count does not include cover sheet) + /► n BY: Maria Date: II /s/ Production Scanning III 111111 1 1111 Stage 1 Page Count from Scanned File: Cl (Count does include cove heet) Page Count Matches Number in Scanning Preparation: V YES NO 9 g BY: Date: , " /s/ �� Stage 1 If NO in stage 1, page(s) discrepancie 0, were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11 11111 I I 1111 ReScanned II EMI I III I BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED ALGA OIL AND GAS CONSERVATION COMSION REPORT OF SUNDRY WELL OPERATIONS JUL 31 ° 2 ' 012 1. Operations Abandon Li Repair Well Li Plug Perforations U Perforate U r� OG C C Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ 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 El Exploratory ❑ 209 -127 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21045 -05 -00 7. Property Designation (Lease Number): glil 8 . Well Name and Number: ADL0028303 A 11 f ( PBU K -07E 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10301 feet Plugs measured None feet true vertical 9007.89 feet Junk measured None feet Effective Depth measured 10130 feet Packer measured See Attachment feet true vertical 8900.86 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 28 - 108 28 - 82.66 1530 520 Surface 2673 13 -3/8" 72# L -80 27 - 2700 27 - 81.66 4930 2670 Intermediate None None None None None None Production 6964 9 -5/8" 47# L -80 28 - 6992 28 - 82.66 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet 5iwitsiMED AUG . *1 U j2- Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 9040 25 - 79.66 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 Prior to well operation: 774 49059 5 0 1087.9 Subsequent to operation: 712 51396 10 0 1119 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . isi Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature ,JCc ,.. C Phone 564 -4424 Date 7/27/2012 Form 10 -404 Revised 10 /201 p'Vis AUG 0 1 2O16fif_" 1. et ji ri . Submit Original Only '(TCli N. l Casing / Tubing Attachment ADL0028303 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 28 - 108 28 - 82.66 1530 520 LINER 2373 7" 26# L -80 6816 - 9189 6148.44 - 6203.1 7240 5410 LINER 1069 3- 3/16" 6.2# L -80 9210 - 10279 8383.46 - 8438.12 LINER 175 4 -1/2" 12.6# L -80 9058 - 9233 8232.44 - 8287.1 8430 7500 LINER 21 2 -7/8" 6.16# L -80 10279 - 10300 8994.21 - 9048.87 13450 13890 LINER 55 3 -1/2" 9.2# L -80 9155 - 9210 8328.8 - 8383.46 10160 10530 • PRODUCTION 6964 9 -5/8" 47# L -80 28 - 6992 28 - 82.66 6870 4760 SURFACE 2673 13 -3/8" 72# L -80 27 - 2700 27 - 81.66 4930 2670 TUBING 9015 4 -1/2" 12.6# L -80 25 - 9040 25 - 79.66 8430 7500 • . • • Packers and SSV's Attachment ADL0028303 SW Name Type MD TVD Depscription K -07E PACKER 6803 6084.13 7" Baker ZXP Mech Top Packer K -07E PACKER 9011 8131.15 4 -1/2" HES TNT Perm Packer K -07E PACKER 9036 8155.95 5" Baker ZXP Top Packer K -07E PACKER 9150 8269.17 4 -1/2" Baker KB Top Packer . • • Perforation Attachment ADL0028303 Perf Meas Meas Operation Operation Depth Depth TVD Depth TVD Depth SW Name Date Code Top Base Top Base K -07E 5/28/12 APF 10114 10124 8890.36 8896.95 K -07E 5/28/12 BPS 10130 10280 8846.2 8940.17 K -07E 5/31/12 SPS 10130 10185 8846.2 8880.77 K -07E 2/18/10 PER 10185 10280 8880.77 8940.17 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 1 • Daily Report of Well Operations ADL0028303 ACTIVITYDATE ( -.., SUMMARY • i ' : 4 DRIFT TUBING W/ 9' OF 2.25" DRIVE DOWN BAILER. SD ON STICKY BOTTOM @ 10217' SLM. 10244' MD WITH 27' KB /BF CORRECTION. INDICATING 36' OF FILL ABOVE LOWEST OPEN PERF. BAILER RECOVERED APPROXIMATELY 1 GALLON OF FORMATION SAND. a RAN 9' OF 2.25" PUMP BAILER TO 10222' SLM. RECOVER 1.3 GALLONS OF FORMATION SAND. 4/29/2012 ** *WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE. * ** T /I /O = 2350/660/0 ( Assist SEL with RST log) Load well with 228 bbls 2% KCL, pump 67 bbls 2% KCL while E -line logs. Freeze protect with 40 bbls crude. FWHP vac /676/0 5/27/2012 SLB on well at departure ** *CONTINUED FROM PREVIOUS DAY * ** TREE VALVES STILL FULLY OPERATIONAL. RIGGED UP AND RAN RST SIGMA FROM 9100 - 10245', DEPTH CORRECTED TO SLB MCNL LOG DATED 18- FEB -10. TAGGED TD AT 10245'. MADE THREE UP PASSES AT 30, 60, 60, ALL PASSES OVERLAY. LRS KILLED WELL WITH 220 BBLS 1% KCL AND LOGGED WHILE PUMPING 0.5 BPM KCL. PUMPED FREEZE PROTECT OF CRUDE BEFORE RIGGING DOWN LRS. UPLOADED DATA TO INTERACT, TOWN ENGINEER REVIEWED LOG AND DECIDED TO GO WITH OPTION #1 ON LOGGING PROGRAM. RETURN IN MORNING FOR PERF GUN RUN AND IBP AS INSTRUCTED. HANDOVER WITH DSO PRIOR TO DEPARTURE, WELL LEFT SHUT -IN AND SECURE. 5/27/2012 ** *CONTINUE NEXT DAY * ** T /1 /0= 231/6/0 Temp =SI Assist E -line (Profile Modification) Pump 40 bbls 80* crude down TBG. Final WHP's= 45/6/0 E -line on well upon departure WV= CLOSED SW, MV, SSV =OPEN 5/28/2012 IA,OA =OTG ** *CONTINUED FROM PREVIOUS DAY * ** RAN 2" HSD 6SPF 60 DEGREE PHASED PJ2006 GUN FROM 10114'- 10124' DEPTH CORRECTED TO SLB MCNL DATED 18- FEB -10. CONFIRMED ALL SHOTS FIRED. SET BAKER 2.13" IBP AT 10160' MID - ELEMENT DEPTH. SLACKED OFF TO CONFIRM SET OF IBP. PUMPED 40 BBLS CRUDE DOWN TUBING PRIOR TO SETTING IBP TO FLUSH ANY PERF DEBRIS FROM SETTING ZONE AS PER PROGRAM. IBP IS 11.05' FEET LONG, 1.375" FISHNECK, PINNED FOR 1840# DOWN TO EQUALIZE, 5500# UP TO RELEASE, THREE ELEMENTS, 2 - 6" SEALING AND 1 - 1" STIFFENER RING. LEFT WELL SHUT -1N AND READY TO POP. HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T /I /0 = 50/700/0. 5/28/2012 ** *JOB COMPLETE * ** ***WELL FLOWING ON ARRIVAL * ** (profile -mod) TAGGED IBP W/2.25" CENT, 2" LIB @ 10,141' SLM (impression of shear stud) DUMP BAILED 11' OF SLUGGITS ON IBP (final depth 10,130' SLM) 5/31/2012 ** *WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS * ** TREE= ' 6" 1vtEVOY • 't!VHaJfAD= ktcEYOY K 0 7 E SAFI�OTES: ORK9NAL, SIDETRACK "A ", "B", ACTUATOR= 011S C" & W ELLBORES NOT SHOWN ON THIS KB. EL-6T= 54.66' DIAGRAM. BE B_E1/ = 27.91' :I - KOP = _..._ __ _..e 9325' Max Angle =— 67° @k,34. ' ' I 2014' H4-1/2" FES X NP, D = 3.813" 1 Datum ( MD _= = -- 10061' tumTVD __ 8800' SS 2604' H9 -5/8" DV COLLAR 1 GAS LFT MMCRELS 113 -3/8' CSG, 72#, L -80, E)= 12.34r H 2709' ST MD TV D DEV TY FE VLV LATCH PORT DATE 4 3295 3292 10 MMG-M DOME FE 16 03/04/10 .....-A 3 6012 5555 43 MMG-M SO FE 20 03/04/10 Minimum ID = 2.36° @ 9150' 2 7836 7037 15 KBG -2LS DMY WIT 0 12/06/99 LINER TOP PACKER 1 8888 8064 8 KBG - 2LS DMY M 0 12/06/99 I TOP OFT LNR H 6803' I 1 ) 1 6803' H 9-518" X r BKR ZXP FKR w /TIEBK SLV, D = 6.313" I I P" -- --I 6816' H 9-5/8• X 7• BKR MAC HGR, D X250" • 19 -5/8" CSG, 47 #, L-80, D = 8.681' H 6992' ' I 8997' H41/2" FIES X NP, D = 3.813" I X I 9011' H7' X 4-1/2" FES TNT PKR, D = 3.875" I I 9028' H412' I-ES XN NP -MLLED OUT 01/21/05, D = 3.80' I I 9036' H T x 5" BKR ZXP PKR, 0= 4.375" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 9 040' ' • '', H I • 9040' H4-12" WLEG, 13= 3.958" I 9050' H 7' X 5' BKR MAC HGR, D = 4.375" I 9058' H 5'X4-12 "XO, D =4.00 I 9150' H4-1/2" KB FKR. D = 2.36" I I 9155' H 3.70" DEPLOY SLV, D = 3.00' I I I 9176' H 3 - 1 x NP, D= 2.812' 1 • 7" LNR, 26 #, L-80 BTGM 9189' I I I 9210• H 3 12' x 33/16' xo, D = 2.786 .0383 bpf, D = 6.276' i MLLOL<T WIDOW (K•07E) 9233' - 9242' 1 141/2 WFPSTOCK H 9233' �. 12 RA TAGS H 9242' % 0 ^'10142' I- -1SLUGGITS (05/31/12) _+ 10153' 12 -1/8' BKR BP (05/28/12) 1 FERFORATION SUMMARY , REF LOG: NA —I 1 0279' H3 -3/16" x 2 -7/8" xo, D = 2.387" 1 ANGLEAT TOP F3 :49° �c 10114' P N .)1V Note: Refer to Production DB for historical perf data ? 4 Q SPF _ `' ,z 3 -3/16" LNR, 6.2#, L -80 ICI, 10279' 2' 610114-10124 O 0528/1 pp76 bpf, D = 2.80' 1 _, 10185- 10280 C 0 PBTD 10282' 12 -7/8" LNR, 6.16#, L -80 STL, .0058 bpf, 0 = 2.441' H 10300' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/05/83 ORIGINAL COMPLETION 03/10/10 CH/JMO DRLG DRAFT CORRECTKNS WELL K -07E 12/06/99 RIG SIDETRACK (K-07C) 06/04/12 RM /JMD SET P. SLUGGITS, PERFS (05/28 -31/12 PERMIT No: "1091270 01/21/05 NORDIC 1 CID (K-07D) 06/17/12 RRD/ PJC IBP/ SLUGGITS DEPTH CORRECTIONS API No: 5 21045.05 02/20/10 NORDIC 1 CM SIDETRACK(K-07E) SEC 4, T11N, R14E, 2041' FNL & 473' FWL 03/04/10 DAV /PJC GLV C/O 03/06/10 PJC DRLG HO CORRECTIONS BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 2/10/2011 Permit to Drill 2091270 Well Name /No. PRUDHOE BAY UNIT K -07E Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21045 -05 -00 MD 10301 TVD 9008 Completion Date 2/20/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, GR / CCL / CNL (data taken from Logs Portion of Master Well Data Maint III Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type- Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Log Neutron 5 Blu 8794 10268 Case 4/26/2010 MCNL, Lee, TNN, TNF, GR, CCL ED C Lis 19585 - Neutron 8784 10278 Case 4/26/2010 LIS Veri, GR, CNT ■ _ 7 LIS Verification 9119 10301 Open 6/3/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS -ED C Lis 19710�duction /Resistivity 9119 10301 Open 6/3/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS tog Induction /Resistivity 25 Col 9230 10301 Open 6/8/2010 MD MPR, GR { Log Gamma Ray 25 Col 9230 10301 Open 6/8/2010 MD GR •g Gamma Ray 5 Col 9110 10310 Open 6/8/2010 Depth Shift Monitor Plot 'pt LIS Verification 9119 10441 Open 6/3/2010 PB1 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS III 1 pt 19714 duction /Resistivity 9119 10441 Open 6/3/2010 PB1 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS L '' Induction /Resistivity 25 Col 9230 10440 Open 6/8/2010 PB1 MD MPR, GR L5g% Gamma Ray 25 Col 9230 10440 Open 6/8/2010 PB1 MD GR I , • Gamma Ray 5 Col 9110 10444 Open 6/8/2010 PB1 Depth Shift Monitor Plot D C Asc Directional Survey 9600 10301 Open 'pt Directional Survey 9600 10301 Open - fr C Asc Directional Survey 9224 10440 Open PB1 DATA SUBMITTAL COMPLIANCE REPORT 2/10/2011 Permit to Drill 2091270 Well Name /No. PRUDHOE BAY UNIT K -07E Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 21045 -05 -00 MD 10301 TVD 9008 Completion Date 2/20/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N pt Directional Survey 9224 10440 Open PB1 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION / Well Cored? Y (N Daily History Received? /`N Chips Received ? —Y 1 N Formation Tops l) N Analysis Received? Comments: Compliance Reviewed By: Date: 16 l eL oJ21.JG/ • • 1 INTEQ Log & Data Transmittal Form f State of Alaska -AOGCC 333 W. 7 th Ave. Suite 100 Anchorage, Alaska 99501 ion: Christine Mahnken Reference: K -07E Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) ( e p g 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job #: 3002527 Sent by: Donna ss Date: 6, 1 4 Received by Date: 8 2 waC i r) PLEASE ACKNOWLEDGE RECEIPT BY SIGH f? E RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive BAICER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 BAKER FN11./GHES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH WELL NAME K -07E STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 6/8/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #: 3002527 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bvj Page 1 of 1 • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7` Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: K- 07EPB1 A ether Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary fl 1 'E 4 {� 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job #: 3002527 009 g 1 Sent by: Donna Moss Date: 06/02/10 Received by Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ 7260 Homer Drive BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 49,$!„. . -P I ES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUN'CY NORTH SLOPE BOROUGH WELL NAME K- 07EPB1 STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 6/2/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: Donna Moss SO #: 3002527 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By:, BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: Page 1 of 1 RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 8 2010 WELL COMPLETION OR RECOMPLETION REPORT ANLaLOGsCons.Commission la. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1 b. Well Class: Ancn(xair 20AAC 25.105 2OAAC 25. 110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Abend.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 2/21/2010 209 - 127 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 2/8/2010 50 029 - 21045 - 05 - 00 • 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number. Surface: 2/14/2010 PBU K -07E 2041' FNL, 473' FWL, SEC. 04, T11 N, R14E, UM 8. KB (ft above MSL): 54 15. Field / Pool(s): Top of Productive Horizon: 1232' FSL, 1299' FWL, SEC. 33, T12N, R14E, UM GL (ft above MSL): 26.21' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1310' FSL, 1218' FWL, SEC. 33, T12N, R14E, UM 10282' 8996' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD): 16. Property Designation: Surface: x- 670744 y - 5975163 Zone- ASP4 10301' 9008' ADL 028303 & 028300 TPI: x - 671486 y - 5978454 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 671403 y 5978530 Zone- ASP4 None 18. Directional Survey: El Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): N/A ft MSL 1900' (Approx.) (Submit electronic and printed information per 20 AAC 25.050) ( PP ( P P ) 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 DIR / GR, GR / CCL / CNL 9232' 8405' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING Wr. PER FT. GRADE ToP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 2709' Surface 2709' 17 -1/2" 3264 cu ft PF 'E'. 465 cu ft PF II 9 -5/8" 47# L -80 Surface 6992' Surface 6279' 12-1/4" 2119 cu ft Class 'G'. 133 cu fo PF 'C' 7" 26# L -80 6803' 9189' 6139' 8362' 8 -1/2" 527 cu ft Class 'G' 4-1/2" 12.6# L -80 9036' 9232' 8210' 8405' 6-1/8" 280 cu ft Class 'G' 3-1/2"x3-3/16" 8.81# 162# / L -80 9150' 10300' 8324' 9907' 4-1/8" 76 cu ft Class 'G' 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 2" Gun Diameter, 6 spf 4 -1/2 ", 12.6#, L -80 9040' 9011' / 8185' MD TVD MD TVD 10185' - 10280' 8935' - 8995' 26. ACID, FRACTURE, CEMENT' SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2200' Freeze Protected w/ 40 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 5, 2010 Flowing Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: 3/13/2010 12 Test Period ♦ 2,095 11,745' 44 95 5,607 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 400 300 24 - Hour Rate ♦ 4,189 23,489 88 31 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® 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 • '! ' I 171. F i PLETIOC None • - ' `A � ,®< 13/D FIEi Form 10-407 Revised 12/20R6DMS MAR 19 20 1 C TINUED ON REVERSE Q n Submit Original Only �•/1� f i. 4 /30 •/o o G 29. GEOLOGIC MARKERS (List all formations andkers encountered): 30. 