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®rganlz®ng (done) RE /~N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: .o..cea iiuimimiuuu DI TAL DATA Diskettes, No. ^ Other, No/Type: ae,~,~~„aaa IIIIIIIIINIIIIIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: pl, ~ /s/ r r Pro"ect Proofin III II'I~IIIIII II III I g BY: Maria Date: ~., ~ / D /s/ Scannin Preparation ~_ x 30 = 3© + ~_ =TOTAL PAGES ~ / g (Count does not include cover sheet) BY: Maria Date: al /s/ Production Scanning """"" "" " "' Stage 1 Page Count from Scanned File: ~~ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: o / ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ nnin is com lete at this Dint unless rescanning is required. II I II II I) I II II I I III Sca g p P r~escanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III Ililll III Ilil III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED .5KA OIL AND GAS CONSERVATION Cl IISSION REPORT OF SUNDRY WELL OPERATIONS JUN 1 7 2014 1. Operations Performed: AOGCc D Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver 0 Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other ❑Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 208-024 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-21842-02-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 028307 PBU 15-25B 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Prudhoe Bay Field/Prudhoe Bay Oil Pool 11. Present well condition summary: Total depth: measured 11738' feet Plugs:(measured) None feet true vertical 8755' feet Junk:(measured) None feet Effective depth: measured 11619' feet Packer: (measured) 8334', 8597' feet true vertical 8779' feet Packer: (true vertical) 7805',8029' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 3521' 10-3/4" 33'-3521' 33'-3521' 3580/5210 2090/2480 Intermediate 8935' 7-5/8" 33'-8935' 33'-8313' 6890 4790 Production Liner 416' 5-1/2" 8597-9013' 8029'-8377' 7740 6280 Liner 3193' 2-3/8" 8465'- 11658' 7916'-8773' 11200 11780 Perforation Depth: Measured Depth: 9890'- 11610' feet True Vertical Depth: 8821'-8780' feet Tubing(size,grade,measured and true vertical depth): 3-1/2",9.2# 13Cr85/L-80 8718' 8131' Packers and SSSV(type,measured and true vertical depth): 7-5/8"x 3-1/2"HES TNT Packer; 8334'; 7805'; 7-5/8"TIW SSBB Packer 8597' 8029' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: SCANNED JUL 1 02014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 80 2500 Subsequent to operation: 0 0 0 20 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: 0 Oil 0 Gas 0 WDSPL 0 Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Contact: Carolyn Kirchner,564-4190 Email: Carolyn.Kirchner@bp.com N/A Printed Name: Joe Lastufka Title: Drilling Technologist /- Signature: • . Phone: 564-4091 Date: F ,113/14 Form 10-404 Revised 10/2012 Submit Original Only , Ettr, , vi-r 6/C 9`!zf R@CMS JUN 18 2 4 15-25B, Well History (Pre-Rig Workover) Date Summary 03/27/14 T/I/O=SSV/0/0,Temp: SI, PPPOT-T(PASS), PPPOT-IC(PASS) Pre RWO. PPPOT-T: Stung into test void(100 psi), bled void to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5,000 psi for 30 minute test. Lost 50 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void (0+psi), bled void to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3,500 psi for 30 minute test. Lost 0 psi in 30 minute test. (PASS) Bled void to 0 psi. 04/04/14 RIH WITH TUBING PUNCH, SHOT TUBING PUNCH HOLES @ 8396'-8398'. CURRENTLY RIH W/ RCT TO CUT TBG. 04/05/14 CUT TUBING WITH 2"RCT CUTTER AT 8426'MD. 05/07/14 T/I/O=59/0/0(Circ-out) Rig to In and out skid. Pump 5 bbls neat meth followed by 720 bbls 8.5 seawater down TBG taking returns up IA and over to well 07-31 FL. SD/Pump 107 bbls diesel down IA taking returns up TBG and over to well 07-31 FL. SD/U-Tube Tx IA. FP surface lines with 3 bbls diesel. RDMO. FWHP=0/0/0 wing=shut/swab=shut/ssv=shut/master=open/IA and OA open to gauges. Operator notified.Well 07-31 FL is freeze protected with 5 bbls neat meth followed by 39 bbls dead crude. 05/13/14 T/I/0=VAC/VAC/VAC. ND upper tree, NU dry hole, PB I/A an O/A valves set BPV pre rig. see log Final T/I/O=0/0/0. Page 1 of 1 North America-ALASKA-BP Page 1 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/16/2014 12:00 - 13:00 1.00 RIGD P PRE RIG DOWN RIG FLOOR. -PJSM. -RIG DOWN RIG FLOOR FOR SKIDDING OPERATIONS. 13:00 - 14:00 1.00 RIGD P PRE SKID RIG FLOOR INTO MOVING POSITION. 14:00 - 17:00 3.00 MOB P PRE MOVE RIG OFF OF WELL 14-37. -PJSM LED BY DOYON RIG MANAGER WITH INPUT ON BP SAFETY POINTS BY BP WELLSITE LEADER. -SET MATS FOR MOVING RIG OFF OF WELL. -CONTACT DSO FOR WITNESS OF MOVING OFF. -ESTABLISH COMMUNICATIONS VIA RADIO WITH ALL HANDS. -TEST RIG MOVING SYSTEM EMERGENCY SHUTDOWN SWITCH.GOOD TEST. -MOVE RIG OFF OF WELL 14-37. 17:00 - 18:00 1.00 MOB P PRE MOVE RIG OFF OF PAD TO SPINE ROAD. *AOGCC REP CHUCK SHEVE WAIVED WITNESS TO UPCOMING BOP TEST. 18:00 - 22:00 4.00 MOB P PRE MOVE RIG FROM DS-14 ACCESS ROAD ONTO SPINE ROAD,TO OXBOW ROAD,TO DS-15 ACCESS ROAD TO DS-15. -SPOT RIG ON PAD. 22:00 - 00:00 2.00 MOB P PRE SPOT RIG OVER WELL 15-25B. -PJSM LED BY DOYON TOUR PUSHER WITH INPUT ON BP SAFETY POINTS BY BP WELLSITE LEADER. -TEST RIG MOVING SYSTEM EMERGENCY SHUTDOWN SWITCH. -ESTABLISH COMMUNICATIONS VIA RADIO WITH ALL HANDS. -CHECK PRESSURE ON WELLHEAD- TUBING=0 PSI,IA=0 PSI,OA=0 PSI. -SPOT RIG OVER WELL 15-25B. 5/17/2014 00:00 - 01:30 1.50 MOB P PRE SPOT RIG OVER WELL 15-25B. -PJSM LED BY DOYON TOUR PUSHER WITH INPUT ON BP SAFETY POINTS BY BP WELLSITE LEADER. -CONTACT DSO FOR WITNESS OF MOVING OVER. -VERIFY NO PRESSURE ON WELL AND ALL VALVES ARE SHUT IN. -ESTABLISH COMMUNICATIONS VIA RADIO WITH ALL HANDS. -FUNCTION ESD ON MOVING SYSTEM BEFORE FINAL PLACEMENT OF RIG.MOVING SYSTEM SHUT DOWN. -SPOT RIG OVER WELL 15-25B. 01:30 - 02:00 0.50 MOB P PRE SKID RIG TO DRILLING POSITION. -PJSM. -SKID RIG OVER TO DRILLING POSITION. II II Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 2 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:30 2.50 RIGU P PRE RIG UP RIG FLOOR. -PJSM. -RIG UP AIR,STEAM AND WATER TO RIG FLOOR. -RIG UP CHOKE LINE,HIGH PRESSURE LINES,AND MUD BUCKET ON RIG FLOOR. -RIG UP BEAVER SLIDE. -SKID CONVEYOR OUT AND SPOT ROCKWASHER. -SPOT LUNCH SHACK AND FUEL TRAILER. -PREP PITS FOR TAKING ON SEAWATER. *SIMOPS-HARDLINE CREW RIGGING UP HARDLINE AND TEST HARDLINE TO 250 PSI/3500 PSI FOR 5 CHARTED MINUTES EACH. **ACCEPT RIG AT 0430 HRS 05/17/2014 04:30 - 05:00 0.50 RIGU P PRE RIG EVACUATION DRILL AND AAR. 05:00 - 06:30 1.50 RIGU P PRE RIG UP TO CIRCULATE OUT FREEZE PROTECT. -PJSM. -RIG UP LINES TO SQUEEZE MANIFOLD AND IA FOR CIRCULATING. -TAKE ON FLUID TO PITS. -RUN AND HOOK UP GAITRONICS LINE TO WSL OFFICE. 