0 FORMATION TESTS — NAME MD TVD Well Tested? ❑ Yes IS 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. Sadlerochit 9274' 8447' None Top CGL / Zone 3 9373' 8532' Base CGL / Zone 2C 9480' 8589' 23SB / Zone 2B 9568' 8626' 22TS 9672' 8668' 21 TS / Zone 2A 9781' 8712' Zone 1B 9908' 8766' 21 TS 10017' 8826' Zone 1B 10157' 8918' TDF / Zone 1A 10219' 8957' Formation at Total Depth (Name): TDF / Zone 1A 10219' 8957' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing 's true and correct to the best of my knowledge. 03) / Signed: Terrie Hubble 1ILt Title: Drilling Technologist Date: / � ! , ii PBU K - 07E 209 - 127 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling engineer: Cody Hinchman, 564 -4468 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- Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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 TVD 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 12/2009 Submit Original Only • • BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2010 11:00 - 11:00 24.00 MOB N WAIT PRE RIG WAS RELEASDED FROM 18 -30A AT 11:00. RIG WAS PUT ON STANDBY WITH CREWS DUE TO PHASE 2 WEATHER AND CONDITIONS ARE EXPECTED TO GO TO PHASE 3. WE WILL NOT BACK OFF THIS WELL UNTILL CONDITIONS ARE IMPROVING. 11:00 - 15:10 4.17 MOB N WAIT PRE WHILE WAITING ON WEATHER IN PHASE 2 CONDITIONS: SLB INSTALLED THE REEL STAND GAURDS. NORDIC IS INSTALLING NEW REEL HOUSE HARDLINE FILTER MANIFOLD. 15:10 - 18:00 2.83 MOB N WAIT PRE PHASE 3 HAS BEEN CALLED ALL NON ESSENTIAL WORK HAS BEEN STOPED. 18:00 - 18:45 0.75 MOB N PRE CALLED IMT & RECIEVED AUTHORIZATION TO CREW CHANGE WITH LOADER 18:45 - 00:00 5.25 MOB N PRE PHASE 3 CONDUCTED SAFETY MEETING WITH CREW & EXPLAINED PRECAUTIONS ASSOCIATED WITH PHASE 3 HELD TABLE TOP SAFETY MEETINGS FOR FIRE DRILL, CONFINED SPACE ENTRY, & MAN DOWN DRILL 2/3/2010 00:00 - 06:00 6.00 MOB N WAIT PRE PHASE 3 WAITING ON WEATHER WEATHER CLEARED UP @ 03:00 RECIEVED PERMISSION FROM IMT TO REMOVE SNOW BUILD UP ON PAD 06:00 - 06:15 0.25 MOB N WAIT PRE CREW CHANGE AND WALK AROUNDS 06:15 - 06:16 0.02 MOB N WAIT PRE 06:15 PHASE CONDITIONS HAVE BEEN LIFTED FROM PHASE 3 TO PHASE 2 LEVEL 3 ALL TRAVEL ON PADS AND ACCESS ROADS REQUIRES APPROVAL FROM THE "IMT ". 06:16 - 18:00 11.73 MOB N WAIT PRE START MAKING ROUNDS AND DIGGING OUT DIG OUT RIG & SAT CAMP LOAD REST OF LOOSE EQUIPMET ONTO TRAILORS MU HP FILTER SCREEN IN REELHOUSE WAIT FOR ROADS & PADS TO CLEAR K -PAD ACCESS ROAD FOR RIG MOVE 18:00 - 18:30 0.50 MOB N WAIT PRE CREW CHANGE OUT 18:30 - 21:20 2.83 MOB N WAIT PRE WAIT ON TRUCKS TO MOVE SATTELITE OFFICE TO K -PAD 21:20 - 22:30 1.17 MOB P PRE CH2MHILL ON LOCATION TO MOVE SATELITE OFFICE TO K -PAD WAIT ON CH2MHILL TO CONDUCT ROUTE DRIVE 22:30 - 00:00 1.50 MOB P PRE SATELITE CAMP OFF LOCATION & HEADED TO K -PAD WAIT ON SECURITY TO ESCORT OFFICE CAMP TO K -PAD SECURITY BACK ON SITE © 00:00 HOURS RELEASE RIG © MIDNITE 2/4/2010 00:00 - 00:25 0.42 MOB P PRE PJSM WITH RIG CREW & SECURITY FOR RIG MOVE 00:25 - 09:00 8.58 MOB P PRE MOVE RIG FROM DS -18 TO K -PAD 09:00 - 10:00 1.00 RIGU P PRE SPOT RIG OVER WELL ACCEPT RIG @ 10:00 10:00 - 12:30 2.50 BOPSUF P PRE NU BOPE 12:30 - 23:00 10.50 BOPSUF P PRE PT BOPE # 12 VALVE ON THE CHOKE MANIFOLD LEAKING OFF PSI NEW ANNULAR BAG UNABLE TO HOLD PSI BLIND RAMS FAILED PT VBR FAILED PT 23:00 - 00:00 1.00 BOPSUF N RREP PRE TROUBLE SHOOT & REPAIR LEAKING COMPONENTS ON Printed: 3/10/2010 1:47:38 PM IP) 1 1110 BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/4/2010 23:00 - 00:00 1.00 BOPSUF N RREP PRE BOPE 2/5/2010 00:00 - 06:00 6.00 BOPSUF N RREP PRE TROUBLE SHOOT & REPAIR LEAKING COMPONENTS OF BOPE 06:00 - 12:00 6.00 BOPSUF N RREP PRE CONTINUE TO TROUBLESHOOT FAILED BOPE TEST 12:00 - 13:00 1.00 BOPSUF N RREP PRE CALL AOGCC REPRESENTATIVE JEFF JONES TO WITNESS BOPE TEST 13:00 - 16:00 3.00 BOPSUF N RREP PRE BEGIN RE- TESTING BOPE 16:00 - 19:30 3.50 BOPSUF N RREP PRE TROUBLE SHHOT & REPAIR FAULTY COMPONENTS ON BOPE 19:30 - 20:30 1.00 BOPSUF N RREP PRE CALL AOGCC REPRESENTATIVE JEFF JONES TO n ,,,Q WITNESS BOPE TEST ,� 20:30 - 00:00 3.50 BOPSUF N RREP PRE PT FAILED BOPE COMPONENTS TEST HIGH & LOW LEVEL ALARMS IN PITS 2/6/2010 00:00 - 02:30 2.50 BOPSUF N RREP PRE PT FAILED BOPE COMPONENTS PT OF BOPE COMPLETE PJSM TO RIG FLOOR DOWN FROM BOPE TEST WHILE TESTING BOPE 02:30 - 03:05 0.58 BOPSUF P PRE RD FLOOR FROM BOPE TEST 03:05 - 03:20 0.25 RIGU P PRE PJSM TO OPEN SSV & INSTALL FUSABLE CAP 03:20 - 03:45 0.42 RIGU P PRE STAB COIL INTO INJECTOROPEN SSV & INSTALL FUSABLE CAP 03:45 - 04:00 0.25 RIGU P PRE PJSM TO PULL COIL ACROSS & STAB INTO INJECTOR 04:00 - 05:15 1.25 RIGU P PRE PULL COIL ACROSS & STAB INTO INJECTOR CUT OFF GRAPPLE & DRESS COIL END BOOT E -LINE STAB INJECTOR 05:15 - 05:40 0.42 RIGU P PRE CHECK CONNECTIONS ON HARDLINE IN REEL HOUSE FLUID PACK COIL WITH 5 BBLS MEOH, FOLLOWED BY 5 BBLS FRESH WATER 05:40 - 0.00 RIGU P PRE PT NEW HP FILTER SYSTEM TO 4,200 PSI FOUND SOME LEAKING CONNECTIONS BLED OFF PSI & TIGHTENED CONNECTIONS PT TO 4,200 PSI PRESSURE LEAKING OFF TROUBLE SHOOT PSI LOSS 06:40 - 06:50 0.17 RIGU P PRE PJSM FOR CHECKING INJECTOR CHAIN BLOCKS. 06:50 - 07:30 0.67 RIGU P PRE BEGIN INSPECTING INJECTOR GRIPPER BLOCKS AFTER FOLLOW UP FROM NORDIC 2 BLOCK FAILURE 07:30 - 08:00 0.50 RIGU P PRE TEST CTD PIT ALARMS AND ELECTRONIC PRESSURE GAUGES. PT ALL TREATING IRON AND CT 08:00 - 08:20 0.33 RIGU P PRE PJSM WITH RIG CREW FOR PUMPING SLACK AND INSTALLING COIL CONNECTOR 08:20 - 09:00 0.67 RIGU P PRE PUMP ELINE SLACK MANAGEMENT AND HEAR ELINE "ZING ". CUT 15' COIL TO FIND ELINE 09:00 - 10:30 1.50 RIGU P PRE MEG ELINE AND TROUBLESHOOT COMMUNICATION ISSUES 10:30 - 11:15 0.75 RIGU P PRE INSTALL COIL CONNECTOR AND PREP TO PUMP 3/4" BALL FOR DRIFT OF COIL 11:15 - 11:30 0.25 RIGU P PRE PJSM FOR LOTO AND DROPPING 3/4" BALL INSIDE REEL 11:30 - 12:45 1.25 RIGU P PRE PUMP AND RECOVER 3/4" BALL FOR SUCCESSFUL DRIFT OF COIL 12:45 - 17:15 4.50 RIGU P PRE INSTALL BAKER UQC AND TEST. TEST FAILED, BEGIN TO TROUBLE SHOOT. RE -HEAD BAKER CONNECTOR AND Printed: 3/10/2010 1:47:38 PM 4110 1110 BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/6/2010 12:45 - 17:15 4.50 RIGU P PRE SUCCESSFULLY TEST. 17:15 - 20:45 3.50 RIGU N RREP PRE PRESSURE TEST INNER REEL VALVE PSI LEAKING OFF FROM PRESSURE BULKHEAD TROUBLE SHOOT & REPAIR PRESSURE BULKHEAD OBTAINED GOOD PELIMINARY PT 20:45 - 22:00 1.25 RIGU N PRE CALLED JEFF WITH AOGCC WAIT ON STATE REP. 22:00 - 23:10 1.17 RIGU P PRE PT & CHART INNER REEL VALVE WITH JEFF JONES FROM AOGCC AS A WITNESS STAB ONTO WELL & TEST FLOW RATE ALARM 23:10 - 23:45 0.58 RIGU P PRE RD FLOOR FROM PRESSURE TEST 23:45 - 00:00 0.25 STWHIP P WEXIT PJSM TO PU & RIH WITH MILLING BHA 2/7/2010 00:00 - 01:10 1.17 STWHIP P WEXIT MU WINDOW MILLING BHA STAB INJECTOR 01:10 - 03:20 2.17 STWHIP P WEXIT TEST TOOLS @ SURFACE OPEN EDC RIH @ 2 BPM FRESH WATER & 90 FPM STACKED WT ON GLM @ 7,836' RIH TO 9,120' 03:20 - 04:00 0.67 STWHIP P WEXIT LOG TIE IN -9.5' CORRECTION, RESET DEPTH TO 9,179 04:00 - 04:15 0.25 STWHIP P WEXIT RIH TO TOWS TAG @ 9,233' 616( PU TO 9,218' & CLOSE EDC 1 FINISH DISPLACEMENT OF CRUDE WITH FRESH WATER FOLLOWED BY GEO -VIS 04:15 - 18:20 14.08 STWHIP P WEXIT RIH TO TOWS FS 2,300PSI @ 2.5 BPM START MILLING FROM 9,232.4' @ 1 FT /HR 04:20 - 9,232.4' - 100 PSI MTR WK 05:40 - 9,233.8' - 400 PSI MTR WK 06:35 - 9,234.6' - 400 PSI MTR WK ^ ., 07:00 - 9,234.8' - 500 PSI MTR WK /f3✓'' 09:00 - 9,236.4' - 340 PSI MTR WK rip - 9,237.3' - 230 PSI MTR WK 13:00 - 9,240.4' - 390 PSI MTR WK 15:00 - 9,241.6' - 400 PSI MTR WK. 1.2K WOB. BEGIN TO LOOK FOR FORMATION SAND IN RETURNS. NO 15:45 - 9,242.2' - 380 PSI MTR WK, 1K WOB. SHUBLIK LIMESTONE IN CUTTINGS. INCREASE ROP TO 2 -3 FPH. 16:50 - 9,244.8' - 400 PSI MTR WK, 1.2K WOB. 18:20 - 9,250' - MILLED 10' OF RATHOLE. BACK REAM THROUGH WINDOW 18:20 - 21:55 3.58 STWHIP P WEXIT MAKE 3 CLEANOUT RUNS THROUGH WINDOW TO INSURE IT'S CLEAN SHUT OFF PUMPS & RUN THROUGH WINDOW, SMOOTH PU TO 9,212' & OPEN EDC 21:55 - 23:45 1.83 STWHIP P WEXIT POH WITH MILLING BHA PJSM TO LD MILLING BHA WHILE POH 23:45 - 00:00 0.25 STWHIP P WEXIT LD MILLING BHA 2/8/2010 00:00 - 00:15 0.25 STWHIP P WEXIT LD MILLING BHA MILL & STRING REAMER IN GAUGE 00:15 - 00:30 0.25 STWHIP P WEXIT PJSM TO CHECK HP FILTER SCREENS IN REEL HOUSE Printed: 3/10/2010 1:47:38 PM • BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/8/2010 00:30 - 00:45 0.25 STWHIP P WEXIT CHECK HP FILTERS IN REEL HOUSE 00:45 - 00:55 0.17 DRILL P PROD1 PJSM TO MU BUILD BHA 00:55 - 01:15 0.33 DRILL P PROD1 MU BUILD BHA WITH 3.2 DEG BEND MTR 01:15 - 03:10 1.92 DRILL P PROD1 TEST TOOLS @ SURFACE OPEN EDC RIH WITH BUILD ASSY TO 9,150 03:10 - 03:45 0.58 DRILL P PROD1 LOG TIE IN @ 9,150' TO 9,210' -6' CORRECTION RESET DEPTH TO 9,204' OPEN EDC 03:45 - 04:20 0.58 DRILL P PROD1 RIH TO TD TAG TD @ 9,250' PU TO 9,247' BRING UP PUMPS 04:20 - 16:00 11.67 DRILL P PROD1 DRILL BUILD FROM 9,250' AS PER GEO & DD FS 2,460 @ 2.5 BPM 05:20 - 100 PSI MTR WK, 0.87K WOB, ECD 9.7 06:00 - 250 PSI MTR WK, 1K WOB, ECD 9.76 PVT = 325 BBLS 16:00 - 23:20 7.33 DRILL P PROD1 CONTINUE TO DRILL BUILD FROM 9382' PER GEO AND DD FS = 2440 PSI @ 2.5 BPM 300 PSI MOTOR WORK AND 1.5K WOB, ECD = 9.83 PVT = 333 BBLS 21:30 - 9,419', 300PSI MTR WK, 2.9K WOB, 9.85 ECD 22:30 - 9,420', 400 PSI MTR WK, 3.3K WOB, 9.85 ECD DRILL TO 9,421' 23:20 - 00:00 0.67 DRILL P PROD1 POH TO ABOVE WINDOW OPEN EDC POH 2/9/2010 00:00 - 01:25 1.42 DRILL P PROD1 POH FOR LATERAL BHA PJSM TO LD BUILD BHA & MU LATERAL BHA WHILE POH 01:25 - 01:50 0.42 DRILL P PROD1 LD BUILD BHA BIT GRADED @ 7- 2- RO- A- X- 3 -LT -TD 01:50 - 02:20 0.50 DRILL P PROD1 CHANGE PACK -OFFS ON INJECTOR CHECK HP FILTER RU TOOLS FOR LATERAL 02:20 - 02:55 0.58 DRILL P PROD1 MU LATERAL BHA WITH 1.2 DEG MTR & HYC T -REX BIT 02:55 - 04:45 1.83 DRILL P PROD1 TEST TOOLS @ SURFACE OPEN EDC RIH TO 9,180' 04:45 - 05:15 0.50 DRILL P PROD1 LOG TIE IN FROM 9,180' TO 9,222' -5' CORRECTION RE -SET DEPTH TO 9,217' 05:15 - 05:25 0.17 DRILL P PROD1 RIH TO TD TAG @ 9,422' 05:25 - 06:00 0.58 DRILL P PROD1 MAD PASS FROM 9,422 TO 9,250' 06:00 - 11:20 5.33 DRILL P PROD1 DRILL AHEAD FROM 9421' FREE SPIN = 2510 PSI 2.33 IN/2.4 OUT PVT = 323 BBLS ROP 20 FPH WOB = 2.9K 11:20 - 12:00 0.67 DRILL P PROD1 WIPER TRIP TO WINDOW 12:00 - 15:30 3.50 DRILL P PROD1 DRILL AHEAD FROM 9550' FREE SPIN 2550 PSI Printed: 3/10/2010 1:47:38 PM BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2010 12:00 - 15:30 3.50 DRILL P PROD1 2.44/2.39 AND 8.65 PPG PVT = 314 BBLS ROP = 40 -90FPH WOB = 2.3K ECD = 9.95 15:30 - 18:30 3.00 DRILL P PROD1 WORK TO FREE WHAT APPEARED TO BE A PLUGGED NOZZLE. PUMPED 30 BBLS OF NEWER MUD. DRILLING AHEAD AT 9616' FREE SPIN 2730 PSI 2.59/2.47 AND 8.65 PPG PVT = 311 ROP = 20 - 50 FPH WOB = 1K ECD = 9.84 18:30 - 19:10 0.67 DRILL P PROD1 CONTINUE DRILLIING FROM 9670 FT. CONTINUE IS 30 -60 FT /HR WITH 1 -2 KLBS DWOB. DRILL TO 9700 FT. 19:10 - 19:30 0.33 DRILL P PROD1 WIPER TRIP FROM 9700 FT TO WINDOW. UP WT IS 41K OFF BOTTOM. 19:30 - 23:00 3.50 DRILL P PROD1 DRILL FROM 9700 FT. CONTINUE HOLDING 65 DEG INC, ANTICIPATE FAULT CROSSING SOON. 2.60 / 2.50 BPM @ 2700 -3000 PSI. ROP IS 20 -40 FT /HR WITH 1 -2 K DWOB. AFTER 9770 FT ROP SLOWS TO 10 -20 FT /HR. PVT = 306 BBLS. AT 9774 FT ROP SLOWS FURTHER TO <10 FT /HR, STACK 5K WITH LITTLE MOTOR WORK. 23:00 - 00:00 1.00 DRILL P PROD1 POOH TO CHECK BIT AND MOTOR. 2/10/2010 00:00 - 00:45 0.75 DRILL P PROD1 CONTINUE POOH WITH BHA #3. 00:45 - 01:00 0.25 DRILL P PROD1 SAFETY MEETING. PJSM FOR UD BHA. 01:00 - 02:20 1.33 DRILL P PROD1 TAG STRIPPER AND UD BHA. BIT IS 3 -2 WITH 1 PLUGGED JET. PICK UP BHA #4 - USED TREX WITH NEW 1.2 DEG XTREME, 3" COILTRAK WITH RES. BHA OAL = 78.94 FT. 02:20 - 04:30 2.17 DRILL P PROD1 TEST TOOL AT SURFACE AND RIH. LOG GR FROM 9190 FT TO TIE -IN DEPTH. CONTINUE RIH TO BOTTOM. 04:30 - 06:30 2.00 DRILL P PROD1 DRILL FROM 9774 FT. ROP IS 10 -45 FT /HR WITH 3 KLBS DWOB. PVT = 298 BBLS. 06:30 - 07:45 1.25 DRILL P PROD1 DRILL AHEAD FROM 9832. FS = 2725 PSI. ROP = 30 - 50 FPH WITH 2 -3K WOB 2.64/2.49 8.68 IN/8.77 OUT PPG PVT = 296 07:45 - 08:30 0.75 DRILL P PROD1 WIPER TRIP TO WINDOW 08:30 - 13:00 4.50 DRILL P PROD1 DRILL AHEAD FROM 9900' FS = 2680 PSI ROP = 20 - 30 FPH WITH 4K WOB 2.57/2.49 8.7 IN/8.8 OUT PPG PVT = 284 13:00 - 13:45 0.75 DRILL P PROD1 WIPER TRIP TO WINDOW AND SWAP TO NEW MUD SYSTEM 13:45 - 18:00 4.25 DRILL P PROD1 DRILL AHEAD FROM 10050'. FS = 2680 PSI. ROP = 24 FPH WITH 4.4K WOB 2.57/2.44 8.51 IN/8.82 OUT PPG PVT = MUD SWAP. DRILL TO 10130 FT. 18:00 - 19:30 1.50 DRILL P PROD1 CONTINUE DRILLING FROM 10130 FT. VARIABLE ROP 10 -40 FT /HR. DRILL TO 10156 FT, PROGRESS <10 FT /HR, PICKUP IS Printed: 3/10 /2010 1:47:38 PM 4110 BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/10/2010 18:00 - 19:30 1.50 DRILL P PROD1 CLEAN. 19:30 - 21:00 1.50 DRILL P PROD1 DRILL TO 10160 FT, NOT MUCH MOTOR WORK OR PROGRESS WITH HIGH DWOB. 21:00 - 23:00 2.00 DRILL P PROD1 POOH FOR BIT CHANGE. PULL THROUGH WINDOW AND OPEN EDC. PUMP 2.9 BPM @ 2400 PSI WHILE POOH. 23:00 - 23:15 0.25 DRILL P PROD1 SAFETY MEETING. PJSM FOR CHANGE OUT BIT. OVERHEAD LOADS AND EQUIPMENT CHECKS WERE DISCUSSED. 23:15 - 00:00 0.75 DRILL P PROD1 TAG STRIPPER AND STAND BACK INJECTOR. L/D BIT, 4 -3 WITH ONE PLUGGED JET AND SHALE PACKED IN WATER COURSES. 2/11/2010 00:00 - 01:00 1.00 DRILL P PROD1 CONTINUE M/U BHA #5 - NEW HCC 4 BLADE BI- CENTER, SAME 1.2 XTREME, 3" COILTRAK WITH RES. BHA OAL = 78.94 FT. 01:00 - 02:10 1.17 DRILL P PROD1 SURFACE TEST TOOL AND RIH. LOG GR DOWN FROM 9190 FT, CORRECT -7 FT. 02:10 - 02:30 0.33 DRILL P PROD1 PASS THROUGH WINDOW AND RIH TO BOTTOM. 02:30 - 06:30 4.00 DRILL P PROD1 DRILL FROM 10160 FT. CONTINUE HOLDING 65 DEG INC TO TD AND KEEP TURNING LEFT (WEST). INITIAL ROP IS 30 FT /HR WITH 2 -3K DWOB. STALLS EASILY. PVT = 292 BBLS. 2.63 / 2.50 BPM @ 2700 PSI FS. AFTER 10185 FT ROP INCREASES TO 80 FT /HR. 06:30 - 07:45 1.25 DRILL P PROD1 WIPER TRIP TO WINDOW 07:45 - 13:45 6.00 DRILL P PROD1 DRILL AHEAD FROM 10300'. 2.59 IN/2.36 OUT. 8.6 IN/8.67 PPG OUT. PVT = 280 BBLS APPEAR TO HAVE DRILLED INTO A FAULT. TD MAY BE EXTENDED TO - 10500' PICK -UPS STICKY WITH SLOWER ROP 20 - 30 FPH. 13:45 - 16:40 2.92 DRILL P PROD1 APPEAR TO HAVE FAULTED INTO THE KAVIK. POOH AND DISCUSS SIDETRACK OPTIONS 16:40 - 19:00 2.33 DRILL C PROD1 DISCUSS SIDETRACK OPTIONS. RIG AND TOWN TEAM AGREE ON SETTING BILLET AT 10,000 FT WITH HIGH SIDE KICKOFF, THEN ROLLING BHA OVER AND DROPPING ANGLE TO ACHIEVE THE TARGET TVD. 19:00 - 19:15 0.25 STKOH C PROD1 SAFETY MEETING. PJSM TO DISCUSS HAZARDS AND MITIGATIONS FOR P/U BILLET BHA. 19:15 - 20:30 1.25 STKOH C PROD1 P/U BHA #6 - OH BILLET, 3" COILTRAK. BHA OAL = 74.77 FT. 20:30 - 22:45 2.25 STKOH C PROD1 RIH BHA #6. SET PUMP TRIP TO 1800 PSI AND PUMP MIN RATE THROUGH OPEN EDC. LOG GR DOWN FROM 9190 FT TO TIE -IN DEPTH. CORRECT -8.5 FT. CONTINUE RIH TO BILLET SETTING DEPTH. 