06:30 - 08:00 1.50 RIGU P PRE RIG UP AND TEST LUBRICATOR TO PULL BACK PRESSURE VALVE. -PJSM. -PICK UP AND RIG UP LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH-GOOD TEST. 08:00 09:00 1.00 RIGU P PRE PULL BACK PRESSURE VALVE. -PULL BPV. -RIG DOWN LUBRICATOR. 09:00 - 10:00 1.00 BOPSUR P PRE RIG UP TO CURCULATE OUT FREEZE PROTECT. -RIG UP LINES TO CIRCULATING MANIFOLD FROM TUBING. -TEST RIG LINES TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH ON CHART-GOOD TEST. 10:00 - 11:00 1.00 BOPSUR P PRE CIRCULATE OUT FREEZE PROTECT. -PJSM. -CIRCULATE 30 BBLS SEAWATER DOWN IA TAKING RETURNS THRU TUBING BACK TO FLOWBACK TANK. -CIRCULATE AT 8 BBLS/MIN @ 2450 PSI. -STOP PUMPS AND REVERSE CIRCULATION PATH. -CIRCULATE 150 BBLS OF SEAWATER DOWN TUBING TAKING RETURNS THRU IA BACK TO FLOWBACK TANK. -CIRCULATE AT 8 BBLS/MIN @ 2460 PSI. 11:00 - 11 30 0.50 BOPSUR P PRE FLOWCHECK WELL. -FLOWCHECK WELL FOR 30 MINUTES-WELL STATIC. Printed 5/27/2014 2:01:31PM • North America-ALASKA-BP Page 3 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table©62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:00 0.50 BOPSUR P PRE BLOW DOWN LINES. -PJSM. -BLOW DOWN ALL LINES. -RIG DOWN LINE FROM TUBING TO MANIFOLD. *SIMOPS-TEST AND CALIBRATE GAS ALARMS. 12:00 - 16:30 4.50 BOPSUR P PRE 'INSTALL BPV AND TEST. -PJSM. -RIG UP LUBRICATOR AT QUICK TEST SUB AND TEST QTS. -INSTALL BACK PRESSURE VALVE. -PUMP 9 BBLS TO TEST FROM BELOW. -OBSERVED PRESSURE ON TUBING. -BLEED PRESSURE OFF OF TUBING TO SEE IF BPV POPPET WOULD SEAL-FAILED. -BLEED PRESSURE OFF OF IAAND TUBING TO PULL BPV. -PULL BPV AND INSPECTED.FOUND BPV DID NOT SEAT.SHEAR PINS SHEARED BUT VALVE DID NOT SET. -REPLACED BPV WITH NEW BPV. -INSTALLED BPV. -PRESSURE UP TO 3000 ON IA TO TEST FROM BELOW,PRESSURE BLED OFF-BUT NO PRESSURE ON TUBING. -PERFORMED ROLLING TEST AT.2 BBL/MIN AND HELD AT 3000 PSI FOR 5 MINUTES-GOOD TEST. 16:30 - 17:00 0.50 BOPSUR P PRE RIG EVACUATION DRILL AND AAR. -TESTED ESD SYSTEM ON RIG-GOOD TEST. 17:00 - 18:00 1.00 BOPSUR P PRE RIG DOWN BACK PRESSURE LUBRICATOR. -PJSM. -BLOW DOWN ALL LINES. -RIG DOWN BACK PRESSURE LUBRICATOR. -BRING LUBRICATOR TO GROUND THRU BEAVERSLIDE AND LOAD ONTO TRUCK. 18:00 - 20:00 2.00 BOPSUR P PRE NIPPLE DOWN DRYHOLE TREE. -PJSM. -NIPPLE DOWN TREE. -INSTALL BLANKING PLUG-INSTALLED WITH 5 TURNS TO LEFT. -RUNNING TOOL INTO BLANKING PLUG IS 6-3/4 TURNS TO LEFT. -CROSSOVER FOR BLANKING PLUG IS 8-1/2 TURNS TO RIGHT(TORQUED CONNECTION). 20:00 - 23:00 3.00 BOPSUR P PRE NIPPLE UP BOP STACK EQUIPMENT. -PJSM. -NIPPLE UP BOP STACK. -INSTALL TURNBUCKLES,RISER,FLOWLINE, BLEEDOFF LINE,HOLE FILL LINE. -WRAP FLOWLINE COVERS WITH ENVIROWRAP. -RECORD RKB'S. -INSTALL MOUSEHOLES. -BREAK DOWN SAFETY JOINT. 23:00 - 00:00 1.00 BOPSUR P PRE RIG UP TO TEST BOP EQUIPMENT. -PJSM. -RIG UP TEST EQUIPMENT TO TEST BOP EQUIPMENT. Printed 5/27/2014 2:01:31PM • North America-ALASKA-BP Page 4 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table©62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 5/18/2014 00:00 - 01:00 1.00 BOPSUR P PRE RIG UP TO TEST BOPE EQUIPMENT. -PJSM. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. PERFORM D-2 DRILL-ALL HANDS RESPONDED IN GOOD TIME. -FILL GAS BUSTER-6 BBLS TO FILL. -RIG UP TO TEST BOPE EQUIPMENT. 01:00 - 06:30 5.50 BOPSUR P PRE TEST BOPE EQUIPMENT. -TEST BOPE EQUIPMENT WITH 3-1/2"AND 4" TEST JOINTS. -TEST BOPE TO 250 PSI LOW/3,500 PSI HIGH FOR 5 MINUTES EACH. -ALL TESTS CHARTED-SEE ATTACHED BOP TEST CHARTS. -TEST WITNESS WAIVED BY AOGCC REP. CHUCK SHEVE. 06:30 - 07:00 0.50 BOPSUR P PRE RIG DOWN BOPE TEST EQUIPMENT. -PJSM,VOID BOPE STACK OF TEST WATER AND BLOW DOWN ALL SURFACE LINES. -ALIGN AND CONFIRM CHOKE ALIGNMENT FOR WELL OPERATIONS. -BREAK OUT ALL CROSSOVERS USED FOR TESTING. *DISCUSS WITH FIELD SUPT AND ODE OF NOT BEING ABLE TO PULL 10.09"BLANKING PLUG ASSEMBLY THROUGH LUBRICATOR. 07:00 - 09:30 2.50 BOPSUR P PRE INSTALL LUBRICATOR ASSEMBLY FOR PULLING BPV. -PJSM,PICK UP AND INSTALL DUTCH RISER INTO BOPE STACK AND CLOSE ANNULAR PREVENTER. -PICK UP AND INSTALL DSM LUBRICATOR ASSEMBLY TO DUTCH RISER WITH BPV RETRIEVING TOOL. 09:30 - 10:00 0.50 BOPSUR P PRE PRESSURE TEST LUBRICATOR ASSEMBLY. -PJSM,PURGE AND TEST LUBRICATOR ASSEMBLY T/250/3,500 PSI.FOR 5 CHARTED MINUTES EACH.GOOD TEST. -BLEED OFF ALL PRESSURE AND CONFIRM NO PRESSURE UNDER ANNULAR PREVENTER THROUGH CHOKE. -OPEN ANNULAR PREVENTER AND PULL LUBRICATOR/DUTCH RISER ASSEMBLY TOGETHER AND SET ON FLOOR. 10:00 - 11:00 1.00 BOPSUR P PRE PULL"IS"BLANKING PLUG. -VOID STACK OF FLUID. -PULL BLANKING PLUG WITH JOINT OF DRILL PIPE. -INSTALL DUTCH RISER WITH LUBRICATOR. 11:00 - 12:00 1.00 BOPSUR P PRE PULL"IS"BPV. -PJSM. -MADE ATTEMPT TO PULL BACK PRESSURE VALVE FROM WELLHEAD WITH NO SUCCESS. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 5 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-0OYHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 16:00 4.00 BOPSUR N WSEQ PRE PULL"IS"BPV. -MADE 2ND ATTEMPT TO PULL BACK PRESSURE VALVE FROM WELLHEAD WITH NO SUCCESS. -MADE 3RD ATTEMPT TO PULL BACK PRESSURE VALVE-BROKE TIP OF RETRIEVAL TOOL OFF. -CALL FOR NEW RETRIEVAL TOOL. -RECOVERED BROKEN RETRIEVAL TOOL PART WITH RIG VACUUM SYSTEM. -WHILE WAITING ON NEW RETRIEVAL TOOL, I MADE UP SECOND CENTRALIZER TO LUBRICATOR ROD. -INSTALLED NEW RETRIEVAL TOOL. -RETRIEVED BACK PRESSURE VALVE. -RIG DOWN AND LAY DOWN LUBRICATOR. -RIG DOWN AND LAY DOWN DUTCH RISER. 16:00 - 17:00 1.00 PULL P DECOMP PULL HANGER FREE. -RIG UP 1 JOINT OF DRILL PIPE WITH CROSSOVERS BACK TO HANGER. -RUN ASSEMBLY IN HOLE AND ENGAGE INTO HANGER THREADS. -INSTALL TOP DRIVE. -BACK OUT LOCK DOWN SCREWS. -PULL HANGER FREE @ 120K PUW(BLOCKS WEIGH 50K=70K TO PULL HANGER (INCLUDING STRING WT)). 17 00 - 19'00 2.00 PULL P DECOMP CIRCULATE WELL. -SHUT IN WELL ON ANNULAR TO CIRCULATE. -PERFORMED WELL KILL DRILL-ALL HANDS RESPONDED IN GOOD TIME. -CIRCULATED 360 BBLS(SURFACE TO SURFACE)OF SEAWATER THRU CHOKE MANIFOLD AND MUD GAS SEPARATOR. INITIAL CIRCULATING PRESSURE AT 6 BBLS/MIN=570 PSI.FINAL CIRCULATING PRESSURE AT 6 BBLS/MIN=620 PSI. -SHUT DOWN PUMPS AND MONITOR WELL FOR 10 MINUTES-WELL STATIC. *SIMOPS-MOBILIZE POWER TONG EQUIPMENT TO RIG FLOOR. 