22:45 - 00:00 1.25 STKOH X DPRB PROD1 STACKING WT AT 9630 FT, 4 TIMES. TRY VARIOUS SPEEDS CAN'T PASS. 10 -12K OVERPULLS WHEN PICKING UP. LIMITED ON SLACKOFF WT AND PUMP RATE BY SETTING TOOL LIMITATIONS. POOH. 10K OVERPULL AT 9290 FT. PULL THROUGH WINDOW AND POOH. 2/12/2010 00:00 - 00:30 0.50 STKOH X DPRB PROD1 CONTINUE POOH WITH BILLET. Printed: 3/10/2010 1:47:38 PM BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/12/2010 00:30 - 00:45 0.25 STKOH X DPRB PROD1 SAFETY MEETING. PJSM FOR UD BILLET AND P/U MOTOR AND BIT. 00:45 - 02:00 1.25 STKOH X DPRB PROD1 TAG STRIPPER AND UD BILLET. P/U USED TREX AND 1.2 XTREME + 3" COILTRACK FOR CLEANOUT RUN. BHA OAL = 66.14 FT. 02:00 - 03:30 1.50 STKOH X DPRB PROD1 TEST TOOL AT SURFACE AND RIH. LOG GR FROM 9180 FT. CORRECT -9 FT. 03:30 - 05:40 2.17 STKOH X DPRB PROD1 CLEANOUT TO 10,100 FT AND BACK TO WINDOW, 2 TIMES. PUMP A HI -VIS SWEEP AROUND AT 10100 FT. 05:40 - 07:30 1.83 STKOH X DPRB PROD1 PULL THROUGH WINDOW AND OPEN EDC. PUMP 3 BPM ON THE WAY OUT. 07:30 - 08:20 0.83 STKOH X DPRB PROD1 LD CLEAN OUT BHA AND PU ALUMINUM BILLET 08:20 - 10:30 2.17 STKOH X DPRB PROD1 RIH WITH BHA #8. BTT ALUMINUM BILLET WITH COIL TRACK. WT CK AT 9100' = 42K 10:30 - 11:10 0.67 STKOH X DPRB PROD1 LOG TIE -IN FROM 9150' -7 FOOT CORRECTION 11:10 - 12:25 1.25 STKOH X DPRB PROD1 RIH TO BILLET SETTING DEPTH. TAG AT 9630' AND TRY TO WORK BILLET THROUGH. 10K OVERPULLS AND A HARD SET DOWN. DISCUSS OPTIONS WITH TOWN TEAM AN4 DECIDE TO SET BILLET HIGHER AT 9540' PARK COIL AT 9550' AND LINE UP TO PUMP DOWN COIL. 3800 PSI SAW SETTING TOOL STROKE AND ABLE TO SET DOWN 4K. POOH 14:00 - 14:30 0.50 STKOH X DPRB PROD1 OOH, LD SETTING TOOL AND CHECK FOR PROPER OPERATION. SETTING TOOL APPEARED TO HAVE FUNCTIONED PROPERLY. 14:30 - 15:00 0.50 BOPSUF P PROD1 WFFKI Y FUNCTION TEST OF ROPE. 15:00 - 17:00 2.00 STKOH X DPRB PROD1 RIH WITH BHA #9. BHI COIL TRAK BHA WITH 1.2 DEGREE MOTOR AND RE -BUILT HYC TREX 17:00 - 17:15 0.25 STKOH X DPRB PROD1 LOG TIE -IN FROM 9150'. -7 FOOT CORRECTION 17:15 - 17:30 0.25 STKOH X DPRB PROD1 RIH TO OH BILLET DEPTH. TAG BILLET AT 9541' AND SET 3K DOWN AT 9543'. PUH AND ESTABLISH FREE SPIN OF 2626 PSI @ 2.49 BPM. 17:30 - 18:15 0.75 STKOH X DPRB PROD1 BEGIN TO TIME DRILL OH SIDETRACK FROM 9541.0 AT 1 FPH. 2637 PSI MOTOR WORK. 2.49/2.32. 8.64/8.81 PPG PVT = 247 DHWOB = .49K 18:15 - 21:00 2.75 STKOH X DPRB PROD1 CONTINUE TIME DRILLING 1 FT /HR AT OL TF TO GET SIDETRACK STARTED. 18:15 - 9541.6 FT 0.1K DWOB 18:25 - STALL AT 9541.7 FT. PICK UP TO 9541.5 FT AND RE -START TIME DRILLING. SET PUMP TRIP 200 PSI OVER FS. 18:50 - 9541.9 FT OK DWOB. 19:05 - 9542.1 FT 0.25K DWOB TAKING WT EACH INCREMENT. AFTER 1 FT DRILLED, GO TO 2 FT /HR. 19:10 - STALL AT 9542.2 FT. GO BACK TO 1 FT /HR. 19:30 - 9542.40 FT OK DWOB 20:00 - 9543.00 FT OK DWOB GETTING VERY SLIGHT MOTOR WORK AND DWOB AT EACH INCREMENT, GO TO 2 FT /HR. 20:30 - 9543.8 FT OK DWOB Printed: 3/10/2010 1:47:38 PM • BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/12/2010 18:15 - 21:00 2.75 STKOH X DPRB PROD1 AT 9544.0 FT GO TO 3 FT /HR. AT 9544.5 FT GO TO 6 FT /HR, STILL SEE VERY SLIGHT MOTOR WORK EACH TIME, NOT MUCH DWOB. AT 9545.2 FT GO TO 10 - 15 FT /HR, TRY TO CONFIRM SIDETRACK. 21:00 - 22:00 1.00 STKOH X DFAL PROD1 APPEAR TO BE PUSHING BILLET RATHER THAN DRILLING NEW HOLE. SHUT OFF PUMP AND CONFIRM, BILLET IS UNSET AFTER 2 LIGHT STALLS. PUSH BILLET DOWN WITH NO PUMP. BRING PUMP BACK ONLINE AND PUSH ON IT. STACK OUT WT AT 9588 FT, WORK PAST. WORK IT TO 9617 FT BIT DEPTH AND STACK 8K DWOB ON IT TWICE, FIRMLY PLANTED. CIRC HI -VIS SWEEP AROUND. 22:00 - 23:45 1.75 STKOH X DFAL PROD1 POOH. PLAN IS TO SET ANOTHER BILLET RIGHT ON TOP OF THE FIRST TO KEEP IT FROM MOVING DOWN, USE A 1.5 DEG MOTOR INSTEAD OF A 1.2 DEG, AND A LESS AGRESSIVE BI- CENTER. 23:45 - 00:00 0.25 STKOH X DFAL PROD1 SAFETY MEETING. PJSM FOR UD MOTOR AND P/U BILLET. 2/13/2010 00:00 - 00:30 0.50 STKOH X DFAL PROD1 UD BIT AND MOTOR AND P/U BILLET. 00:30 - 02:40 2.17 STKOH X DFAL PROD1 OPEN EDC AND RIH. PUMP 0.2 BPM @ 900 PSI WHILE �.1I„eP RIH. TIE IN DEPTH FROM 9195 FT. CORRECT -8 FT. A t Z 02:40 - 03:10 0.50 STKOH X DFAL PROD1 PASS THROUGH WINDOW, RIH TO SETTING DEPTH. SLIGHT DRAG ON THE WAY DOWN. TAG AT 9618 FT, 2 TIMES, AND GET STRING WT BACK. CLOSE EDC AND PRESSURE UP TO SHEAR OFF, SHEARS AT 4500 PSI. DWOB AT 6.5K WHEN SET, FALLS OFF TO 2.6K. SLACK DOWN SLOWLY TO 4.8K DWOB TO CONFIRM SET, HOLDING WT. 03:10 - 04:30 1.33 STKOH X DFAL PROD1 POOH. 04:30 - 04:45 0.25 STKOH X DFAL PROD1 SAFETY MEETING. PJSM FOR UD RUNNING TOOLS. 04:45 - 05:30 0.75 STKOH X DFAL PROD1 TAG STRIPPER AND UD BILLET SETTING TOOL. TOOL HAS FUNCTIONED NORMALLY. OFFLOAD BTT TOOLS. 05:30 - 08:00 2.50 STKOH P PROD1 LIFT UP INJECTOR, REMOVE BHI CABLE HEAD. REMOVE CT CONNECTOR. BOOT END OF CABLE. BEGIN PUMPING REVERSE SLACK INTO COIL CUT 50' OF COIL TO FIND E -LINE. 2.7% SLACK ELINE IN COIL. 08:00 - 11:00 3.00 STKOH N SFAL PROD1 TROUBLE SHOOT ELINE ISSUES. UNABLE TO MEG ELINE. OPEN JUNCTION BOX IN REEL HOUSE AND NOTED FLUID IN BOX. CONTINUE TO TROUBLESHOOT. FOUND TERMINAL BLOCK IN JUNCTION BOX WAS BAD. REPLACED AND HAD A GOOD TEST. 11:00 - 14:00 3.00 STKOH P PROD1 MAKE UP COIL CONNECTOR AND BHI BHA. 14:00 - 15:30 1.50 STKOH X DFAL PROD1 RIH WITH BHA #11. COIL TRAK BHA WITH 1.5 DEGREE MOTOR WITH 4 BLADED HUGHES BIT. 15:30 - 16:00 0.50 STKOH X DFAL PROD1 TIE IN AT 9180'. CORRECT -7' 16:00 - 16:15 0.25 STKOH X DFAL PROD1 RIH TO TIME DRILL OH SIDETRACK Printed: 3/10/2010 1:47:38 PM • BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/13/2010 16:15 - 18:15 2.00 STKOH X DFAL PROD1 TAG 2K DOWN AT 9606'. PUW = 45.5K ESTABLISH FREE SPIN AT 2.6 BPM OF 2670 PSI. BEGIN TIME DRILLING OH WINDOW AT 9604' 2.57 IN/2.41 OUT. 8.64 IN/8.76 OUT PVT = 234 18:15 - 22:30 4.25 STKOH X DFAL PROD1 CONTINUE TIME DRILLING 1 FT /HR AT OL TF. PUMP TRIP SET AT 300 PSI OVER FS. 18:15 - 9605.90 FT -0.13K DWOB STALL AT 9606.1 FT. ALLOW PRESSURE TO BLEED OFF BEFORE PICKING UP. BHA NOT SLIDING SMOOTHLY, CALL FOR NEW MUD SYSTEM. RE -START AT 9605.3 FT AT 1 FT /HR. 18:50 - 9605.50 FT 0.77K DWOB 19:20 - 9605.70 FT 1.21 K DWOB 20:00 - 9606.10 FT 0.85K DWOB 20:10 - 200 PSI MOTOR WORK, PUMP TRIPS AT 9606.3 FT. 20:55 - 9606.60 FT 0.89K DWOB 21:30 - 9606.90 FT 0.58K DWOB DWOB DRILLING OFF MORE QUICKLY WITH EACH STEP NOW, GO TO CONTROL DRILLING, 5 -10 FT /HR. START MUD SWAP. 22:00 - 9607.70 FT 0.68K DWOB 22:30 - 9609.87 FT 0.58K DWOB 11 FT /HR 22:30 - 00:00 1.50 DRILL C PROD1 DRILL FROM 9610 FT. DRILL 10 FT AT OL THEN START ROLLING TF OVER TO THE RIGHT IN 30 DEG INCREMENTS. INITIAL ROP 1S 20 -30 FT /HR. AFTER 9640 FT HOLD 90R TO GAIN SEPARATION FROM THE OLD WELLBORE. DRILL TO 9650 FT. 2/14/2010 00:00 - 02:20 2.33 DRILL C PROD1 CONTINUE DRILLING FROM 9650 FT. HOLD 90R TF FOR NOW TO CONTINIJF RH Tl IRN 2.54 / 2.45 BPM @ 2600 -3040 PSI. PVT = 334 BBLS. ROP IS 40 -60 FT /HR WITH 1 -2 KLBS DWOB. DRILL TO 9750 FT. 02:20 - 03:00 0.67 DRILL C PROD1 WIPER TRIP FROM 9750 FT TO WINDOW. PULL THROUGH WINDOW AND SHUT OFF CTU POWER PACK BRIEFLY TO GET THE AUTO DRILLER WORKING AGAIN. REDUCE PUMP GOING PAST BILLET. 03:00 - 05:30 2.50 DRILL C PROD1 DRILL FROM 9750 FT. SLOWLY REDUCE ANGLE TO 65 DEG. 2.56 / 2.50 BPM @ 2700 -3150 PSI. PVT = 320 BBLS. ROP IS FOLLOWING WHAT WAS SEEN IN THE OTHER LEG. DRILL TO 9900 FT. 05:30 - 06:30 1.00 DRILL C PROD1 WIPER TRIP FROM 9900 FT TO WINDOW. REDUCE PUMP GOING PAST BILLET. CLEAN PASS UP AND DOWN. 06:30 - 08:50 2.33 DRILL C PROD1 DRILL FROM 9900 FT. 2.64 IN/2.54 OUT. 8.65 PPG IN/8.75 PPG OUT. WOB = 2.7K PVT = 311 ROP - 90 FPH. ECD = 10.21. 08:50 - 09:15 0.42 DRILL C PROD1 WIPER TRIP TO WINDOW AND TIE IN LOG. 09:25 - 09:50 0.42 DRILL C PROD1 LOG TIE IN PASS. +2 FEET CORRECTION Printed: 3/10 /2010 1:47:38 PM • BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2010 09:50 - 10:20 0.50 DRILL C PROD1 WIPER TRIP TO BOTTOM 10:20 - 12:40 2.33 DRILL C PROD1 DRILL AHEAD FROM 10050' 2.69 IN/2.62 OUT. PVT = 304 BBLS DHWOB = 2.7K 12:40 - 13:50 1.17 DRILL C PROD1 WIPER TRIP TO WINDOW 13:50 - 14:30 0.67 DRILL C PROD1 DRILL FROM 10200'. 2900 PSI FREE SPIN 2.56 IN/2.46 OUT. 8.70 PPG IN /8.80 PPG OUT PVT = 297 BBLS ,-(Q 14:30 - 16:15 1.75 DRILL C PROD1 WIPER TO 10000' AND DRILL AHEAD FROM 10250' 16:15 - 17:15 1.00 DRILL C PROD1 TD CALLED. WIPER TO WINDOW FROM 10300' AND TIE IN PASS 17:15 - 17:40 0.42 DRILL C PROD1 LOG TIE IN FROM 9190' CORRECTED +2' 17:40 - 18:15 0.58 DRILL C PROD1 _RIH TO CONFIRM TD AND LAY IN LINER RUNNING PILL 18:15 - 19 :00 0.75 DRILL C PROD1 POH LAYING IN LINER RUNNING PILL AT 1 BPM. 19:00 - 20:15 1.25 DRILL P PROD1 PULL THROUGH WINDOW AND OPEN EDC. EOP FLAGS AT 9000 FT AND 7900 FT. 20:15 - 20:30 0.25 DRILL P PROD1 SAFETY MEETING. PJSM FOR UD BHA AND PUMPING SLACK FORWARD. 20:30 - 21:00 0.50 DRILL P PROD1 TAG STRIPPER AND UD FINAL DRILLING BHA. BIT IS 6 -4, 2 NOZZLES PLUGGED WITH ALUMINUM SHAVINGS, NOSE IS STARTING TO RING OUT. REMOVE BHI CABLE HEAD. 21:00 - 22:30 1.50 CASE P RUNPRD INSTALL CABLE BOOT. FILL WELL WITH 1 BBLS. PUT 1 JT PH6 IN THE WELL AND M/U CT RISER. PUMP FORWARD 4 BPM TO PUMP OUT CABLE. CABLE ZINGS BRIEFLY THEN QUITS. CYCLE PUMP SEVERAL TIMES. POP OFF WELL AND TUG ON CABLE, NOT MUCH HAS BEEN PUMPED OUT (SHOULD BE 300+ FT). GET BACK ON WELL AND PUMP 40 BBLS FRESH WATER, 4 BPM. 22:30 - 23:00 0.50 CASE P RUNPRD POP OFF WELL. CUT OFF 75 FT OF CABLE. FIND A KINK IN THE CABLE ABOUT 35 FT DOWN, WHICH LIKELY PREVENTED ANY FURTHER CABLE FROM BEING PUMPED OUT ONCE THE KINK EXITED THE PH6. RE -BOOT CABLE. ADD A SECOND JT OF PH6 TO THE ONE IN THE WELL. 23:00 - 00:00 1.00 CASE P RUNPRD M/U CT RISER, PUMP 10 BBLS WATER FORWARD CHASE IT WITH MUD 4 BPM. CABLE IS HEARD ZINGING FOR AWHILE. POP OFF WELL, REMOVE CABLE FROM WELL, CUT ANOTHER 295 FT OFF. TOTAL OF 370 FT OF CABLE PUMPED OUT. 2/15/2010 00:00 - 01:40 1.67 CASE P RUNPRD REMOVE SLB CT CONNECTOR AND DRESS THE END OF THE CT. INSTALL BTT CT CONNECTOR. PULL TEST TO 35K, PT TO 3500 PSI, GOOD. SET INJECTOR DOWN ON LEGS, PREP RIG FLOOR FOR RUNNING LINER. 01:40 - 02:00 0.33 CASE P RUNPRD SAFETY MEETING. PJSM FOR M/U LINER. 02:00 - 06:25 4.42 CASE P RUNPRD M/U LINER AS PER PROGRAM. GUIDE SHOE, 2 FLOATS, PUP JT, LANDING COLLAR, Printed: 3/10/2010 1:47:38 PM • • • BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/15/2010 02:00 - 06:25 4.42 CASE P RUNPRD STAGE COLLAR, 33 JTS 3.19" LINER WITH TURBOS, 1 JT 3.5" LINER, X NIPPLE, DEPLOYMENT SLEEVE, SELRT GEN 2, 3/4 DISCO, 4 JTS PH6, LOCKABLE SWIVEL. BHA OAL = 1283.23 FT. 06:25 - 06:40 0.25 CASE P RUNPRD PT HIGH PRESSURE FILTERS IN REEL HOUSE 06:40 - 13:00 6.33 CASE P RUNPRD RIH WITH LINER ASSEMBLY., SAW BOTH FLAGS - -10' OFF INDICATED DEPTH. RIH WITH -OUT SET DOWNS. TAG WITH 3K DOWN AT 10311.4. PUH FOR WT CK. 50K TO 57K UP WEIGHT. DROP 5/8" STEEL BALL TO DISCONNECT FROM LINER. SAW BALL SEAT AT 38.7 BBLS. PRESSURE UP TO SHEAR LINER RELEASE. SAW PRESSURE DROP AT 4600 PSI...PUH TO 10303' AND SAW WEIGHT BREAK OVER AT 38.5K. LINE UP TO PUMP XS KCL. DISPLACE WELL BORE TO XS KCL AT 1.5 BPM AT 1900 PSI. WELL BORE DISPLACED TO XS KCL. 1.66 BPM @ 575 PSI. BEGIN TO BUILD BIOZAN PILL AND HOLD PJSM WITH CEMENT CREW BEFORE RIGGING UP 13:00 - 14:25 1.42 CASE P RUNPRD 100 BBLS OF 2 POUND PER BBL BIOZAN MIXED IN PITS. CEMENT CREW RIGGED UP. HOLD PJSM WITH CEMENT CREW AND RIG CREW. DISCUSS PUMP SCHEDULE, EXPECTATIONS FOR SAFETY AND MUSTER AREA. STARTED TO CONDUCT SAFETY MEETING AND REALIZED THAT NORDIC CREW HAD WEEKLY CHANGEOUT AT 14:00. POSTPONED PJSM UNTIL ONCOMING NORDIC CREW ARRIVED. 14:25 - 15:10 0.75 CASE P RUNPRD PRIME CEMENT PUMP AND BEGIN BATCHING 15.8 PPG CEMENT. PT CEMENT LINE TO 4600 PSI CEMENT AT WEIGHT AT 14:52 15:10 - 17:00 1.83 CASE P RUNPRD STAGE 1, 13.3 BBLS 15.8 PPG CLASS G CEMENT 10 BBLS AWAY = 2.0 BPM CO 1650 PSI 13.3 BBLS CEMENT AWAY, STOP PUMPING AND ISOLATE LINE FROM CEMENTERS. BLOW DOWN LINE TO CEMENTERS WITH COMPRESSED AIR. STAGE 2, 2# BIOZAN DISPLACEMENT COIL CAPACITY WITH LINER RUNNING ASSEMBLY = 67.2 BBLS 10 BBL, 2.0 BPM, 1985 PSI 20 BBL, 2.0 BPM, 1209 PSI 30 BBL, 2.0 BPM, 894 PSI 40 BBL, 2.0 BPM, 1183 PSI 43 BBL, DROP RATE TO 1.5 BPM, 50 BBL, 1.78 IN/1.68 OUT AT 787 PSI 54.1 BBL, CEMENT AT SHOE, ZERO RETURN MM 56.5 BBL DISPLACEMENT, STOP PUMP WITH 2 BBL CEMENT LEFT INSIDE COIL PU 13' TO OPEN DOGS ABOVE DEPLOYMENT SLEEVE SET DOWN 10' HIGHER ON DOGS WITH 10K DOWN ATTEMPT TO PRESSURE UP ON PEE WEE DART. UNABLE TO PRESSURE UP WITH 1 BBL. WOULD PRESSURE UP TO 700 PSI AND BLEED OFF TO Printed: 3/10/2010 1:47:38 PM 1 BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/15/2010 15:10 - 17:00 1.83 CASE P RUNPRD 180 PSI. PUMPED ADDITIONAL .2 BBL AND COIL HELD 200 PSI. PU TO BREAK OVER AT 10292'. NO DEFINITIVE PRESSURE BLEED OFF NOTED OPENED BAKER CHOKE AND SET BACK DOWN WITH 10K COMPRESSION. CLOSED CHOKE AND ATTEMPTED TO PRESSURE UP WITH .3 BBLS CALL TOWN TEAM AND AGREE TO PUMP ADDTIONAL 1 BBL AND THEN PUMP CALCULATED LINER DISPLACEMENT OF 8.5 BBLS(MINUS 2.5 ALREADY PUMPED). PUMPED ADDITIONAL .2 BBLS OVER AND STOPPED PUMPING. UNSTING FROM LINER AND PUMP 5 BBLS 2# BIOZAN AT LINER TOP 17:00 - 18:30 1.50 CASE P RUNPRD POOH PUMPING 1.1 BPM AND 100 FPM 18:30 - 18:45 0.25 CASE P RUNPRD SAFETY NMEETING. 18:45 - 20:15 1.50 CASE P RUNPRD L/D PH6 AND SELRT GEN 2 RUNNING TOOL. RECOVER 5/8" STEEL BALL. APEARS THE PEE WEE DART HAS RELEASED NORMALLY HOWEVER THE LWP HAS NOT RELEASED, STILL ATTACHED TO THE RUNNING TOOL. SELRT GOING BACK TO BTT SHOP FOR INSPECTION. 20:15 - 20:30 0.25 CASE P RUNPRD SAFETY MEETING. PJSM FOR P/U HYDRIL AND CLEANOUT BHA. 20:30 - 21:45 1.25 CASE P RUNPRD M/U CLEANOUT BHA. 2.74 MILL, 2 -1/8 MOTOR, 1/2" CIRC SUB, 5/8" DISCONNECT, 20 STANDS 1.25" CSH, 3/4" DISCONNECT, DBPV, 2 JTS PH6 TUBING. BHA OAL = 1319.25 FT. 21:45 - 23:40 1.92 CASE P RUNPRD RIH BHA #13. CHECK WITH SLB LAB, CEMENT STARTING TO BUILD COMPRESSIVE STRENGTH. 23:40 - 00:00 0.33 CASE P RUNPRD CONTINUE RIH, CEMENT AT 500 PSI COMPRESSIVE. 2/16/2010 00:00 - 00:15 0.25 CASE N CEMT RUNPRD PASS THROUGH LINER TOP, NOTHING SEEN. CONTINUE RIH 1.58 BPM @ 1400 PSI TAG AND STALL AT 9351 FT. PICK UP AND DRILL THROUGH IT. APPEAR TO BE WASHING THROUGH GREEN CEMENT. 