19:00 - 20:00 1.00 PULL P DECOMP RIG UP TUBULAR HANDLING EQUIPMENT. -CHECK FOR PRESSURE UNDER ANNULAR-NO PRESSURE. -OPEN ANNULAR. -PULL HANGER TO RIG FLOOR. -FINISH RIGGING UP TUBULAR HANDLING EQUIPMENT. -BREAK OUT HANGER FROM STRING AND LAY DOWN TO PIPE SHED. -MAKE UP 3-1/2"SAFETY JOINT WITH CROSSOVERS. -CHANGE OUT ELEVATORS TO 3-1/2". -BLOW DOWN TOP DRIVE. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 6 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) •20:00 - 21:00 1.00 PULL P DECOMP CIRCULATE TO BALANCE WELL. -MONITOR HOLE WITH HOLE FILL ON. -WELL WAS GIVING FLUID THRU TUBING-NO GAINS WERE OBSERVED. -SHUT DOWN HOLE FILL. -CIRCULATED TUBING VOLUME OF 76 BBLS TO BALANCE OUT WELL. -CIRCULATED AT 7 BBLS/MIN @ 820 PSI. -SHUT DOWN PUMPS AND PERFORMED FLOWCHECK FOR 10 MINUTES-WELL STATIC. -RIG DOWN CIRCULATING EQUIPMENT. 21:00 - 00:00 3.00 I PULL P DECOMP DECOMPLETE WELL. -PJSM. -PULL 3-1/2"TUBING FROM WELL. '-PULL FROM 8,426'TO 5,500'. `FLUID LOSSES FROM NOON TO MIDNIGHT=13 BBLS(WHEN CIRCULATING STS) 5/19/2014 00:00 - 01:30 1.50 PULL P DECOMP DECOMPLETE WELL. -PJSM. -PULL AND LAY DOWN TO PIPE SHED 3-1/2" TUBING. -PULL FROM 5,500'TO 4,500'. 01:30 - 02:00 0.50 PULL P DECOMP RIG SERVICE. • 02:00 - 03:00 1.00 PULL N SFAL 4,500.00 DECOMP REPLACE TUBULAR POWER TONG UNIT. -DISCOVERED HYDRAULIC LEAK ON A HOSE ON POWER TONG UNIT. -RIG DOWN TONGS AND LAY DOWN BEAVER SLIDE. -PICK UP BACK UP SET OF TONGS TO RIG FLOOR AND RIG UP. 03:00 - 04:00 1.00 PULL P DECOMP DECOMPLETE WELL. -PULL AND LAY DOWN TO PIPE SHED 3-1/2" TUBING. -PULL FROM 4,500'TO 4,000'. 04:00 - 04:30 0.50 PULL N RREP 4,000.00 DECOMP CHANGE OUT FILTER HOUSING ON RIG HYDRAULIC SYSTEM. -DISCOVERED HYDRAULIC LEAK ON PUMP FILTER HOUSING. -SHUT DOWN PUMPS AND REPLACE FILTER HOUSING. 04:30 - 07:30 3.00 PULL P DECOMP DECOMPLETE WELL. -PULL AND LAY DOWN TO PIPE SHED 3-1/2" TUBING. -PULL FROM 4,000'TO SURFACE'. -PULL TOTAL OF 266 JOINTS,2 GAS LIFT MANDRELS,1'X'NIPPLE ASSEMBLY,AND 1 CUT OFF JOINT-2.85'LONG X 3.5"OD,3"ID. 07:30 - 09:00 1.50 PULL P DECOMP RIG DOWN COMPLETION HANDLING EQUIPMENT. -PJSM. -RIG DOWN TONGS,SLIPS. -LAY DOWN TONGS AND SLIPS IN BEAVER SLIDE. -INSTALL WEAR BUSHING:LENGTH=1', OD=10.75",ID=9.125". 09:00 - 11:00 2.00 PULL P DECOMP CUT AND SLIP DRILL LINE. -PJSM. -CUT AND SLIP59.5'OF DRILL LINE. Printed 5/27/2014 2:01:31 PM • North America-ALASKA-BP Page 7 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table©62.0ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:00 1.00 DHB P OTHCMP MAKE UP 7-5/8"RBP. -PJSM. -PICK UP AND MAKE UP 7-5/8"RBP. 'LOSSES FROM MIDNIGHT TO NOON=15 BBLS. 12:00 - 12:30 0.50 DHB P OTHCMP RIG SERVICE. -SERVICE TOP DRIVE,BLOCKS,PIPE SKATE, DRAW WORKS AND SLIDING SLEEVE. 12:30 - 22:00 9.50 DHB P OTHCMP RUN IN HOLE WITH 7-5/8"RBP. -PJSM. -PICK UP 4"XT-39 DRILL PIPE AND RUN IN HOLE WITH RBP WITH SINGLES OUT OF PIPE SHED. -RUN IN HOLE FROM 62'TO 8,374'. *OPEN OA FOR UPCOMING PACKOFF CHANGE OUT AT 15:30-0 PSI ON OA. 22:00 - 23:00 1.00 I DHB P OTHCMP SET 7-5/8"RBP AT 8,400'. -PJSM. -OBTAIN PARAMETERS AT 8,374':PUW 175K, SOW 162K. -RIH AND SET RBP AT 8,400'CENTER OF ELEMENT. 