00:15 - 01:10 0.92 CEMT N CEMT RUNPRD STALL AT 9404 FT. PULL 50 FT WIPER TRIP. CONTINUE PUSHING THROUGH SEMI -SOFT CEMENT, 250 -350 FT /HR. PULL SHORT WIPERS EVERY 50 FT. 01:10 - 01:40 0.50 CEMT N CEMT RUNPRD AFTER 9550 ROP SLOWS TO 80 FT /HR. START A 3# BIO SWEEP DOWN THE CT. DRILL CEMENT TO 9600 FT. 01:40 - 02:10 0.50 CEMT N CEMT RUNPRD WIPER TRIP FROM 9600 FT TO LINER TOP. 02:10 - 03:45 1.58 CEMT N CEMT RUNPRD DRILL HARD CEMENT FROM 9600 FT. ROP IS 100 -140 FT/HR. 1.59 BPM @ 1400 -1600 PSI. DRILL TO 9750 FT. 03:45 - 04:45 1.00 CEMT N CEMT RUNPRD WIPER TRIP FROM 9750 FT TO LINER TOP. UP WT IS 41 K. Printed: 3/10/2010 1:47:38 PM • BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2010 03:45 - 04:45 1.00 CEMT N CEMT RUNPRD PUMP ANOTHER BIOZAN SWEEP, 20 BBLS. 04:45 - 06:15 1.50 CEMT N CEMT RUNPRD DRILL CEMENT FROM 9750 FT. ROP IS 60 -100 FT /HR. 06:15 - 07:00 0.75 CEMT N CEMT RUNPRD WIPER TRIP TO TOP OF LINER FROM 9883. BEGIN BUILDING 3# BIOZAN SYSTEM FOR CLEAN OUT AND CALL FOR USED GEOVIS SYSTEM. 07:00 - 08:00 1.00 CEMT N CEMT RUNPRD DRILL CEMENT FROM 9890'. ROP IS 100 FT /HR. PUMP FREQUENT 20 BBL 3# BIOZAN PILLS WHILE WAITING ON GEOVIS SYSTEM. 08:00 - 11:20 3.33 CEMT N CEMT RUNPRD POOH TO PICK UP BI- DIRECTIONAL JAR AND WAIT FOR USED GEO -VIS SYSTEM 11:20 - 13:00 1.67 CEMT N CEMT RUNPRD LD BHA TO ADD BI- DIRECTIONAL JAR AND REMOVE BPV. 13:00 - 14:50 1.83 CEMT N CEMT RUNPRD M/U BHA #14 - 2.74 MILL, 2.12 MOTOR, 1/2" CIRC SUB, 5/8" DISCONNECT, UP JARS, 20 STDS 1.25 CSH, 3/4" DISCONNECT, 2 JTS PH6, SWIVEL. BHA OAL = 1324.18 FT. 14:50 - 16:30 1.67 CEMT N CEMT RUNPRD RIH BHA #14. 16:30 - 18:00 1.50 CEMT N CEMT RUNPRD TAG AT 9965 FT 44K UP 19K DOWN. MILL CEMENT 1.69 / 1.61 BPM @ 2400 - 2800 PSI. ROP IS 30 -50 FT /HR. DRILL TO 10000 FT._ 18:00 - 18:30 0.50 CEMT N CEMT RUNPRD WIPER TRIP FROM 10000 FT TO LINER TOP. 18:30 - 19:40 1.17 CEMT N CEMT RUNPRD DRILL CEMENT FROM 10000 FT TO 10050 FT. ROP IS 30 -50 FT /HR. 19:40 - 21:00 1.33 CEMT N CEMT RUNPRD WIPER TRIP FROM 10050 FT. PULL ABOVE LINER TOP AND CIRC 1 BOTTOMS UP. 21:00 - 22:30 1.50 CEMT N RREP RUNPRD CHANGE OUT RADIATOR ON DRILLERS SIDE GEN SET. RADIATOR WAS LEAKING. INSTALL NEW RADIATOR AND HOOK UP HOSES. 22:30 - 00:00 1.50 CEMT N CEMT RUNPRD BOTH GENERATORS BACK ONLINE, RIH TO DRILL. DRILL CEMENT FROM 10050 FT. ROP IS 40 -50 FT /HR. 2/17/2010 00:00 - 00:20 0.33 CEMT N CEMT RUNPRD DRILL CEMENT TO 10,100 FT. 00:20 - 01:40 1.33 CEMT N CEMT RUNPRD WIPER TRIP FROM 10,100 FT TO WINDOW. 01:40 - 03:30 1.83 CEMT N CEMT RUNPRD DRILL FROM 10,100 FT AT 30 -40 FT /HR. $TALL AT 10126 FT,,PULL A 100 FT WIPER. CONTINUE DRILLING FROM 10126 FT. ROP AROUND 20 -40 FT /HR. STALL AT 10134 FT. DRILL CEMENT TO 10150 FT. 03:30 - 05:00 1.50 CEMT N CEMT RUNPRD WIPER TRIP FROM 10150 FT TO LINER TOP. 05:00 - 06:00 1.00 CEMT N CEMT RUNPRD DRILL CEMENT FROM 10150 FT. ROP IS 30 -40 FT /HR. 8.76 / 8.86 PPG. STALL AT 10172 FT, 2 TIMES. PULL A SHORT WIPER. 06:00 - 06:15 0.25 CEMT N RUNPRD CREW CHANGE. DISCUSS OPERATIONS AND PLAN FORWARD. 06:15 - 06:30 0.25 CEMT N RUNPRD TAG AND STALL AT 10,177'. APPEARS TO BE +/- TOL. SOFT TAG LOOKS LIKE CUTTINGS BUILD UP. 06:30 - 08:00 1.50 CEMT N RUNPRD MAKE WIPER TO 8000'. 50 FPM. 2390 PSI AT 1.7 BPM IN/1.38 OUT. NOTED INCREASED CEMENT FINES WITH BTMS UP. 08:00 - 13:15 5.25 CEMT N RUNPRD MILL CEMENT FROM 10,181'. WIPER TRIP TO LINER TOP EVERY 50'. ROP AVERAGED 30 FPH. TAG XO AT 10,279' (UNCORRECTED) VERIFY WITH Printed: 3/10/2010 1:47:38 PM BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/17/2010 08:00 - 13:15 5.25 CEMT N RUNPRD SEVERAL STALLS. 13:15 - 16:00 2.75 CEMT N RUNPRD CIRCULATE OUT OF HOLE AT 80 %. 2690 PSI AT 1.74 BPM IN. 16:00 - 18:00 2.00 CEMT N RUNPRD TAG STRIPPER, SET INJECTOR ON LEGS STAND BACK 20 STDS OF 1.25 CSH. 18:00 - 18:15 0.25 EVAL P LOWER1 SHIFT CHANGE AND SAFETY MEETING WITH NIGHT TOUR. 18:15 - 19:10 0.92 EVAL P LOWER1 M/U BHA #15 FOR CLEANOUT TO LINER TOP. 2.125 NOZZLE, 1 STD 1.25 CSH, 3/4" DISCONNECT, DBPV, 2 JTS PH6. BHA OAL = 130.35 FT. 19:10 - 20:20 1.17 EVAL P LOWER1 RIH BHA #15. 20:20 - 20:50 0.50 EVAL P LOWER1 TAG DEPLOYMENT SLEEVE LIGHTLY, 9224 FT UNCORRECTED. GO TO 3 BPM, START WELL SWAP TO 2% KCL DOUBLE SLICK. 20:50 - 22:45 1.92 EVAL P LOWER1 POOH SWAP WELL TO 2% KCL DOUBLE SLICK ABOVE LINER TOP. 22:45 - 23:00 0.25 EVAL P LOWER1 SAFETY MEETING. PJSM FOR UD BHA AND JETTING STACK. 23:00 - 23:25 0.42 EVAL P LOWER1 UD BHA #15. P/U SWIZZLE STICK AND JET STACK. 23:25 - 00:00 0.58 EVAL P LOWER1 CLOSE SWAB AND JET STACK. 2/18/2010 00:00 - 00:20 0.33 EVAL P LOWER1 LINE UP VALVES FOR LINER LAP TEST. TEST LAP, FAILS. INJECTIVITY RATE OF 0.7 BPM @ 750 PSI. 00:20 - 00:40 0.33 EVAL P LOWER1 PREP RIG Fl OOR TO RUN MCNUGR/CCL RUN. 00:40 - 01:00 0.33 EVAL P LOWER1 SAFETY MEETING. PJSM FOR HANDLING MCNL TOOLS 01:00 - 02:30 1.50 EVAL P LOWER1 M/U BHA #16. MCNUGR/CCL WITH CARRIER, 1/2" CIRC SUB, 5/8" DISCONNECT, 20 STANDS 1.25" CSH, 3/4" DISCONNECT, DBPV, 2 JTS PH6, LOCKABLE SWIVEL. BHA OAL = 1332.8 FT. 02:30 - 02:50 0.33 EVAL P LOWER1 INSTALL COUNTER ON INJECTOR FOR MCNL TOOLS. 02:50 - 04:15 1.42 EVAL P LOWER1 RIH BHA #16. 04:15 - 05:40 1.42 EVAL P LOWER1 LOG DOWN AT 30 FT /MIN FROM 8800 FT. PUMP 2 BPM WHILE LOGGING DOWN. JAGS AT 10287 FT. UNCORRECTED. CIRC PERF PILL TO NOZZLE. 05:40 - 08:00 2.33 EVAL P LOWER1 TAG PBTD LIGHTLY AND LOG UP AT 60 FT /MIN. LAY IN PERF PILL. 08:00 - 10:00 2.00 EVAL P LOWER1 PULL OUT OF HOLE. HOLD PJSM. 10:00 - 11:00 1.00 EVAL P LOWER1 AT SURFACE. GET OFF WELL. UNSTAB COIL. STAND BACK CSH. LD MCNL TOOLS. PROCESS LOG DAT. PBTD IS 10,282' CORRECTED. LINER TOP IS 9155' CORRECTED. 11:00 - 11:15 0.25 PERFOB P LOWER1 HOLD PJSM TO DISCUSS HANDLING PERF GUNS AND BHA. 11:15 - 13:15 2.00 PERFOB P LOWER1 MU PERF BHA W/ 2 JTS PH6 AND 40 JTS CSH. 7 - 2.0" GUNS. OAL: 1435.26' 13:15 - 15:30 2.25 PERFOB P LOWER1 GET ON WELL. RUN IN HOLE. TAG BTM AT 10,309'. CORRECT TO 10,282'. Printed: 3/10/2010 1:47:38 PM • BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2010 15:30 - 16:15 0.75 PERFOB P LOWER1 CIRCULATE COIL AS PER SLB SCHEDULE TO ACTIVATE GUNS. GOOD INDICATION OF GUNS FIRING. PERF 10,185' TO 10,280' WITH 6 SPF 2.0" 2006PJ GUNS. 16:15 - 17:45 1.50 PERFOB P LOWER1 PULL OUT OF HOLE. CIRC DOWN COIL TO FILL HOLE. 880 PSI AT 1.25 BPM IN. MONITOR HOLE FILL. 17:45 - 18:15 0.50 PERFOB P LOWER1 AT SURFACE. MONITOR WELL FOR FLOW. 18:15 - 20:00 1.75 PERFOB P LOWER1 STAND BACK CSH AND UD SPENT GUNS. ALL GUNS FIRED. 20:00 - 20:30 0.50 CASE P RUNPRD OFFLOAD PERF GUNS AND LOAD LTP RUNNING TOOLS ONTO RIG. 20:30 - 21:30 1.00 CASE P RUNPRD M/U BHA #18. SEALS, LOCATOR, PUP JT, 45KB LINER TOP PACKER, 4" GH RUNNING TOOL, 3/4" DISCONNECT, 2 JTS PH6, SWIVEL. BHA OAL = 95.37 FT. 21:30 - 23:50 2.33 CASE P RUNPRD RIH BHA #18. UP WT AT 9000 FT IS 38K. PUMP 0.5 BPM, STING INTO DEPLOYMENT SLEEVE AT 9166 FT, UNCORRECTED. OPEN BAKER CHOKE. 23:50 - 00:00 0.17 CASE P RUNPRD RIH TO 9171 FT TO NO -GO WITH THE LOCATOR. 11K STRING WT. P/U 2 FT PAST BREAKOVER WT TO 9165 FT. P/U TO A BALL DROP POSITION. 2/19/2010 00:00 - 00:40 0.67 CASE P RUNPRD LAUNCH 5/8" STEEL BALL. BALL IS HEARD ROLLING. REDUCE PUMP RATE AT 70% COIL VOLUME. BALL ON SEAT AT 46.1 BBLS. OPEN BAKER CHOKE. 00:40 - 01:00 0.33 CASE P RUNPRD RIH STACK 10K AT THE SAME DEPTH AS BEFORE. PICK UP TO BREAKOVER WT AND SPACE OUT. BREAKOVER WT IS ABOUT 4K HEAVIER. REPEAT THIS 2 MORE TIMES TO CONFIRM. CLOSE BAKER CHOKE. PRESSURE UP CT TO 2400 PSI. SLACK BACK TO 10K DOWN WT. NOW 4 FT HIGHER THAN BEFORE, AS EXPECTED. BLEED OFF CT PRESSURE ON BAKER CHOKE. 01:00 - 01:20 0.33 CASE P RUNPRD LINE UP TO PT ANNULUS. PT TO 2000 PSI FOR 10 MIN. 0 MIN 1992 PSI 3 MIN 1974 8 MIN 1970 10 MIN 1970 PSI GOOD TEST. 01:20 - 02:30 1.17 CASE P RUNPRD CLOSE BAKER CHOKE. PRESSURE UP CT TO SHEAR OFF OF PACKER. SHEARS AT 3800 PSI. PICK UP OUT OF PACKER. UP WT IS 43K. LINER TOP IS NOW 9150'. POOH. 02:30 - 03:30 1.00 CASE P RUNPRD TAG STRIPPER AND UD LTP RUNNING TOOLS, HAS FUNCTIONED NORMALLY. RECOVER 5/8" STEEL BALL. OFFLOAD LTP RUNNING TOOLS AND REST OF BTT GEAR. M/U NOZZLE AND DBPV FOR FREEZE PROTECT. 03:30 - 04:00 0.50 WHSUR P POST RIH FOR FREEZE PROTECT. PJSM WITH LRS WHILE RIH. Printed: 3/10/2010 1:47:38 PM • • BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: K -07 Common Well Name: K -07 Spud Date: 1/1/1990 Event Name: REENTER +COMPLETE Start: 1/30/2010 End: 2/21/2010 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/19/2010 04:00 - 05:20 1.33 WHSUR P POST PT LRS LINE TO 3000 PSI THEN PUT 40 BBLS DIESEL IN CT. POOH LAY IN DIESEL. 05:20 - 05:50 0.50 WHSUR P POST TAG STRIPPER. L/D FREEZE PROTECT BHA. PUMP 3 BBLS MEOH BACKWARDS INTO REEL TO FREEZE PROTECT. 05:50 - 06:00 0.17 RIGD P POST RIG UP TO PURGE KILL AND CHOKE MANIFOLD WITH AIR. 06:00 - 06:15 0.25 RIGD P POST CREW CHANGE. DISCUSS OPERATIONS. MAKE RIG ROUNDS AND CHECKS. 06:15 - 09:00 2.75 RIGD P POST CONTINUE TO PREP RIG FOR MOVE. CLEAN PITS. CLEAN OUT CUTTINGS BOX. GREASE TREE. 09:00 - 11:30 2.50 BOPSUF P POST HOLD PJSM WITH VALVE CREW. DRY ROD BPV IN TO WELL HEAD. 11:30 - 13:30 2.00 BOPSUF P POST ND BOPS. 13:30 - 14:45 1.25 BOPSUF P POST NU TREE CAP FLANGE. FILL TREE WITH MEOH. TEST TREE CAP TO 4000 PSI. 14:45 - 18:00 3.25 DEMOB N WAIT POST WAIT ON WEATHER. WINDS BLOWING AT 30 TO 40 MPH. CELLAR DOORS CANNOT BE OPENED SAFELY. ROAD TO C PAD IS HEAVILY DRIFTED. TAKE ON EXTRA RIG WATER. FUEL LEVEL OK. WINDS PREDICTED TO DIMINISH IN AM. 18:00 - 00:00 6.00 DEMOB N POST CONTINUE WAIT ON WIND. WINDS 30 -40 MPH. PHASE 2 ANNOUNCED AT 20:30. NORDIC CREW REPLACES CHOKE VALVE #3. 2/20/2010 00:00 - 06:00 6.00 DEMOB N WAIT POST CONTINUE WAIT ON WIND TO OPEN CELLAR DOORS. PHASE 2 CONDITIONS. WEATHER PREDICTED TO WORSEN. 25 -40 MPH WINDS. BLOWING SNOW. CONVOY WITH LOADER TO MAN CAMP FOR CREW CHANGE. 06:00 - 06:15 0.25 DEMOB N WAIT POST CREW CHANGE. DISCUSS STANDBY OPS. MAKE RIG CHECKS AND ROUNDS. CONVOY BACK TO CAMP. 06:15 - 18:00 11.75 DEMOB N WAIT POST CONTINUE TO STAND BY FOR WEATHER. REVIEW AUDIT PUNCH LIST. CLEAN RIG. WORK ON AUDIT ITEMS. DO SOME ONLINE TRAINING. PHASE CONDITION REDUCED FROM 2 TO 1 AT 1230. WINDS STILL 25 MPH GUSTING TO 35 -40 MPH. 18:00 - 00:00 6.00 DEMOB N WAIT POST CONTINUE TO STAND BY FOR WIND. GO OUTSIDE AND CHECK CELLAR AREA PERIODICALLY TO DETERMINE IF DOORS CAN BE OPENED. HOUSEKEEPING AROUND RIG. FINISH INSTALLING NEW PULLBACK COLLAR AROUND BOP STACK, AND HOOK UP SHACKLES AND CHAIN HOISTS. NEEDLE GUN SPILL CONTAINMENT TUB, PREP IT FOR PAINTING. RELEASE RIG AT 00:00. ALL FURTHER DATA ON C -20C DIMS REPORT. Printed: 3/10/2010 1:47:38 PM • • 1141 BAKER HUGIS 1NTEQ North America - ALASKA - BP Prudhoe Bay PB K Pad K -07 K -07E Survey: MWD Survey Report - Geographic 16 February, 2010 4) p MAt • niAMIES Survey Report - Geographic bP 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well K - 07 Project: Prudhoe Bay TVD Reference: K -07C © 54.66ft (generic rig) Site: PB K Pad MD Reference: K -07C © 54.66ft (generic rig) Well: K - 07 North Reference: True Wellbore: K - 07E Survey Calculation Method: Minimum Curvature Design: K -07E Database: EDM .16 - Anc Prod - WH24P 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 1Site PB K Pad, TR -11 -14 Site Position: Northing: 5,973,161.33ft Latitude: 70° 19' 57.435 N From: Map Easting: 670,342.10ft Longitude: 148° 37' 5.245 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.30 ° Well K - 07 API No 500292104500 I Well Position +N / -S 0.00 ft Northing: 5,975,163.00 ft Latitude: 70° 20' 17.028 N +E / -W 0.00 ft Easting: 670,744.00 ft Longitude: 148° 36' 52.181 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore K -07E API No 500292104505 1 Magnetics . Model Name Sample Date Declination Dip Angle Field Strength (0) ( (nT) I BGGM2009 2/16/2010 22.35 80.97 57,688 Design K-07E Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,600.36 Vertical Section: Depth From (TVD) +N/-S +E / -W Direction ` (ft) (ft) (ft) ( 28.45 0.00 0.00 12.39 Survey Program Date: 2/16/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description 91.45 6,989.24 1 : Sperry-Sun BOSS gyro multi (K -07) BOSS -GYRO Sperry-Sun BOSS gyro multishot 6,989.78 9,224.23 3 : MWD - Standard (K -07C) MWD MWD - Standard 9,230.00 9,600.36 MWD (K- 07EPB1) MWD MWD - Standard 9,607.00 10,301.00 MWD (K -07E) MWD MWD - Standard 2/16/2010 9:33:52AM Page 2 COMPASS 2003.16 Build 71 ' • • Survey Report - Geographic bP INTEQ Company: North America - ALASKA - BP Local Co ordinate Reference: Well K - 07 Project: Prudhoe Bay TVD Reference: K -07C © 54.66ft (generic rig) Site: PB K Pad MD Reference: K -07C © 54.66ft (generic rig) Well: K North Reference: True Welibore: K - 07E Survey Calculation Method: Minimum Curvature Design: K -07E Database: EDM .16 - Anc Prod - WH24P 1 Survey I Measured Vertical Map Map Depth Inclination Azimuth Depth +N! -S +E/.W Northing Easting (ft) ( (°) (ft) (ft) (ft) (ft) (ft) Latitude . Longitude 9,600.36 65.60 340.15 8,639.58 2,821.50 897.43 5,978,004.02 671,576.89 70° 20' 44.776 N 148° 36' 25.960 W TIP 9,607.00 65.58 339.57 8,642.33 2,827.18 895.35 5,978,009.64 671,574.68 70° 20' 44.832 N 148° 36' 26.021 W KOP 9,634.35 67.28 347.26 8,653.28 2,851.18 888.21 5,978,033.48 671,567.00 70° 20' 45.068 N 148° 36' 26.229 W 9,664.43 66.61 352.75 8,665.06 2,878.43 883.41 5,978,060.60 671,561.58 70° 20' 45.336 N 148° 36' 26.369 W 9,695.75 66.26 357.99 8,677.59 2,907.03 881.09 5,978,089.14 671,558.61 70° 20' 45.618 N 148° 36' 26.437 W 9,725.81 66.52 4.03 8,689.64 2,934.55 881.57 5,978,116.67 671,558.47 70° 20' 45.888 N 148° 36' 26.423 W 9,756.13 66.10 10.33 8,701.83 2,962.08 885.04 5,978,144.26 671,561.31 70° 20' 46.159 N 148° 36' 26.321 W 9,786.29 65.30 12.00 8,714.25 2,989.05 890.36 5,978,171.34 671,566.01 70° 20' 46.424 N 148° 36' 26.166 W 9,821.31 65.09 8.27 8,728.94 3,020.33 895.95 5,978,202.75 671,570.89 70° 20' 46.732 N 148° 36' 26.002 W 9,851.25 64.86 1.17 8,741.62 3,047.34 898.19 5,978,229.80 671,572.51 70° 20' 46.998 N 148° 36' 25.937 W 9,885.39 64.26 356.72 8,756.29 3,078.16 897.62 5,978,260.59 671,571.24 70° 20' 47.301 N 148° 36' 25.953 W 9,919.07 61.40 352.86 8,771.67 3,107.99 894.92 5,978,290.35 671,567.86 70° 20' 47.594 N 148° 36' 26.032 W 9,958.59 56.74 346.64 8,792.00 3,141.32 888.93 5,978,323.54 671,561.12 70° 20' 47.922 N 148° 36' 26.207 W 9,993.11 54.20 343.20 8,811.57 3,168.77 881.55 5,978,350.81 671,553.11 70° 20' 48.192 N 148° 36' 26.423 W 10,027.17 50.42 337.46 8,832.40 3,194.14 872.52 5,978,375.97 671,543.50 70° 20' 48.441 N 148° 36' 26.686 W 10,062.15 47.28 331.59 8,855.42 3,217.91 861.23 5,978,399.47 671,531.68 70° 20' 48.675 N 148° 36' 27.016 W 10,095.77 47.59 324.19 8,878.18 3,238.86 848.08 5,978,420.11 671,518.06 70° 20' 48.881 N 148° 36' 27.400 W 10,130.05 49.47 317.70 8,900.90 3,258.77 831.90 5,978,439.65 671,501.43 70° 20' 49.077 N 148° 36' 27.873 W 10,161.49 51.80 313.78 8,920.84 3,276.16 814.93 5,978,456.65 671,484.07 70° 20' 49.248 N 148° 36' 28.369 W 10,190.27 51.44 308.16 8,938.72 3,290.94 797.91 5,978,471.04 671,466.72 70° 20' 49.394 N 148° 36' 28.866 W 10,221.55 51.16 309.23 8,958.27 3,306.20 778.86 5,978,485.86 671,447.32 70° 20' 49.544 N 148° 36' 29.423 W 10,253.77 51.22 315.33 8,978.48 3,323.08 760.30 5,978,502.31 671,428.38 70° 20' 49.710 N 148° 36' 29.965 W 10,269.97 51.55 319.71 8,988.59 3,332.41 751.75 5,978,511.44 671,419.63 70° 20' 49.801 N 148° 36' 30.215 W 10,301.00 51.55 319.71 9,007.89 3,350.95 736.04 5,978,529.62 671,403.50 70° 20' 49.984 N 148° 36' 30.674 W TD Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 6,989.79 6,276.99 9 5/8" 9.625 12.250 9,186.79 8,360.39 7" 7.000 8.500 Survey Annotations Measured Vertical Local Coordinates Depth Depth +pi/.S +E/ -W (ft) ; (ft) (ft) (ft) Comment 9,600.36 8,639.58 2,821.50 897.43 TIP 9,607.00 8,642.33 2,827.18 895.35 KOP 10,301.00 9,007.89 3,350.95 736.04 TD Checked By: Approved By: Date: 2/16/2010 9:33:52AM Page 3 COMPASS 2003.16 Build 71 • • FA 'Ali II BAKER INTEQ North America - ALASKA - BP Prudhoe Bay PB K Pad K -07 K- 07EPB1 Survey: MWD Survey Report - Geographic 16 February, 2010` l� (� sue: TV Sy d �(� 3 0 by Mill • • litgliiis Survey Report - Geographic 0 bP INTEQ i Company: North America - ALASKA - BP Local Co- ordinate Reference: Well K - 07 Project Prudhoe Bay TVD Reference: K -07C © 54.66ft (generic rig) C� Site: PB K Pad MD Reference: K -07C 54.66ft (generic ri eneric 9) Well: K - 07 North Reference: True Welibore: K - 07EPB1 Survey Calculation Method: Minimum Curvature Design: K- 07EPB1 Database: EDM .16 Anc Prod WH24P 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 I Site PB K Pad, TR -11 -14 Site Position: Northing: 5,973,161.33ft Latitude: 70° 19' 57.435 N From: Map Easting: 670,342.10ft Longitude: 148° 37' 5.245 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.30 ° I Well K - 07 API No 500292104500 Well Position +NI-S 0.00 ft Northing: 5,975,163.00 ft Latitude: 70° 20' 17.028 N +E / -W 0.00 ft Easting: 670,744.00 ft Longitude: 148° 36' 52.181 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft 1 Welibore K- 07EPB1 API No 500292104572 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1 (1 ; C) (nT) BGGM2009 10/7/2009 22.53 80.96 57,678 9 Desi n K- 07EPB1 l 1 Audit Notes: j Version: 1.0 Phase: ACTUAL Tie On Depth: 9,224.23 1 Vert Section: Depth From (TVD) +NI-S +E/ -W Dire (ft) (ft) (ft) r) 28.45 0.00 0.00 9.56 Survey Program Date: 2/16 /2010 From To `. (ft) (ft) ' Survey (Welibore) Tool Name Description i S 91.45 6,989.24 1 : Sperry-Sun BOSS gyro multi (K -07) BOSS -GYRO Sperry-Sun BOSS gyro multishot 6,989.78 9,224.23 3 : MWD - Standard (K -07C) MWD MWD - Standard 9,230.00 10,440.00 MWD (K- 07EPB1) MWD MWD - Standard 2/16/2010 9 :26 :13AM Page 2 COMPASS 2003.16 Build 71 • MMus Survey Report - Geographic 0 bP 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well K - 07 Project: Prudhoe Bay TVD Reference: K - 07C @ 54.66ft (generic rig) Site: PB K Pad MD Reference: K -07C © 54.66ft (generic rig) Well: K -07 North Reference: True Wellbore: K- 07EPB1 Survey Calculation Method: Minimum Curvature Design: K- 07EPB1 Database: EDM .16 - Anc Prod WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +EI -VV Northing Easting (ft) ( °) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,224.23 6.20 11.12 8,397.61 2,576.20 964.24 5,977,760.32 671,649.27 70° 20' 42.364 N 148° 36' 24.009 W TIP 9,230.00 6.12 7.36 8,403.35 2,576.81 964.34 5,977,760.93 671,649.35 70° 20' 42.370 N 148° 36' 24.006 W KOP 9,249.58 7.03 359.58 8,422.80 2,579.05 964.46 5,977,763.16 671,649.43 70° 20' 42.392 N 148° 36' 24.002 W 9,280.70 17.25 353.88 8,453.18 2,585.56 963.96 5,977,769.66 671,648.77 70° 20' 42.456 N 148° 36' 24.017 W 9,318.14 29.45 351.39 8,487.49 2,600.23 961.98 5,977,784.29 671,646.46 70° 20' 42.600 N 148° 36' 24.075 W 9,340.74 33.85 350.47 8,506.73 2,611.94 960.10 5,977,795.95 671,644.32 70° 20' 42.715 N 148° 36' 24.129 W 9,381.18 46.08 342.32 8,537.69 2,637.03 953.79 5,977,820.89 671,637.43 70° 20' 42.962 N 148° 36' 24.314 W 9,414.58 57.64 339.73 8,558.28 2,661.82 945.22 5,977,845.47 671,628.30 70° 20' 43.206 N 148° 36' 24.564 W 9,443.58 61.29 339.72 8,573.01 2,685.24 936.56 5,977,868.69 671,619.12 70° 20' 43.436 N 148° 36' 24.817 W 9,474.10 64.46 341.59 8,586.93 2,710.87 927.57 5,977,894.10 671,609.55 70° 20' 43.688 N 148° 36' 25.079 W 9,504.70 65.55 344.60 8,599.86 2,737.40 919.51 5,977,920.44 671,600.88 70° 20' 43.949 N 148° 36' 25.315 W 9,536.08 65.98 348.47 8,612.74 2,765.22 912.85 5,977,948.10 671,593.59 70° 20' 44.223 N 148° 36' 25.509 W 9,568.16 64.87 345.04 8,626.09 2,793.61 906.17 5,977,976.34 671,586.27 70° 20' 44.502 N 148° 36' 25.704 W • 9,600.36 65.60 340.15 8,639.58 2,821.50 897.43 5,978,004.02 671,576.89 70° 20' 44.776 N 148° 36' 25.960 W 9,629.58 65.53 337.62 8,651.67 2,846.32 887.85 5,978,028.60 671,566.75 70° 20' 45.021 N 148° 36' 26.240 W 6 .(tAJ - 1 9,662.64 66.09 336.42 8,665.22 2,874.08 876.07 5,978,056.09 671,554.35 70° 20' 45.294 N 148° 36' 26.584 W C 9,706.52 65.33 338.41 8,683.27 2,911.00 860.71 5,978,092.65 671,538.15 70° 20' 45.657 N 148° 36' 27.032 W 9,736.08 66.32 343.31 8,695.38 2,936.47 851.88 5,978,117.91 671,528.74 70° 20' 45.907 N 148° 36' 27.290 W q6 ". N4" 9,762.68 66.42 347.40 8,706.05 2,960.04 845.72 5,978,141.33 671,522.04 70° 20' 46.139 N 148° 36' 27.470 W (� 9,807.38 65.46 352.84 8,724.28 3,000.23 838.71 5,978,181.35 671,514.12 70° 20' 46.534 N 148° 36' 27.675 W 9,847.20 65.00 356.97 8,740.97 3,036.23 835.50 5,978,217.27 671,510.09 70° 20' 46.888 N 148° 36' 27.769 W 9,877.28 65.09 359.73 8,753.66 3,063.49 834.71 5,978,244.50 671,508.69 70° 20' 47.157 N 148° 36' 27.791 W 9,906.94 65.00 358.07 8,766.18 3,090.38 834.20 5,978,271.36 671,507.56 70° 20' 47.421 N 148° 36' 27.806 W 9,951.82 65.15 356.70 8,785.09 3,131.03 832.34 5,978,311.96 671,504.78 70° 20' 47.821 N 148° 36' 27.861 W 9,983.46 64.30 352.36 8,798.61 3,159.50 829.62 5,978,340.36 671,501.41 70° 20' 48.101 N 148° 36' 27.940 W 10,011.88 64.49 348.63 8,810.89 3,184.77 825.39 5,978,365.53 671,496.60 70° 20' 48.349 N 148° 36' 28.064 W 10,045.40 64.78 345.21 8,825.26 3,214.27 818.53 5,978,394.86 671,489.08 70° 20' 48.639 N 148° 36' 28.264 W 10,073.16 65.22 341.56 8,836.99 3,238.37 811.34 5,978,418.79 671,481.34 70° 20' 48.876 N 148° 36' 28.474 W 10,105.46 65.46 334.75 8,850.48 3,265.60 800.42 5,978,445.76 671,469.81 70° 20' 49.144 N 148° 36' 28.793 W 10,133.62 65.24 333.81 8,862.23 3,288.66 789.32 5,978,468.56 671,458.18 70° 20' 49.371 N 148° 36' 29.117 W 10,163.28 65.44 329.89 8,874.61 3,312.42 776.60 5,978,492.02 671,444.93 70° 20' 49.605 N 148° 36' 29.489 W 10,198.32 65.95 323.87 8,889.04 3,339.14 759.16 5,978,518.34 671,426.88 70° 20' 49.868 N 148° 36' 29.998 W 10,227.34 66.37 318.76 8,900.77 3,359.85 742.58 5,978,538.66 671,409.83 70° 20' 50.071 N 148° 36' 30.483 W 10,258.24 65.77 313.74 8,913.32 3,380.25 723.06 5,978,558.61 671,389.85 70° 20' 50.272 N 148° 36' 31.053 W 10,287.22 66.41 309.82 8,925.06 3,397.89 703.30 5,978,575.80 671,369.71 70° 20' 50.445 N 148° 36' 31.630 W 10,316.86 66.93 305.91 8,936.81 3,414.59 681.82 5,978,592.00 671,347.85 70° 20' 50.610 N 148° 36' 32.258 W 10,356.40 66.94 300.43 8,952.31 3,434.49 651.38 5,978,611.20 671,316.97 70° 20' 50.805 N 148° 36' 33.147 W 10,440.00 66.94 300.43 8,985.05 3,473.45 585.06 5,978,648.63 671,249.78 70° 20' 51.189 N 148° 36' 35.085 W TD 2/16/2010 9:26:13AM Page 3 COMPASS 2003.16 Build 71 • DI rig • Survey Report - Geographic by INTEQ Company: North America - ALASKA BP Local Co- ordinate Reference: Well K -07 Project: Prudhoe Bay TVD Reference: K -07C @ 54.66ft (generic rig) Site: PB K Pad MD Reference: K -07C © 54.66ft (generic rig) Well: K -07 North Reference: True Welibore: K- 07EPB1 Survey Calculation Method: Minimum Curvature Design: K- 07EPB1 Database: EDM .16 Anc Prod - WH24P 1 Targets Target Name - 'hit/misstarget Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting - Shape (") ( °) (ft) (ft) (ft) (ft) (ft) Latitude L K -07E Fault 1 0.00 0.00 54.66 3,186.15 346.66 5,978,356.00 671,018.00 70° 20' 48.363 N 148° 36' 42.052 W - survey misses target center by 8387.98ft at 9224.23ft MD (8397.61 TVD, 2576.20 N, 964.24 E) - Polygon Point 1 54.66 3,186.15 346.66 5,978,356.00 671,018.00 Point 2 54.66 2,958.06 830.62 5,978,139.00 671,507.00 Point 3 54.66 2,883.04 1,489.13 5,978,079.00 672,167.00 Point 4 54.66 2,958.06 830.62 5,978,139.00 671,507.00 K -07E Fault 2 0.00 0.00 54.66 3,471.76 982.37 5,978,656.00 671,647.00 70° 20' 51.172 N 148° 36' 23.475 W - survey misses target center by 8390.90ft at 9224.23ft MD (8397.61 TVD, 2576.20 N, 964.24 E) - Polygon Point 1 54.66 3,471.76 982.37 5,978,656.00 671,647.00 Point2 54.66 3,141.15 1,795.11 5,978,344.00 672,467.00 K -07E Fault 4 0.00 0.00 54.66 3,784.80 -68.85 5,978,945.00 670,589.00 70° 20' 54.251 N 148° 36' 54.193 W - survey misses target center by 8493.10ft at 9224.23ft MD (8397.61 TVD, 2576.20 N, 964.24 E) - Polygon Point 1 54.66 3,784.80 -68.85 5,978,945.00 670,589.00 Point2 54.66 4,449.96 592.51 5,979,625.00 671,235.00 K -07E Target 1 0.00 0.00 8,864.66 3,271.43 730.73 5,978,450.00 671,400.00 70° 20' 49.202 N 148° 36' 30.829 W - survey misses target center by 60.08ft at 10145.95ft MD (8867.39 TVD, 3298.64 N, 784.23 E) - Point K -07E Fault 3 0.00 0.00 54.66 3,691.15 661.26 5,978,868.00 671,321.00 70° 20' 53.330 N 148° 36' 32.858 W - survey misses target center by 8422.57ft at 9224.23ft MD (8397.61 TVD, 2576.20 N, 964.24 E) - Polygon Point 1 54.66 3,691.15 661.26 5,978,868.00 671,321.00 Point 2 54.66 3,887.59 1,171.90 5,979,076.00 671,827.00 K -07E Target 2 0.00 0.00 8,960.66 3,447.67 634.71 5,978,624.00 671,300.00 70° 20' 50.935 N 148° 36' 33.634 W - survey misses target center by 22.84ft at 10356.40ft MD (8952.31 TVD, 3434.49 N, 651.38 E) - Point K -07E Polygon 0.00 0.00 54.66 3,456.27 432.84 5,978,628.00 671,098.00 70° 20' 51.020 N 148° 36' 39.533 W - survey misses target center by 8406.05ft at 9224.23ft MD (8397.61 TVD, 2576.20 N, 964.24 E) - Polygon Point 1 54.66 3,456.27 432.84 5,978,628.00 671,098.00 Point 2 54.66 3,541.51 686.86 5,978,719.00 671,350.00 Point 3 54.66 3,235.13 962.98 5,978,419.00 671,633.00 Point4 54.66 3,192.26 692.91 5,978,370.00 671,364.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 6,989.79 6,276.99 9 5/8" 9.625 12.250 9,186.79 8,360.39 7" 7.000 8.500 Survey Annotations Measured Vertical Local Coordinates Depth Depth +f4/ -S +E! -W (ft) (ft) (ft) (ft) Comment 9,224.23 8,397.61 2,576.20 964.24 TIP 9,230.00 8,403.35 2,576.81 964.34 KOP 10,440.00 8,985.05 3,473.45 585.06 TD 2/16/2010 9 :26 :13AM Page 4 COMPASS 2003.16 Build 71 TREE = ` ' 6" McEVOY ID SA, NOTES: ORIGINAL, SIDETRACK "A ", "B ", WELLHEAD = McEVOY "C" S "D" WELLBORES NOT SHOWN ON THIS ACTUATOR = OTIS K-07 E DIAGRAM. KB. ELEV = 54.66' BF. ELEV = 27.91' :1 I KOP = 9325' Max Angle = 67° @ 9634' I I I 2014' H 4 -1/2" HES X NIP, ID = 3.813" I Datum MD = 10061' Datum ND = 8800' SS 2604' H 9 -5/8" DV COLLAR I 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2709' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Ld 4 3295 3292 10 MMG -M DOME RK 16 03/04/10 Minimum ID = 2.36" 9150 3 6012 5556 43 MMG -M SO RK 20 03/04/10 2 7836 7037 15 KBG -2LS DMY INT 0 12/06/99 LINER TOP PACKER 1 8888 8064 8 KBG -2LS DMY INT 0 12/06/99 'TOP OF 7' LNR 1-1 6803' I L , 6803' I- -I9 - 5/8" X 7" BKR ZXP PKR w /TIEBK SLV, ID = 6.313" I 1 6816' H 9 -5/8" X 7" BKR HMC HGR, ID = 6.250" I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" h 6992' I I 8997' H 4 -1/2" HES X NIP, ID = 3.813" E I 9011' 1 X 4-1/2" HES TNT PKR, ID = 3.875" I ' I 9028' I-- I4 -1/2" HES XN NIP - MILLED OUT 01/21/05, ID = 3.80" I 9036' H 7' x 5" BKR ZXP PKR, ID = 4.375" I 14-1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9040' I 9040' I- I 4 -1/2" WLEG, ID = 3.958" ■ 9050' H 7" X 5" BKR HMC HGR, ID = 4.375" I 9058' I X 4 -1/2" XO, ID = 4.00 I 9150' 1 KB PKR, ID = 2.36" I I ' I 9155' H3.70" DEPLOY SLV, ID = 3.00" I 9176' I-J 3 - 1 /2" OTIS X NIP, ID = 2.812" 7" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1 - 1 9189' I I I 9210' I-I -1/2" X 3- 3/16" XO, ID = 2.786" I I4 -1/2" WHIPSTOCK 1-1 9233' v t4 ` �� 12 RA TAGS H 9242' r --. l 4 MILLOUT MILLOUT WINDOW (K - 07E) 9233' - 9242' . ` PERFORATION SUMMARY —1 10279' I 1 3- 3/16" X 2 -7/8" XO, ID = 2.387" I REF LOG: NA ANGLE AT TOP PERF: 52° @ 10185' Note: Refer to R DB for historical perf data 3- 3/16" LNR, 6.2 #, L -80 TCII, 10279' SIZE SPF INTERVAL Opn /Sqz DATE 0076 bpf, ID = 2.80" 2" 6 10185 - 10280 0 02/18/10 I PBTD I 10282' I2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" H 10300' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/05/83 ORIGINAL COMPLETION 03/10/10 CH/JMD DRLG DRAFT CORRECTIONS WELL: K -07D 12/06/99 RIG SIDETRACK (K -07C) PERMIT No: ° '2091270 01/21/05 NORDIC 1 CTD (K -07D) API No: 50 - 029 - 21045 - - 02/20/10 NORDIC 1 CTD SIDETRACK(K - 07E) SEC 4, T11 N, R14E, 2041' FNL & 473' FWL 03/04/10 DAV /PJC GLV C/O 03/06/10 PJC DRLG HO CORRECTIONS BP Exploration (Alaska) GENE } t..AI\ 'J 1) ll pi 04/21/10 Schiwulergrr NO. 5511 y „._ . r , ^ Y , . q , S " //�� � i E .'� .,7t Vd� .,. 1 '. 'S'4;v o, Alaska Data & Consulting Services Company: State of Alaska Andbtraga 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD F -30 BBUO-00014 PRODUCTION PROFILE . if 4 ib " 19 OS'? 