23:00 - 00:00 1.00 DHB P OTHCMP PERFORM CASING MIT. -PJSM. -RIG UP CHART RECORDER,CIRCULATING HOSES TO TEST CASING. -PURGE SYSTEM OF ALLAIR. -SHUT IN ANNULAR ELEMENT ON DRILL PIPE TO TEST CASING. -PRESSURE UP CASING TO 3185 PSI. 'FLUID LOSSES FROM NOON TO MIDNIGHT=14 BBLS. 5/20/2014 00:00 - 01:00 1.00 DHB P OTHCMP PRESSURE TEST 7-5/8"CASING(MIT). -PJSM. -PRESSURE TEST 7-5/8"CASING FROM 8,400' TO SURFACE. -PRESSURE TEST CASING:INITIAL PRESSURE=3180 PSI,15 MINUTE=3180 PSI, 30 MINUTE=3180 PSI-GOOD TEST.SEE ATTACHED FORM AND CHART. -FLUID VOLUME TO PRESSURE UP=4.5 BBLS-4.2 BBLS CALCULATED. -OBTAINED APPROVAL FROM ACTING WTL(K. SCHNEIDER)AT 00:30 HRS TO PROCEED FORWARD. -BLED DOWN PRESSURE-4.2 BBLS BLED BACK. 01:00 - 03:30 2.50 DHB P OTHCMP PULL OUT OF HOLE WITH RBP RUNNING TOOL. -PJSM. -POOH WITH RUNNING TOOL FROM 8,400'TO 2,345'. -POOH ON 4"DRILL PIPE STANDING BACK IN DERRICK. Printed 5/27/2014 2:01:31 PM • North America-ALASKA-BP Page 8 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:OOAM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table©62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 04:30 1.00 DHB P OTHCMP SET RTTS. -PJSM. -PICK UP AND MAKE UP 7-5/8"RTTS WITH 2,345'DRILL STRING HANGING UNDER PLUG. -RUN IN HOLE WITH RTTS 1 STAND(90')AND SET AS PER HALIBURTON. 04:30 - 05:00 0.50 DHB P OTHCMP TEST RTTS. -RIG UP CIRCULATING EQUIPMENT AND CHART RECORDER. -PRESSURE UP AND TEST RTTS FROM ABOVE TO 250 PSI LOW/3,000 PSI HIGH FOR 15 MINUTES EACH ON CHART-GOOD TEST-SEE ATTACHED CHART. 05:00 - 06:30 1.50 BOPSUR P OTHCMP NIPPLE DOWN BOP EQUIPMENT. -PJSM. -NIPPLE DOWN BOP EQUIPMENT. -PERFORM SPILL DRILL-ALL HANDS 'RESPONDED WELL. 06:30 - 08:00 1.50 1 WHSUR P OTHCMP PULL TUBING SPOOL. -BLEED OFF TUBING VOID. -NIPPLE DOWN AND REMOVE TUBING SPOOL FROM WELLHEAD. 08:00 - 09:30 1.50 WHSUR P OTHCMP PULL 7-5/8"PACKOFF OUT OF WELLHEAD. -PJSM. -PULL PACKOFF OUT OF WELLHEAD. 09:30 - 12:00 2.50 WHSUR P OTHCMP PREP CASING FOR NEW PACKOFF. -PJSM. -CUT AND DRESS 7-5/8"CASING FOR NEW PACKOFF 12:00 - 14:30 2.50 WHSUR P OTHCMP PREP CASING AND INSTALL TUBING SPOOL. -PJSM. -PREP CASING FOR TUBING SPOOL. -INSTALL PACKOFFAND TUBING SPOOL. -TEST PACKOFF AND VOID TO 250 PSI LOW FOR 5 MINUTES AND 3500 PSI HIGH FOR 30 MINUTES. -TEST NEW OUTER ANNULUS VALVES TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH. 14:30 - 17:00 2.50 BOPSUR P OTHCMP NIPPLE UP BOPE. -CONDUCT SPILL DRILL-ALL HANDS RESPONDED WELL. -PJSM. -NIPPLE UP BOP EQUIPMENT. -INSTALL TURNBUCKLES,RISER,FLOWLINE, FLOWLINE COVERS,BLEEDOFF LINE,HOLE FILL LINE AND ENVIRO-WRAP. 17:00 - 18:00 1.00 BOPSUR P OTHCMP PRESSURE TEST BOP BREAKS. -PJSM. -RIG UP AND RUN IN TEST PLUG TO TEST BOP BREAKS. -TEST BOP BREAKS TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH ON CHART-GOOD TEST. -RIG DOWN TEST EQUIPMENT. -PULL TEST PLUG. 18:00 - 19:00 1.00 WHSUR P OTHCMP INSTALL WEAR RING:LENGTH=1.63', OD=10.75",ID=9.125". -RUN IN 4 LOCK DOWN SCREWS. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 9 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task ! Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 20:00 1.00 DHB P OTHCMP PULL RTTS. -PJSM. -MAKE UP RTTS RUNNING TOOL. -RUN IN HOLE WITH RUNNING TOOL ON 1 STAND OF DRILL PIPE. -INSTALL FULL OPEN SAFETY VALVE. -SCREW INTO RTTS. -CHECK FOR PRESSURE UNDER RTTS WITH FULL OPEN SAFETY VALVE-NO PRESSURE. -PULL FULL OPEN SAFETY VALVE. -CLOSE ANNULAR ELEMENT ON DRILL PIPE. -UNSEAT RTTS BY PULLING UP 2'.LET RTTS ELEMENT RELAX. -CHECK FOR PRESSURE UNDER ANNULAR ELEMENT-NO PRESSURE. -OPEN ANNULAR ELEMENT. -PULL RTTS TO SURFACE,BREAK OUT OF 1 STRING AND LAY DOWN RTTS WITH CROSSOVER AND RUNNING TOOL. 20:00 - 22:15 2.25 DHB P OTHCMP RUN IN HOLE ON DRILL PIPE FROM DERRICK TO PULL 7-5/8"RBP. -PJSM. -BLOW DOWN CHOKE LINE. -RUN IN HOLE WITH 4"DRILL PIPE FROM DERRICK FROM 2,295'TO 8,374'. -PICK UP SINGLE DRILL PIPE FROM PIPE SHED. -ESTABLISH ARAMETERS AT 8,374': PUW=175K,SOW=162K. 22:15 - 23:00 0.75 DHB P OTHCMP PULL RETRIEVABLE BRIDGE PLUG. -PJSM. -ENGAGE RBP BY SETTING 10K DOWN ONTO PLUG. -OFFSEAT RBP AS PER HALLIBURTON REP. -RUN IN HOLE PAST SETTING DEPTH TO ENSURE ENGAGEMENT OF RBP-GOOD RUN. -FLOWCHECK WELL FOR 10 MINUTES-WELL STATIC. 23:00 - 00:00 1.00 DHB P OTHCMP PULL OUT OF HOLE WITH 7-5/8"RBP. -PJSM. -MOBILIZE DRILL PIPE THREAD PROTECTORS TO RIG FLOOR. -PULL OUT OF HOLE WITH RBP,LAYING DOWN SINGLES OF 4"DRILL PIPE TO PIPE SHED. -PULL OUT OF HOLE FROM 8,400'TO 7,429'. . 5/21/2014 00:00 - 06:30 6.50 DHB P OTHCMP PULL OUT OF HOLE WITH 7-5/8" RETREIVABLE BRIDGE PLUG. -PJSM. -POOH WITH RBP FROM 7,429'TO SURFACE. -POOH LAYING DOWN SINGLE DRILL PIPE TO PIPE SHED. 06:30 - 08:30 2.00 WHSUR P OTHCMP PULL WEAR RING. -PJSM. -PULL WEAR BUSHING. -FLUSH STACK WITH STACK WASHING TOOL. 08:30 - 10:30 2.00 RUNCOM P RUNCMP RIG UP TUBULAR HANDLING EQUIPMENT. -PJSM. -BRING POWER TONGS TO RIG FLOOR. -RIG UP POWER TONGS. -RIG UP 3-1/2"HANDLING EQUIPMENT. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 10 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table©62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 11:00 0.50 RUNCOM P RUNCMP SERVICE RIG. 11:00 - 12:00 1.00 RUNCOM P RUNCMP RIG EVACUATION/H2S DRILL. -CONDUCTED AAR AFTER DRILL-ALL HANDS RESPONDED WELL. 12:00 - 14:00 2.00 RUNCOM P RUNCMP TABLETOP DRILLS. -TABLE TOP DIVERTING SHALLOW GAS DRILL,REVIEWED SOP'S AND DISCUSS. -TABLETOP MAN DOWN/RESCUE DRILL, REVIEWED MAN DOWN/RESCUE GUIDELINES AND SOP'S. 14:00 - 16:00 2.00 RUNCOM P RUNCMP MAKE DUMMY RUN WITH HANGER. -MAKE UP LANDING JOINT TO HANGER. -SUCK OUT BOP STACK. -MAKE DUMMY RUN WITH HANGER AND ,LAND. -MARK LANDING JOINT AT RIG FLOOR. -CONFIRM SEATING OF HANGER VIA LOCKDOWN SCREWS. -BOLDS -PULL HANGER. -LAY DOWN HANGER/LANDING JOINT TO PIPE SHED. 16:00 - 16:30 0.50 RUNCOM N WAIT RUNCMP WAIT ON COMPLETIONS EQUIPMENT TO BE DELIVERED TO PAD. 16:30 - 18:30 2.00 RUNCOM N WAIT RUNCMP RECIEVE COMPLETIONS JEWELRY. -UNLOAD COMPLETION JEWELRY. -STRAP COMPLETION EQUIPMENT AND TALLY. -ADD TO RUNNING ORDER AND VERIFY. -LOAD INTO PIPE SHED IN PROPER RUN ORDER. 18:30 - 00:00 5.50 RUNCOM P RUNCMP RUN 3-1/2"COMPLETIONS. -PJSM. -RUN 3-1/2"COMPLETIONS AS PER RUN TALLY. -BAKER LOCK ALL COMPLETIONS JEWELRY CONNECTIONS BELOW TNT PACKER. -RUN 3-1/2"9.2#13-CR-85 VAMTOP TUBING WITH ALL ASSOCIATED JEWELRY FROM SURFACE TO 3,657'. -ALL 3-1/2"COMPLETIONS EQUIPMENT TORQUED TO OPTIMUM TORQUE MAKEUP TO 2,900 FT-LBS. 5/22/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP RIG SERVICE. 