03/17/10 1 1 12 -14AL1 AYKP -00079 PRODUCTION PROFILE (� ) iq 03/18/10 1 1 12 -15 B3SQ -00049 PRODUCTION PROFILE ) ' � j (e 5` , (, i 03/18/10 1 1 17 -11 83SG -00053 PRODUCTION PROFILE my -�� �' ( G ,, i 03/30/10 1 1 17 -05 B3SQ -00052 PRODUCTION PROFILE / - - / 1 03/29/10 1 1 J -23A BCUE -00010 MEM PRODUCTION PROFILE ,P1141— ( 3 J 04/14/10 1 1 _ 07 -18 BC72 -00006 FL DETERMINATION/PERF / 0: •a — (J_71 / GE i 04/17/10 1 1 0 • -LE. P 04114/10 1 1 04/17/10 1 1 (:) °111. P2 -31A B3SQ -00046 CH EDIT PDC ((JUNK BASKET) ZAq – 1 b j q # `64 02/27/20 1 � O C -15A AWJI -00069 MCNL 00 – ( � a +R > c L 01/27/10 1 1 b�J K -07E B2NJ -00054 MCNL ., . / `, 9/ g' 02/18110 1 1 01 -28A BAUJ -00004 MCNL d ( S I �'S-7f 12/18/09 1 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1 3 • � # « 997 7 oko c X SEAN PARNELL, GOVERNOR LI I L L / ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1 LISSION / ANCHORAGE, ALASKA 99501 -3539 07 PHONE (9 07) 279-1433 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K -07E BP Exploration (Alaska) Inc Permit No: 209 -127 Surface Location: 2041' FNL, 473' FWL, SEC. 04, T11N, R14E, UM Bottomhole Location: 1426' FSL, 1150' FWL, SEC. 33. T12N. R14E, UM Dear Mr. McMullen: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). • cerely, Daniel T. Seamount, Jr. Chair DATED this3° day of October, 2009 cc: Department of Fish 85 Game, Habitat Section w/o end. Department of Environmental Conservation w/o end. STATE OF ALASKA RECEIVED.Adie ALASepIL AND GAS CONSERVATION COMMI N / PERMIT TO DRILL OC1 2 0 2009 20 AAC 25.005 la. Type of work: lb. Proposed Well Class: ® Development Oil ❑ Service - Winj ❑ Single Zone liaskikaikOrtiesgonassinistiol ❑ Drill ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Ai11±hs Hydrates ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ((�] b ale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU K - 07E 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 10366' TVD 8906'ss Prudhoe Bay Field / Prudhoe 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028303 & 028300 2041' FNL, 473' FWL, SEC. 04, T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 592' FSL, 1499' FWL, SEC. 33, T12N, R14E, UM January 15, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1426' FSL, 1150' FWL, SEC. 33, T12N, R14E, UM 2560 5,700' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 54.66' feet 15. Distance to Nearest Well Open Surface: x- 670744 y- 5975163 Zone- ASP4 GL Elevation above MSL: 26.21' feet to Same Pool: 1,370' 16. Deviated Wells: Kickoff Depth: 9250 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angie: 66 degrees Down hole: 3289 Surface: 2409 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 4 - 1/8" 3 - 3/16" / 2 - 7/8" J 6.2# / 6.16# L - 80 TCII / STL 1186' 9180' 8298'ss ,10366' 8906'ss 71 cu ft Class '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 ND (ft): Junk (measured): 11901 8729 None 11901 8729 None Casing ' Length Size Cement Volume MD TVD Conductor / Structural 110' 20" x 30" 8 cu vds Concrete 110' 110' Surface 2709' 13 -3/8" 3264 cu ft PF 'E'. 465 cu ft PF II 2709' 2709' Intermediate 6992' 9 -5/8" 2119 cu ft Class 'G'. 133 cu ft PF 'C' 6992' 6279' Production Liner 2386' 7" 527 cu ft Class 'G' 6803' - 9189' 6139' - 8362' Liner 280' 4-1/2" 280 cu ft Class 'G' 9036' - 9316' 8210' - 8488' Liner 2636' 3 -1/2" x 3- 3/16" x 2 -7/8" 62 cu ft Class 'G' 9265' - 11901' 8438' - 8729' Perforation Depth MD (ft): Slotted Liner: 10436' - 11900' Perforation Depth ND (ft): 8791' - 8729' 20. Attachments: ❑ Property Plat IS BOP Sketch _4 Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Cody Hinchman, 564 -4468 Printed Name Jo Mr; ,i' /Ai Title Engineering Team Leader Prepared By Name/Number: Signature '/' Phone 564 -4711 Date t(S/�j / G " j Terrie Hubble, 564 -4628 Commission Use Only /// Permit To Drill API Number: Permit pro I Date: See cover letter for Number: a,0574,7 � 50- 029 - 21045 -05 -00 _ /0 f other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed gas hydrates, or gas contained shales: (E Other: * 3s 1 01-.... 60 Si° Samples Req'd: ❑ Yes No Mud Log Req'd: ❑ erNo An \ HA Measures: ' b0 Yes ❑ No Directional Survey Req'd: Litt Yes ❑ No 7 t Z SOO 1Sv pinn �t.lct_,r T L s /; 1 � O Date APPROVED BY THE COMMISSION / , COMMISSIONER Form 10-401 Revised 0 /2009 This permit is valid for 24 months frote date of approval (20 AAC 25.005(9)) Submit In Duplicate ORIGINAL id. o, de,e70/ • • • � bp BPXA Prudhoe Bay K -07E Sidetrack To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Cody Hinchman CTD Engineer Date: October 15, 2009 Re: PBU K -07E Permit to Drill Permit to Drill approval is requested for a sidetrack lateral from the K -07E well. Well History K -07D was drilled in January 2005 as a CTD sidetrack targeting Z1 A sands. It was a bonsai completion with slotted liner below 10,436' MD. As a result of the liner failing a pressure test, a KB LTP was set. Production started at 30k GOR and exceeded MGOR within two weeks. It healed to 40k after a month SI and stayed on for a week after being returned to production. Since then the well has had virtually no on -time and has been utilized as a swing well. Diagnostic SCMT /CNL/Temp logs were run on 6/17/05. The SCMT showed cement form 10,300' to 9476'. The updated GOC from the CNL was 9683' MD (8730' tvdss) leaving -20' LOC. The temp log was run shortly after the well was SI and there was no clear indication of gas entry from the residual temp profile. A STP was run on 1/28/06 over the LTP interval to rule out the possibility of an LTP leak. The STP showed no indication of a LTP leak. The gas influx was then suspected to be from either thin LOC or a fault/fracture matrix from a huge boundary fault to the North. An STP was run on 9/05/07 to help determine the gas source and found the majority of gas coming in at the top of the slotted liner at 10,436' MD and at the bonsai baffle plate at 10,340'. Due to having a good cement job, it is not suspected we are connected up with the gas cap but rather that we have no cement between the reservoir and the bonsai baffle plate. Also, it seems the majority of production from the well is flowing outside the slotted liner and entering at 10,436' MD. Due to its low value, K -07D has been screened for CST multiple times, including 2007 and 2009. A calliper run on 12/14/07 showed the tubing and liner to be in good condition with no significant areas of cross sectional wall loss. On 7/23/09, an MIT -IA and MIT -OA passed to 3000 psi and 2000 psi respectively. A packoff test of the tubing and inner casing both passed and all LDS were torqued and cycled At current operating conditions, K -07D is uncompetitive and has had no significant on -time since it was drilled in 2005 due to high GORs. Reason for PTD Request - Your approval is requested to drill a coil sidetrack lateral from the K -07D well. The proposed K -07E well is a high angle GD well through ZN1 and ZN2 and will increase reservoir exposure while maximizing standoff to the GOC. CTD Sidetrack Summary Pre -Rig Work Summary: 1. V PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi. 2. F MIT -IA to 3000 psi, OA to 2000 psi. 3. W Function LDS - 4. W PPPOT -T- 5. S Dummy all GLM's 6. S Drift with dummy 4 -1/2 ".)stock and tag PKR at 9265' 7. E Set 4-1/2" packer whipst with top at 9,230'. 8. F PT packer whipstock to 1000 psi 9. 0 Bleed T, IA, gas lift and production flowlines down to zero and blind flange. 2 06j -S 10. 0 Remove S- Riser, Remove wellhouse, level pad. J Rig Sidetrack Operations: (Scheduled to begin on January 15, 2010 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high. 3. Mill a 3.80" window at 9230'. 4. Drill build /turn section of the K -07E lateral with 4.125" bicenter bit and land well. 5. Drill lateral section to 10,368' MD. 6. Run and cement a 3- 3/16" x 2 -7/8" solid liner string. (12.6 bbls of cement) 7. Make a cleanout run with mill and motor. 8. Make a logging run with a SWS GR -CNL logging tool. 9. Set LTP. 10. Make a perforating run with 2.0" OD pert guns (-100'). 11. Circulate well to KWF brine. FP well to 2000' with diesel. 12. Set BPV. ND 7- 1/16" stack. FP tree and PT tree cap to 3500 psi. 13. RDMO Nordic 1. Post -Rig Work: 1. V Pull BPV. 2. 0 Re- install well house and FLs 3. S Run gas lift design. 4. T Flow test well (100' of perfs). Mud Program: • Well kill: 8.6 ppg brine. • Milling /drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: Fully cemented liner • 3- 3/16 ", L -80 6.2# TCII 9,180' and - 9,800' and • 2 -7/8 ", L -80 6.16# STL 9,800' and - 10,366' and • A minimum of 12.6 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 4 -1/8" bit size and TD @ 10,366', with 40% excess in the open hole interval) • TOC planned at 9,180' Existing casing/tubing Information 13 -3/8 ", L -80 72 #, Burst 5380, collapse 2670 psi 9 5/8 ", L -80 47 #, Burst 6870, collapse 4750 psi 7 ", L -80 26 #, Burst 7240, collapse 5410 psi 4 -1/2 ", L -80 12.6 #, Burst 8430, collapse 7500 psi 3- 3/16 ", L -80, 6.2 #, Burst 10,160, collapse 10,540 2 -7/8 ", L -80, 6.16 #, Burst 10,570, collapse 11,170 Well Control: • • BOP diagram is attached. • 2" coil will be used to drill the laterals • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 3500 psi. Directional • See attached directional plans. Maximum planned hole angle on the K -07E lateral is 65.70 deg @ 9,875' . • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 5,700' N. • Distance to nearest well in pool is 1,370' to well K -08A. Logging • MWD directional and Gamma Ray will be run over all of the open hole sections. • Gamma Ray, CCL and CNL will be run after the lateral is cased. Hazards • The maximum H2S concentration on the K -07C well is 10 ppm recorded on 8/12/2000. • The maximum H2S concentration on the pad is on well K -03B at 20 ppm on 3/16/2008. Reservoir Pressure • The reservoir pressure on K -07D was last recorded at 3,289 psi at 8,800' TVDSS in Oct. 2007. (7.19 ppg equivalent) . • Max. expected surface pressure with gas (0.10 psi /ft) to surface is 2,409 psi. Cody Hinchman CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble TREE = 6 PlicEVOY • T _ . M Will DIME 7r 970 , . 17. WELLHEAD = 6" McEVOY ACTU4TOR = OTIS K-070 PRE- K-070 WOK VIELLSOFIE pare a K-117C) WIT WM= nu TIM numusan Elf . ECEV = 27.91' KOP *.................. 9325' . .„.....iiT_AVe !.._ .................. I 2014' H41/2" I4W X NV, ID = 3913" I mum MD = 9.6.54' I Datum TVD = 8E00' SS 215114' I-194ff DV COLLAR I 113-3/8" CS0.729, L-80. ID = 12.347" H nor J OAS LIT MANDRELS T MD TVD DEV TYPE VLV LATCH PORT DATE Ur 4 3295 3238 11 MMG-M DMY RK 0 071209 3 6012 5501 42 MMO-M DMY RK 0 07/209 Minimum ID Is 2.30"S 10337' 2 7836 6982 17 1030-ZS DMY INT 0 12/06/99 BKR 0 RMI3 SUB (MILLED oinsns) 1 8888 8009 8 KEI0-2LS DMY _ ea 0 12/06/99 ITOP OF7' LNR H nor I --I 11119' H9-5/9" X r 9KR ZXP PKR la/ WOK SLV. ID =0.313" 110117 1-19-5/r X7" 9KR NW 140.R. ID =0.250' I 'TOP OF WHIPSTOCK I-1 SW I MLLOUT WINDOW(1(17C) 699? 7008' I 4 \ I 11997' H4-1/2" HES X NIP, ID = 3.813] v I I:1 9011' (---17" X 41fr HES TNT PKR.11) =3.875" I A I IO21' H4.1/2" HES X/4 NIP-MILLED OUT oiatec 9037 HT x 5* BKR ZXP PKR. ID = 4.375' I 141/2" 190, 12.09. L-80..0152 bpf. ID* 3.958" 9039' :. 'A 9040' 1-141/2" WLEG. ID a 3.958" I 9090' I--Ir x 5" IIIKR NIX NOR. 11) 4.375" 1 17" LNR, 269. L-80 IITC..0383 bpf. ID = 6.276" H sur F-41 ONY 4112“ KB PKR, ID * 239" IPASC HANICAL HOLLOW WS H gm. L I 9277 H3-1/2" DEPLOY SLV, ID a 3.00" I RA I MY . 1 - 43.1/2" OTIS )(N NP*4 /RA TAO. II ..2.84" -mAava4-1-1Thr PERFORATION &MARY REF LOG: NA 9297 H3 X 3 X0. ID" 2.786" I ANGLE AT TOP PS?. 93 0 10436' Note: Refer to Produdion DO for historical "art data 1 MLLOUT WINDCWOLVD) 9325'. 9330' SIZE 1 SPIr INTERVAL OpniSqz DATE PRE-DRILLED 10436 - 119C0 0 01/21/05 I 9710' }-13-3/14* X 2-7/8" XO. ID = 2.377" 1 '‘ FIITD --1 10734' % % 14112" LNR. 12.69, L-80 IC, .0162 bpf. ID = 3.959" { 10920' I V VAN OW■ % 13-3118* LNR. 629. L-80 TCI..0078 bpf . ID = 2.80" 1 9700' MID 111e0 I2-7/8* LNR. 6.169. L80 STL, .0058 bpf. ID • 2.441" H DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11111111 ORIGINAL COMPLETION 12117/07 TFA/SV OLV 00 WELL: K-07D linen IIIG ROMA= fLrfg 06/28109 ACB/TLH OLV 00 PERMIT No: 1042420 01•199 00001C 1 CTD Q(OID) 07/24109 CJNIPJC OLV CA) (07/24/09) API No: 50-029-21045-04 05/29/126 COATM PERF/TREE CORRECT (6/13/04) SEC 4, 111N, R141, 2041' SM. & 473' En.. 09/27106 ?PJC ORLO DRAFT CORRECTION 05/28107 JAFA DRLG DRAFT CORRECTION • Worst's* plink4 TREE = 6" McEVOY • WELLHEAD = NtEVOY K _0 7 E SAFETY NOTES: WELL ANGLE > 70" If 9700'. ACTUATOR = OTIS PRE- K -07D SDTRK WELLI30RE CK.0711 & K -07C) KB. ELEV = 54.66' Proposed CTD Sidetrack MIT cNnww nN TNtc rnar,Ralu BF. ELEV = 27.91' KOP = 9325' Max Angle = 98' @ 11585' ' 201 2604 4 ' — I 49 - 518" 1/2' H DV COES X LLAR NIP, ID = 3213" Datum MD = 9854' Datum TVD = 8800' SS 13 -318" CSG, L -80, ID = 2 347" I 2709' I G LI FTMA ID RELS ST MD TVD DEV TYPE VLV LATCH PORT DATE En 1 3295 3238 11 MMG -M DMY RK 0 07(24/09 3 6012 5501 42 MMG -M DMY RK 0 07(24 /09 Minimum ID = 2.30" ill 9170' 2 7836 6982 17 KBG -2LS DMY INT 0 12 /06/99 TOL 3.5" 1 8888 8009 8 KBG -2LS DMY INT 0 12 /06/99 TOP OF 7' LNR —1 6809' I 420 6809' -- I 9.518" X 7" BKR ZXP PKR w I TIEBK SLV, ID =8.313" i 1:4 I 4 6816 1- 9.5/8" X7" BKR HMC HGR, ID = 8.250" I TOP OF WHIPSTOCK —I 6992' MILLOUT MNDOW (K - OiC) 6992' - 7008' ' 899T 11410 HES X NIP, ID = 3.813' e i � 9011' —17" X 4-1/2' HES TNT PKR, ID = 3.875" • 902W — 141E2" HES XN NIP- MILLED OUT01/21/05, ID = 3.80 1 9036' H7 x 5" BKR ZXP PKR, ID = 4.375" I 1 1_I 9040' 4- 1 /2" W LEG, ID = 3.958" 141/2" TBO, 12.6 #, L -80, .0152 bpf, ID = 3.958" I-1 9039' I A. 9050' —17" x 5" BKR HMC HOR, ID = 4.375" I e 9058' —15" x 4.9' Xo, ID = 4.000" 7" LNR, 26 #, L -80 BTC, .0383 bpf, ID = 5.276" I 9189' \\ - ,/ R, ID = 2.563" I TSGR 9160' Y SLV, ID = 2.30" I r0CK H 9230' I 16" ''O, ID= 2.786" I PEORATION SUMMARY 6° REF LOG: NA 141(Y" KB PKR, ID = 2." I ANGLE AT TOP PERF: xx @ xxxx' Note: Refer to Production DB for hitoricl pert data SIZE SPF INTERVAL OpnlSga DATE 0' I ,3 -3/1 6" X 2 -718" XO, ID = 2.377" 4 -1 /2" LNR, 12.6 #, L -80 IBC, .0152 bpf, ID = 3.958" —I PBTD H MECHANICAL HOLLOW WS H 932T ;r Q. 0 RA MARKER H 9329' I 65 ,r.,15.2#, L -80 TCII. .01 = 2.80" ?? ' - IILLOI IT'V 1ND::U,t (CM) 12 -7/8" LI '" STL, 0058 bpf, ID = 2.441" H 10368' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 17AIO ORIGINAL COMPLETION 12/17 /07 TFA/SV GLV CO WELL: K -07 121 11133 RIG SIDETRACK (K -OSC) 06/28 /09 ACB/TLH GLV CO PERMIT No: 01l21105 NORDIC 1 CTD (K -010) 07(24 /09 CJNIPJC GLV CO (07/24 /09) API No: 50- 029 - 21045 -0 05/29/06 COOTM PERF/TREE CORRECT (6/13/04) 09/01/09 MSE PROPC6ED CTD SIDETRACK SEC 4, TI 1 N, RI4E, 2041' SNL & 473' BM_ 0927106 ?/PJC DRLG DRAFT CORRECTION 0528 /07 JAFIPJC DRLG DRAFT CORRECTION _ _ BP Ex orrtion (Alrsks) • • Rig Floor to To of Lubricator Rig Floor to Top of Bag Well G -16A 2.25 f 111111111 '4 - --- -. 9.23 ` Lubricator ID = 6.375" with 6" Otis Unions • I l-lydril Annular I 7 1116" Annular x 5000 psi 1 5.00 :, • 7 1;16" 5000 psi. RX -46 I Blind 12.65 I 4r-- � TOT Shears 13.56 1..______, ME — 7 1/16" 5000 psi RX -46 ll 2 1;16" 5000 psi . R -24 I — �—� Mud Cross ± f_—_L — �-- I — HCR_ _ M at"dcross V‘ligE-----1 _ HCR - 14.89 — 4 Choke Line I Kill Line ` 1 r 1 16.10 14-- 2W" x 3 1t2" 2 1/16" 5000 psi , RX -24 Variable Ram - 16.66 I f— 2" Combs TOT 7 1116" 5000 psi (RX -46) 7 1/16" X 3 1/8' Flanged Adapter --II. i 20.04 I Swab Valve I F_______j I Tree Size r 4 116" r 1 6" I I Flow Tee I , Flow Line --P. 1 22.88 ` • O SSV I J _ 24.86 Master Valve I I I iceDLJ_ rC° 26.68 I Lock Down Screws I 31.00 ` Ground Level I nag BPPASSPORT BAKER BP Coil Tubing Report 0 by . HUGHES Company North America - ALASKA - BP Local Co- ordinate< Reference Well K -07 .:Project :., Prudhoe Bay <` TYD Ref a[enee Mean Sea Level Site • PB K Pad MD R eference i K -07C @ 54.66ft (generic rig) Well ' K -07 North Reference.; True Vt elibore : Plan 3, K -07E :Survey Calculation Method) Minimum Curvature Design .....' ' Plan 3 a Database EDM .16 - Anc Prod - WH24P Project Prudhoe Bay North Slope, UNITED STATES 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 K Pad,, TR 11 -14 ... ... .. ......... .... . .:.r Site Position: Northing: 5,973,161.33 ft Latitude: 70° 19' 57.435 N From: Map Easting: 670,342.10 ft Longitude: 148° 37' 5.245 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.30 ° . , . . Well , K -07, K -07 Well Position +N / -S 0.00 ft Northing: 5,975,163.00 ft Latitude: 70° 20' 17.028 N +E / -W 0.00 ft Easting: 670,744.00 ft Longitude: 148° 36' 52.181 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Weliborre : ; Plan 3, K -07E Magnettas Model Name Sample Date Declination Dip Angle Fletd. Strung #h BGGM2009 10/7/2009 22.53 80.96 57,678 Dae# Plan 3 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,224.23 Vortical Section . e Depth From (TVD) + N/-S #Et W Direction (ft) (ft) tft) ( °) � -26.21 0.00 0.00 330.00 10!7/2009 2:51:22PM Page 2 COMPASS 2003.16 Build 71 [ail ! BPPASSPORT BAKER BP Coil Tubing Report 0 bp HUGHES Company North America - ALASKA - BP Local Co -ordinate Reference Well K -07 Project ! Prudhoe Bay TYD Reference �, Mean Sea Level ,,Site PB K Pad M D @ .66 (generic Reference K -07C 54 ft (ge ri g) Well K -07 North Reference True Wellbore: > ; Plan 3, K -07E y' Survey Ca tcula(ton Method Minimum Curvature Dealgn Plan 3 database: EDM .16 - Anc Prod - WH24P il Survey Tool Program Date 10/7/2009 Frorri To (ft) (ft) Survey Yllellbore) Tool Name Description 91.45 6,889.24 1 : Sperry-Sun BOSS gyro multi (K -07) BOSS -GYRO Sperry-Sun BOSS gyro multishot 6,988.24 9,224.23 2 : MWD - Standard (K -07C) MWD MWD - Standard 9,224.23 10,366.34 Plan 3 (Plan 3, K -07E) MWD MWD - Standard Ptanned.Survey. MD )' ; Inc Azi TVDSS ' N /S E!W rthing. sting . DL eg Y Sec TFaacef ( ft ' ( °) °) g ( ) (ft (ft) No (fty Ea (ft} ( °110oft) (ft). ; =i : (°y >: 9,224.23 6.18 10.13 8,343.34 2,575.45 963.83 5,977,759.55 671,648.88 0.00 1,748.49 0.00 TIP 9,230.00 6.12 7.36 8,349.08 2,576.06 963.93 5,977,760.17 671,648.96 5.22 1,748.97 - 102.01 KOP 9,250.00 7.90 5.09 8,368.93 2,578.49 964.19 5,977,762.60 671,649.16 9.00 1,750.94 -10.00 End of9 deg /100ftDLS 9,300.00 25.31 358.07 8,416.66 2,592.70 964.13 5,977,776.81 671,648.78 35.00 1,763.28 -10.00 9,400.00 60.29 355.96 8,488.90 2,659.48 960.23 5,977,843.47 671,643.36 35.00 1,823.06 -3.20 9,404.89 62.00 355.91 8,491.26 2,663.75 959.93 5,977,847.74 671,642.96 35.00 1,826.91 -1.57 End of35 deg /100ft DLS 9,500.00 62.60 343.03 8,535.62 2,746.29 944.55 5,977,929.90 671,625.71 12.00 1,906.08 - 90.00 9,600.00 64.48 329.78 8,580.33 2,828.03 908.75 5,978,010.80 671,588.06 12.00 1,994.77 -83.99 9,624.89 65.13 326.56 8,590.93 2,847.16 896.87 5,978,029.65 671,575.75 12.00 2,017.28 -78.07 5 , 9,700.00 64.52 336.50 8,622.94 2,906.81 864.51 5,978,088.55 671,542.04 12.00 2,085.12 96.00 9,800.00 64.75 349.78 8,665.93 2,993.02 838.39 5,978,174.14 671,513.97 12.00 2,172.84 91.76 9,874.89 65.70 359.63 8,697.38 3,060.62 832.15 5,978,241.57 671,506.19 12.00 2,234.50 86.05 6 9,900.00 65.36 356.34 8,707.79 3,083.45 831.35 5,978,264.38 671,504.87 12.00 2,254.68 -97.00 10,000.00 64.77 343.11 8,750.10 3,172.41 815.25 5,978,352.94 671,486.75 12.00 2,339.77 -95.64 10,100.00 65.35 329.89 8,792.43 3,255.31 779.18 5,978,434.99 671,448.81 12.00 2,429.59 -90.04 10/7/2009 2:51:22PM Page 3 COMPASS 2003.16 Build 71 FARO BPPASSPORT BAKER BP Coil Tubing Report 0 bp HUGHES Company North America - ALASKA - BP Locat Co;:o Well K -07 Project Prudhoe Bay VD Reference Mean Sea Level $Rte PB K Pad :; @ 4.66 (generic g MD Reference K 07C 5 ft e rig) W81f' S K -07 North Reference True Welibor8: Plan 3, K -07E Survey Calculation Method Minimum Curvature Destgn. , ',- Plan 3 Database; EDM .16 - Anc Prod - WH24P Ptanned.Survey MD : Inc . Azi TVDSS N($ "EIW Notttftng E asting [Leg ; 3 V Sec TF ,,, 10,124.89 65.67 326.63 8,802.75 3,274.56 767.27 5,978,453.97 671,436.46 12.00 2,452.22 - 84.44 7 10,200.00 65.05 336.52 8,834.13 3,334.50 734.81 5,978,513.14 671,402.65 12.00 2,520.35 96.00 10,224.89 64.99 339.82 8,844.64 3,355.44 726.42 5,978,533.88 671,393.78 12.00 2,542.68 91.87 8 10,300.00 64.22 329.87 8,876.92 3,416.76 697.65 5,978,594.53 671,363.62 12.00 2,610.18 -97.00 10,324.89 64.12 326.56 8,887.76 3,435.80 685.85 5,978,613.29 671,351.39 12.00 2,632.56 -92.73 9 10,366.34 63.70 332.08 8,906.00 3,467.79 666.86 5,978,644.84 671,331.68 12.00 2,669.76 96.00 TD III 10/7/2009 2:51:22PM Page 4 COMPASS 2003.16 Build 71 Bbl • BPPASSPORT • 0 ,, BAKIR Travelling Cylinder Report bP HUGHES Company' North America - ALASKA - BP LocatCo401i3inate Reference Well K-07 P Prudhoe Bay TVDYReteretuer K -07C @ 54.66ft (generic rig) Wince site: ' PB K Pad MD Referen 4:.` K -07C @ 54.66ft (generic rig) S11. Error 0• n 00ft North Reference: '; True Referece We0 , K -07 Survey Catculatton Method . . . ! Minimum Curvature Weil EnrOr : 0.00ft Output err are,at `° 1.00 sigma #Referent. Welipore Plan 3, K -07E Ct EDM .16 - Anc Prod - WH24P Refarent Plan 3 lffset.TVD Reference: Offset Datum Summary Refereince Offset centre ta No= 3o .flal I ensur ed Measured Ce , Distance t ltow tev 1lffarnin Sfte N Depth D epth D istance ( f rom F►1an Offset 1 Afell + 1Kelibore * Design r ` ,:(1) r (ft) (tY PB K Pad K-03 - K -03B - K -03B 9,290.00 11,275.00 1,053.42 583.86 572.44 Pass - Major Risk K -03 K- 03BPB1 - K -03B WP03 9,290.00 11,325.00 1,040.52 582.28 562.91 Pass - Major Risk K -06 - K -06 - K -06 9,295.13 9,150.00 623.13 602.74 476.50 Pass - Major Risk K-06 - K -06A - K -06A 9,310.00 9,575.00 741.05 549.84 332.08 Pass - Major Risk K-06 - K -06B - K -06B 9,270.00 9,100.00 692.89 555.13 499.68 Pass - Major Risk K -07 - K -07 - K -07 9,916.76 9,750.00 909.79 250.81 706.94 Pass - Major Risk K -07 - K -07A - K -07A 9,925.00 10,296.79 855.67 252.23 610.53 Pass - Major Risk K -07 - K- 07APB1 - K- 07APB1 9,916.76 9,750.00 909.79 250.81 706.94 Pass - Major Risk K -07 - K- 07APB2 - K- 07APB2 9,950.00 10,286.79 941.85 244.50 704.10 Pass - Major Risk K -07 - K -07B - K -07B 9,916.76 9,750.00 909.79 250.81 706.94 Pass - Major Risk K -07 - K -07C - K -07C 9,249.72 9,250.00 0.51 0.68 -0.05 FAIL - Major Risk K -07 - K -07D - K -07D 9,249.72 9,250.00 0.51 0.64 -0.05 FAIL - Major Risk K -08 - K -08 - K -08 Out of range K -08 - K -08A - K -08A Out of range K -08 - K -08A - Plan #3 Out of range K -08 - K -08B - K -08B Out of range 9 K -09 - K -09 - K -09 Out of range 9 K -09 - K- 09APB1 - K- 09APB1 Out of range K -09 - K -09B - K -09B Out of range K -09 - K- 09BPB1 - K- 09BPB1 Out of range K -09 - K -09C - K -09C Out of range K -09 - K -09C - Plan #4 Out of range K-10-K-10-K-10 Out of range K -10 - K -10A - K -10A Out of range K -10 - K- 10APB1 - K- 10APB1 Out of range K -10 - K- 10APB2 - K- 10APB2 Out of range K -10 - K- 10APB3 - K- 10APB3 Out of range K -10 - K -10B - K -10B Out of range K -11 - K -11 - K -11 Out of range K -12 - K -12 - K -12 Out of range K -12 - K -12A - K -12A Out of range K -12 - K- 12APB1 - K- 12APB1 Out of range K -12 - Plan K -12B - Plan #4 K -12B Out of range K -13 - Plan K -13A - K -13A wp01 10,000.00 10,475.00 530.47 413.64 242.93 Pass - Major Risk K- 19- K- 19 -K -19 Out of range K -19 - K -19A - K -19A Out of range K -19 - K -19AL1 - K -19AL1 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 10/7/2009 3:07:17PM Page 3 of 22 COMPASS 2003.16 Build 71 Azinuthclo T ewm WELLBORE DETAILS: Plan 3, K -07E REFERENCEINFO SIAI1CN FARE Project: Prudhoe Bay Magnetic Nore ns3 - -- Site: PB K Pad C (N /E) Reference: Well K -07, True North n 576 3 e 500292104505 V ertical (ND) Reference: Mean Sea Level 0 Well: K -07 sut„ym. ns�e.35nr BAKER Slot -(0.00N, 0.00E) • bp Wellbore: Plan 3,K -07E OD 10 .90 sc Reference N Plan: Plana K -07 /Plan 3, K-07E) Dale: UM200s Parent Wellbore: K -07C Section(VS) Referen ee Depth Reference K -07C @ 54 600 (gene c rig) ) ne 9,a ,eon Tie on MD: 9224.23 Dalwla0on Method: Minimum Curvature HUGHES 4350 WELL DETAILS: K -07 4200 Ground Level: 0.00 +N / -S +E/ -W Northing Easting La88ude Longitude Slot 4050 0.00 0.00 5975163.00 670744.00 70 °20'17.028N 148 °36'52.181W • K -07E Fau1t4 3900 SECTION DETAILS ANNOTATIONS ` , Sec MD Inc Azi ssTVD +N/ -S +E/ -W DLeg TFace VSec Taret Annotion 37� 1 9224.23 6.18 10.13 8343.34 2575.45 963.83 0.00 0.00 1748.49 TIP t I I I 7E K- 07/1-07 2 9230.00 6.12 7.36 8349.08 2576.06 963.93 5.22 - 102.01 1748.97 KOP 360Q 2 s K - 07X 07A2B1 3 9250.00 7.90 5.09 8368.93 2578.49 964.19 9.00 350.00 1750.94 Endof9deg /100ftDLS K - 0' 4 9404.89 62.00 355.91 8491.26 2663.75 959.93 35.00 350.00 1826.91 Endof 35 deg/ 100ft DLS 0 3451 - - 07tiF<ult2 , - 07 -07B 5 9874.89 65.13 326.56 8697.38 2847.16 896.87 12.00 270.00 2017.28 5 �- 6 9874.89 65.70 359.63 8697.38 3060.62 832.15 12.00 96.00 2234.50 0 ■ ■01,.� 4.50 6 0 7 10124.89 65.67 326.63 8844.64 3274.56 767.27 12.00 263.00 2452.22 7 3311 ■� ■� -� 1 ! / • 8 10224.89 64.99 339.82 8844.64 3355.44 726.42 12.00 96.00 2542.68 8 �"' 9 10324.89 64.12 326.56 8887.76 3435.80 685.85 12.00 263.00 2632.56 9 "3150 / 10 10366.34 63.70 332.08 8906.00 3467.79 666.86 12.00 96.00 2669.76 TD � M EM K_ - r 3131313 1 Fault ■■ ■■��imM 28 r. 11111100rtDM'- -' 2700 EliEllirlikrabo....- 2551 I, U US' 2400 ■■ I: - ' K- 1740 -0713 2250 r. F 2100 / X50 -300 -150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 West( -) /East( +) (150 ft/in) IP 8415 ■■ ■■■■■ ■ ■■■■■.! ■m 11 ' 1�1■■■■■■■■■■■■■■■■■ ■ ■■ n 8471 ■ ■■■ ■ ■ ■■■■ ■ ■■■�i 11 i ��■■■■■■■ ■■■■■■ ■■■ ■ ■ ■■ • 8525 ■ ■■ ■ ■ ■ ■■■■ ■■■■,®III■.I■■■■■ ■■■ ■ ■ ■ ■ ■ ■ ■ ■ ■■ ■■ tin 85:1 ■■■■■■■■■■■ ■ ■■1i■',mI;■ ■■ ■■■■■■■■ ■ ■ ■■ ■■■ ■i A 8535 ■ ■■■■■■■■■■ ■ ■■I,i uu�i�►'; ■■■■■■ ■■■■■■■■ ■■■ • • . ■■■■■■■■//IIU�■■■■■■■■■■■■■■■■■ • 8 ;45 � :■ ■ ■■■■■■■■ ■%■■■■ ■I�■■\■IIIIIIIM ■■■■■■■■ 8:11 ■ ■ ■ ■ ■ ■ ■ ■ ■ ■■ ■■■ ■■■ It ■ ■ ■■ 44 41 ■ ■■ ! ■ ■ ■ ■■ 1111 ■■ ■1111■ ■ ■■ ■■■ l® ■ ■■■ ■ ■ ■►R ■E ■ ■ ■ ■ ■ ■■■ 89 ■■■■■■■■■■■■■r■ ■ llIEE7: K 0 ■. ■ ■■', ■ ■ ■ ■■ Mean 8965 E■■■■■■■■■■■■■■■■ ■ ■ ■■ ■ ■ ■■■■ ■■II■ ■ ■■■ 1045 1100 1155 1210 1265 1320 1375 1430 1485 1540 1595 1650 1705 1760 1815 1870 1925 1980 2035 2090 2145 2200 2255 2310 2365 2420 2475 2530 2585 2640 2695 2750 2805 2860 2915 2970 3025 3080 3135 Vertical Section at 330.00° (55 ft/in) EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 - rr 1 L 1 AEO2 , i • 6000000 AEO 1 5950000 -� Li K -07D 5900000 40 CFR 147.102 (b)(3) • • • 5850000 400000 500000 600000 700000 800000 Alaska Department of Natural sources Land Administration System • Page 1 of/ Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources ra Alaska DNR Case Summary File Type: ADL File Number: 28300 Printable Case File Summary See Township, Range, Section and Acreage? Yes No ( New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28300 \la Search for Status Plat Updates As of 10/26/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 014E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 014E Section: 28 Section Acres: 640 Meridian: U Township: 012N Range: 014E Section: 33 Section Acres: 640 Meridian: U Township: 012N Range: 014E Section: 34 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -121 012N- 014E -UM 27, 28, 33, 34 2560.00 10 -01 -1998 * * * MIDNIGHT SUN PA LEGAL DESCRIPTION PRUDHOE BAY UNIT TRACT 27 (PARTIAL) http: / /dnr.alaska.gov /projects /las /Case Summary.cfin ?FileType= ADL &FileNumber = 283... 10/26/2009 Alaska Department of Natural1sources Land Administration System • Page 1 ofi/ Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28303 8 Printable Case File Summary See Township, Range, Section and Acreage? New Search [!) Yes 0 No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28303 `' Search for Status Plat Updates As of 10/26/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 03 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 04 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 09 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 10 Section Acres: 640 Legal Description 05 -28 -1965 * ** SALE NOTICE LEGAL DESCRIPTION * ** C14-124 11 N 14E UM 3, 4, 9,10 2560.00 U- 3- 7 End of Case Summary Last updated on 10/26/2009. http: / /dnr.alaska.gov /projects /las /Case_Summary.cfm ?FileType= ADL &FileNumber = 283... 10/26/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME R- 07,E PTD# ,.2O9 /0.?J r Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: p.e"..444 VY POOL: ' 4'e' ' ?TAY a/1 Circle 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 perforate and 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: 1/11/2008 I WELL PERMIT CHECKLIST & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT K -07E Program DEV _ Well bore seg ❑ PTD#: 2091270 Company BP EXPLORATION (ALASKA) INC _ Initial Class/Type _ DEV / PEND GeoArea 890 _ Unit 11650 On /Off Shore On Annular Disposal ❑ Administration '1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes ,4 Well located in a defined pool Yes '5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. '8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 10/26/2009 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by injection Order # (put IO# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 1 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven, gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided NA - conductor set in K -07D Engineering 19 Surface casing - protects all known USDWS NA Surface casing set and cemented in K -07D 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set in K -07D 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in -K -07D 22 CMT will cover all knownproductive horizons Yes Liner will be cemented 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits, All waste to approved disposal well. 25 If a re-drill, has a 10 -403 for abandonment been approved Yes 309 -355 P & A sundry K -07D 26 Adequate wellbore separationproposed Yes Proximity analysis performed. 27 If diverter required, does it meet regulations NA Wellhead and BOP stack in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Formation pressure = 3289 psi (7.2 ppg EMW) Will drill with 8.6 ppg mud GLS 10/28/2009 29 BOPES,do they meet regulation . Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2409 psi Will test BOP'S to 3500 psi._ 3 • 1 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 1 33 Is presence of H2S gas probable _ Yes - H2S present on K pad. Rig has sensors and alarms. 134 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No - _ Max level H2S on pad is_20ppm for well K-03B (3/16/08). Geology .36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 10/26/2009 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA _i Geologic Engineering P ; y, Date: Date ►. _ Date Commissioner: Co mission r: Co r � $& r;. / fir /0 -30 - ey • S Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process • but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I tapescan.txt * * ** REEL HEADER * * ** MWD 10/05/12 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 10/02/14 3002527 01 3" CTK * ** LIS COMMENT RECORD * ** 11111111 11111111111 Remark File Version 1.000 111111 1111111111111 Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame well Information Block # MNEM.UNIT Data Type Information STRT.FT 9119.0000: Starting Depth STOP.FT 10301.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K -07E FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 20' 17.028 "N 148 deg 36' 52.181 "w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 14 Mar 2010 API . API NUMBER: 500292104505 Parameter Information Block #MNEM.UNIT Value Description SECT. 04 Section TOWN.N T11N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation of Perm. Datum LMF . DF Log Measured from FAPD.F 54.66 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 54.66 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 .9001 -cam 19a I • tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths ( TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting Sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 18 Feb 2010 per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from K -07C through a milled window in a 4 1/2 inch liner. Top of window 9230 ft.MD (8348.5 ft.TVDSS) Bottom of window 9238 ft.MD (8356.6 ft.TvDSS) (9) Tied to K -07C at 9224 feet MD (8342.9 feet TVDSS). (10) Baker Hughes INTEQ run 11 was an open hole sidetrack at 9606 feet MD (8587.5 feet TVDSS). (11) Baker Hughes INTEQ runs 4 through 10 were used to drill K- 07EPB1. (12) The interval from 10274 ft to 10301 ft MD (8936.4 ft. to 8953.2 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (oHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9121.56, 9123.4, ! 1.84766 9128.95, 9131.2, ! 2.25781 9135.1, 9135.72, ! 0.616211 9140.44, 9141.26, ! 0.821289 9148.85, 9149.47, ! 0.616211 9150.91, 9152.34, ! 1.43652 9155.63, 9156.65, ! 1.02637 9161.17, 9161.58, ! 0.411133 9165.28, 9165.89, ! 0.615234 9168.35, 9169.59, ! 1.23242 9170.82, 9171.43, ! 0.615234 9172.31, 9172.92, ! 0.615234 9178.88, 9178.47, ! - 0.410156 9187.09, 9187.29, ! 0.206055 9190.99, 9191.4, ! 0.410156 9193.04, 9194.07, ! 1.02637 9201.45, 9203.71, ! 2.25781 9208.84, 9211.31, ! 2.46289 9212.33, 9215.21, ! 2.87305 9216.03, 9218.29, ! 2.25781 9222.51, 9225.59, ! 3.07812 9228.88, 9232.98, . 4.10547 Page 2 . 4 tapescan.txt 9232.37, 9236.47, ! 4.10547 9234.62, 9237.7, ! 3.0791 9240.17, 9244.07, ! 3.90039 9243.04, 9246.12, ! 3.07812 9243.86, 9247.14, ! 3.28418 9251.66, 9253.51, ! 1.84766 9253.3, 9257.2, ! 3.89941 9256.38, 9259.66, ! 3.28418 9265.82, 9269.52, ! 3.69434 9269.93, 9273.42, ! 3.48926 9274.44, 9278.14, ! 3.69434 9277.32, 9281.01, ! 3.69434 9284.01, 9288.11, ! 4.10449 9288.32, 9292.22, ! 3.89941 9296.53, 9301.25, ! 4.7207 9299.81, 9303.71, ! 3.89941 9302.07, 9305.97, ! 3.89941 9303.51, 9307.41, ! 3.89941 9313.33, 9316.62, ! 3.28418 9319.49, 9322.98, ! 3.48926 9321.96, 9325.85, ! 3.89941 9324.62, 9328.11, ! 3.48926 9333.86, 9336.94, ! 3.0791 9338.17, 9341.25, ! 3.0791 9338.99, 9343.1, ! 4.10449 9342.28, 9346.38, ! 4.10449 9347.41, 9350.28, ! 2.87402 9350.49, 9353.77, ! 3.28418 9352.74, 9357.46, ! 4.7207 9354.59, 9358.9, ! 4.30957 9357.87, 9361.57, ! 3.69531 9362.8, 9366.5, ! 3.69434 9365.44, 9368.93, ! 3.48926 9369.96, 9374.07, ! 4.10547 9393.8, 9397.91, ! 4.10449 9423.56, 9426.64, ! 3.07812 9426.85, 9429.52, ! 2.66797 9435.88, 9438.34, ! 2.46387 9451.96, 9454.21, ! 2.25781 9464.89, 9467.96, ! 3.0791 9478.2, 9481.08, ! 2.87305 9485.39, 9487.64, ! 2.25781 9496.68, 9498.73, ! 2.05273 9504.89, 9507.35, ! 2.46289 9507.35, 9510.02, ! 2.66895 9565.76, 9568.84, ! 3.0791 9572.54, 9574.18, ! 1.6416 9576.85, 9577.05, ! 0.205078 9582.8, 9584.24, ! 1.43652 9584.44, 9586.29, ! 1.84766 9589.57, 9592.65, ! 3.07812 9594.77, 9597.64, ! 2.87305 9599.9, 9602.78, ! 2.87402 9602.78, 9605.85, ! 3.07812 9609.34, 9611.19, ! 1.84766 9624.16, 9623.95, ! - 0.205078 9634.42, 9635.65, ! 1.23145 9642.22, 9643.65, ! 1.43652 9661.72, 9662.95, ! 1.23145 9665.82, 9668.08, ! 2.25781 9668.49, 9670.95, ! 2.46289 9676.08, 9678.96, ! 2.87305 9678.93, 9680.78, ! 1.84766 Page 3 I • tapescan.txt 9685.91, 9688.38, ! 2.46289 9691.45, 9692.69, ! 1.23145 9703.77, 9706.85, ! 3.0791 9707.46, 9709.11, ! 1.64258 9720.11, 9725.24, ! 5.13184 9727.09, 9730.37, ! 3.28418 9732.01, 9735.91, ! 3.89941 9739.61, 9743.3, ! 3.69531 9769.96, 9773.45, ! 3.48926 9775.5, 9777.96, ! 2.46289 9778.38, 9781.86, ! 3.48926 9783.3, 9785.35, ! 2.05176 9785.15, 9787.41, ! 2.25781 9786.59, 9788.84, ! 2.25781 9787.82, 9790.9, ! 3.07812 9791.92, 9794.18, ! 2.25781 9795.41, 9798.9, ! 3.48926 9812.98, 9816.06, ! 3.0791 9834.94, 9836.38, ! 1.43652 9843.97, 9846.85, ! 2.87402 9849.11, 9851.36, ! 2.25684 9856.21, 9858.67, ! 2.46289 9863.39, 9865.24, ! 1.84766 9868.73, 9870.37, ! 1.6416 9874.68, 9877.14, ! 2.46289 9886.59, 9888.64, ! 2.05176 9902.63, 9905.91, ! 3.28418 9905.91, 9909.2, ! 3.28418 9908.79, 9911.66, ! 2.87305 9913.51, 9916.59, ! 3.0791 9916.38, 9919.05, ! 2.66895 9917.41, 9920.69, ! 3.28418 9927.03, 9929.49, ! 2.46289 9929.49, 9931.75, ! 2.25781 9938.52, 9942.01, ! 3.48926 9959.05, 9963.97, ! 4.92578 9965.21, 9968.49, ! 3.28418 9968.08, 9971.16, ! 3.07812 9981.49, 9983.54, ! 2.05273 9984.36, 9986.21, ! 1.84766 9988.47, 9990.72, ! 2.25781 9991.96, 9994.42, ! 2.46289 10002.6, 10004.9, ! 2.25781 10007.3, 10010, ! 2.66895 10013.1, 10015.6, ! 2.46387 10018.4, 10021.1, ! 2.66895 10020.3, 10022.9, ! 2.66797 10026.4, 10027.7, ! 1.23145 10042.4, 10043.6, ! 1.23145 10065.6, 10066.6, ! 1.02637 10076.4, 10077.1, ! 0.616211 10079.9, 10081.4, ! 1.43652 10083.2, 10083.6, ! 0.410156 10087.7, 10090, ! 2.25781 10091, 10093, ! 2.05273 10097.6, 10098.2, ! 0.615234 10101.5, 10102.9, ! 1.43652 10105.1, 10105.1, ! 0 10109, 10110.1, ! 1.02637 10116.2, 10117.3, ! 1.02637 10121.4, 10122, ! 0.616211 10129.5, 10131.6, ! 2.05176 10132.4, 10134.1, ! 1.64258 Page 4 S tapescan.txt 10134.9, 10136.1, ! 1.23145 10136.5, 10138, ! 1.43652 10143.7, 10145.4, ! 1.6416 10151.9, 10152.9, ! 1.02637 10164.9, 10165.1, ! 0.205078 10167.5, 10168.1, ! 0.615234 10170.8, 10169.8, ! - 1.02539 10172.5, 10171.6, ! - 0.821289 10175.1, 10175.3, ! 0.205078 10192.6, 10194.4, ! 1.84668 10194.4, 10196.1, ! 1.64258 10199.3, 10200.2, ! 0.821289 10201.4, 10202.8, ! 1.4375 10204.9, 10206.7, ! 1.84766 10207.3, 10209, ! 1.64258 10211.5, 10213.3, ! 1.84766 10214.9, 10216.6, ! 1.6416 10224.4, 10225.2, ! 0.821289 10225.6, 10226.8, ! 1.23145 10229.3, 10230.7, ! 1.43652 10236.3, 10235.8, ! - 0.411133 10241.2, 10241.8, ! 0.616211 10245.5, 10247.1, ! 1.6416 10258, 10259, ! 1.02637 10259.9, 10262.1, ! 2.25781 10264.2, 10266.4, ! 2.25781 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 250 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD *** 111111111 Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 12 Feb 2010 per Doug stoner with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Page 5 . i Ilk tapescan.txt Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 66 Tape File Start Depth = 9119.000000 Tape File End Depth = 10303.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ° * ** FILE TRAILER * * ** Tape Subfile: 2 79 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** 1!111111111 ,1111II Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Loci Depth Scale Units: Feet Frame spacing: 0.250000 Page 6 tapescan.txt Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples Units size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 132 Tape File Start Depth = 9117.000000 Tape File End Depth = 10301.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 145 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes ° * ** TAPE TRAILER * * ** MWD 10/02/14 3002527 01 * ** REEL TRAILER * * ** MWD 10/05/12 BHI 01 Page 7 r . 410 411 tapescan.txt Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9119.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9119.5000 72.4615 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10303.0000 - 999.2500 70.9598 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9119.000000 Tape File End Depth = 10303.000000 Tape File Level spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: Lis DEPTH GR ROP RAD RAS RPD RPS 9117.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9117.2500 74.6000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10301.0000 - 999.2500 71.2000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9117.000000 Tape File End Depth = 10301.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS Page 8 • tapescan.txt * * ** REEL HEADER * * ** MWD 10/05/18 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * ** MWD 10/02/12 3002527 01 3" CTK * ** LIS COMMENT RECORD * ** Remark File Version 1.000 1 1 1!1 1111 ! 111111111 Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9119.0000: Starting Depth STOP.FT 10441.0000: Ending Depth STEP.FT 0.5000: Level spacing NULL. - 999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K- 07EPB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 20' 17.028 "N 148 deg 36' 52.181 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 11 Feb 2010 API . API NUMBER: 500292104573 -Parameter Information Block # MNEM.UNIT Value Description SECT. 04 Section TOWN.N T11N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 54.66 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 54.66 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 • S tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths ( TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL above the Kick off Point of 9604 ft MD dated 12 Feb 2010 per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from K -07C through a milled window in a 4 1/2 inch liner. Top of window 9230 ft.MD (8348.5 ft.TVDSS) Bottom of window 9238 ft.MD (8356.6 ft.TVDSS) (9) Tied to K -07C at 9224 feet MD (8342.9 feet TvDSS). (10) The interval from 10400 ft to 10440 ft MD (8914.7 ft. to 8930.3 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP_AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9121.56, 9123.4, ! 1.84766 9128.95, 9131.2, ! 2.25781 9135.1, 9135.72, ! 0.616211 9140.44, 9141.26, ! 0.821289 9145.85, 9146.68, ! 0.821289 9148.85, 9149.47, ! 0.616211 9150.91, 9152.34, ! 1.43652 9155.63, 9156.65, ! 1.02637 9161.17, 9161.58, ! 0.411133 9165.28, 9165.89, ! 0.615234 9168.35, 9169.59, ! 1.23242 9170.82, 9171.43, ! 0.615234 9172.31, 9172.92, ! 0.615234 9178.88, 9178.47, ! - 0.410156 9187.09, 9187.29, ! 0.206055 9190.99, 9191.4, ! 0.410156 9193.04, 9194.07, ! 1.02637 9201.45, 9203.71, ! 2.25781 9208.84, 9211.31, ! 2.46289 9212.33, 9215.21, ! 2.87305 9216.03, 9218.29, ! 2.25781 9222.51, 9225.59, ! 3.07812 9228.88, 9232.98, ! 4.10547 9232.37, 9236.47, ! 4.10547 Page 2 • . tapescan.txt 9234.62, 9237.7, ! 3.0791 9240.17, 9244.07, ! 3.90039 9243.04, 9246.12, ! 3.07812 9243.86, 9247.14, ! 3.28418 9251.66, 9253.51, ! 1.84766 9253.3, 9257.2, ! 3.89941 9256.38, 9259.66, ! 3.28418 9262.13, 9264.18, ! 2.05273 9265.82, 9269.52, ! 3.69434 9269.93, 9273.42, ! 3.48926 9274.44, 9278.14, ! 3.69434 9277.32, 9281.01, ! 3.69434 9284.01, 9288.11, ! 4.10449 9288.32, 9292.22, ! 3.89941 9296.53, 9301.25, ! 4.7207 9299.81, 9303.71, ! 3.89941 9302.07, 9305.97, ! 3.89941 9303.51, 9307.41, ! 3.89941 9313.33, 9316.62, ! 3.28418 9319.49, 9322.98, ! 3.48926 9321.96, 9325.85, ! 3.89941 9324.62, 9328.11, ! 3.48926 9333.86, 9336.94, ! 3.0791 9338.17, 9341.25, ! 3.0791 9338.99, 9343.1, ! 4.10449 9342.28, 9346.38, ! 4.10449 9347.41, 9350.28, ! 2.87402 9350.49, 9353.77, ! 3.28418 9352.74, 9357.46, ! 4.7207 9354.59, 9358.9, ! 4.30957 9357.87, 9361.57, ! 3.69531 9362.8, 9366.5, ! 3.69434 9365.44, 9368.93, ! 3.48926 9369.96, 9374.07, ! 4.10547 9382.13, 9387.05, ! 4.92676 9393.8, 9397.91, ! 4.10449 9423.56, 9426.64, ! 3.07812 9426.85, 9429.52, ! 2.66797 9435.88, 9438.34, ! 2.46387 9451.96, 9454.21, ! 2.25781 9464.89, 9467.96, ! 3.0791 9478.2, 9481.08, ! 2.87305 9485.39, 9487.64, ! 2.25781 9496.68, 9498.73, ! 2.05273 9504.89, 9507.35, ! 2.46289 9507.35, 9510.02, ! 2.66895 9565.76, 9568.84, ! 3.0791 9572.54, 9574.18, ! 1.6416 9576.85, 9577.05, ! 0.205078 9582.8, 9584.24, ! 1.43652 9584.44, 9586.29, ! 1.84766 9589.57, 9592.65, ! 3.07812 9594.77, 9597.64, ! 2.87305 9599.9, 9602.78, ! 2.87402 9602.78, 9605.85, ! 3.07812 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 153 records... Minimum record length: 10 bytes Maximum record length: 132 bytes Page 3 • • tapescan.txt * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** 11111 11111111111111 Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL above the Kick off Point of 9604 ft MD dated 12 Feb 2010 per Doug Stoner with BP Exploration (Alaska), In * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 74 Tape File Start Depth = 9119.000000 Tape File End Depth = 10444.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Page 4 • tapescan.txt Tape subfile: 2 87 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD *** 1111111111111 Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 148 Tape File Start Depth = 9117.000000 Tape File End Depth = 10441.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Page 5 4► • tapescan.txt Tape Subfile: 3 161 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 10/02/12 3002527 01 * * ** REEL TRAILER * * ** MWD 10/05/18 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9119.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9119.5000 72.4615 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10444.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9119.000000 Tape File End Depth = 10444.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS Page 6 i S tapescan.txt RPD RPS 9117.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9117.2500 74.6000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10441.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9117.000000 Tape File End Depth = 10441.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS • Page 7