00:30 - 07:30 7.00 RUNCOM P RUNCMP RUN 3-1/2"COMPLETION. -PJSM. -RUN 3-1/2"COMPLETION AS PER RUN TALLY. -RUN 3-1/2"9.2#13-CR-85 VAMTOP TUBING WITH ALL ASSOCIATED JEWELRY FROM 3,657'TO 7,600'. -ALL 3-1/2"COMPLETIONS EQUIPMENT TORQUED TO OPTIMUM TORQUE MAKEUP TO 2,900 FT-LBS. -PERFORM TABLE TOP D1 KICK WHILE TRIPPING DRILL. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 11 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:OOAM Rig Release:5/23/2014 Rig Contractor DOYON DRILLING INC. UWI:500292184200 sft(above MeanSea Level) datum:Kelly Bushing/Rotary Table @62.00u Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 08:30 1.00 RUNCOM P RUNCMP LAND COMPLETIONS TO NO-GO. -SLACK OFF WITH OVERSHOT OVER TUBING STUB. -1ST SET OF SHEAR PINS OBSERVED AT 8,443'-SHEARED WITH 10K DOWN. -2ND SET OF SHEAR OBSERVED AT 8,851', SHEARED WITH 10K DOWN. -SLACK OFF AND TAGGED NO-GO AT 8,454'. -TOP OF TUBING STUB @ 8,439'. 08:30 - 10:00 1.50 RUNCOM P RUNCMP SPACE OUT CALCULATIONS AND SPACE OUT COMPLETIONS TUBING. -PULL 3 FULL JOINTS(2 EXTRA PLUS LAST FULL JOINT TO BE RUN IN HOLE). -SPACE OUT WITH 3 PUP JOINTS TOTAL AS PER WSL. -MAKE UP LAST FULL JOINT(#257)AND RUN IN HOLE. -MAKE UP TUBING HANGER. -RUN IN TUBING HANGER AND RUN IN LOCK DOWN SCREWS. -PICK UP WT=115K,SOW 115K. -OVERSHOT SPACED OUT 6.7'FROM NO-GO SHOULDER. -TUBING STUB AT 8,439',BOTTOM OF OVERSHOT AT 8,447.01',NO-GO SHOULDER AT 8,433.21',SWALLOW OVER TUBING STUB AT 7.1'. 'COMPLETIONS TUBULAR SUMMARY:TOTAL OF 257 JTS OF 3-1/2"9.2#13CR-80 VAMTOP TUBING,1 EA 7-5/8"UNIQUE MACHINE OVERSHOT @ 8,431',3 EA"X"NIPPLES @ 8,369'(RHC-M PLUG INSTALLED),8,303',2,216, 1 EA HES 7-5/8"X 3=1/2"TNT PACKER @ 8,334',3 EA 3-1/2"X 1-1/2"MMG GAS LIFT MANDRELS @ 8,269'(DGLV INSTALLED), 5,558'(DGLV INSTALLED),AND 3,190'(CAMCO DCR SHEAR VALVE INSTALLED),1 EA4-1/2"X 3-1/2"CROSSOVER PUP JOINT BELOW HANGER,AND 1 EA 11"X 4-1/2"AB TUBING HANGER TYPE"H"PROFILE. SEE ATTACHED TUBULAR WORKBOOK FOR MORE DETAILS. 10:00 - 12:30 2.50 RUNCOM P RUNCMP REVERSE CIRCULATE CORROSION INHIBITOR INTO IA. -PJSM. -RIG UP TO REVERSE CIRCULATE CORROSION INHIBITOR. -REVERSE CIRCULATE 285 BBLS OF SEAWATER SPIKED WITH MI KI-3869 CORROSION INHIBITOR INTO IA TAKING RETURNS THRU TUBING TO PITS. -CIRCULATE AT 4 BBLS/MIN @ 520 PSI. 12:30 - 13:00 0.50 RUNCOM P RUNCMP DROP BALL AND ROD ASSEMBLY. -RIG DOWN CIRCULATING EQUIPMENT FROM LANDING JOINT. -DROP BALL AND ROD ASSEMBLY WITH THE LANDING JOINT. -PULL LANDING JOINT. -FLUID PACK LINES AND STACK FOR PACKER SETTING AND TESTING. -WAIT FOR BALL AND ROD TO FALL TO SEAT. • Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 12 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:00AM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 16:30 3.50 RUNCOM P RUNCMP SET PACKER/TEST TUBING AND IA. -CLOSE BLIND RAMS FOR TESTING. -PRESSURE UP TUBING TO 250 PSI AND HOLD FOR 5 MINUTES-GOOD LOW TEST.IA PRESSURE-0 PSI. -INCREASE PRESSURE ON TUBING TO 3,000 PSI AND HOLD FOR 30 MINUTES FOR TUBING MIT.OBSERVED PRESSURE STALL AT 1,800 PSI FOR PACKER INFLATION.INITIAL PRESSURE=3,200 PSI,FIRST 15 MINUTE PRESSURE WAS 3,175 PSI(25 PSI LOSS),2ND 15 MINUTE PRESSURE WAS 3,165 PSI(10 PSI LOSS)-GOOD TEST. -BLED DOWN PRESSURE ON TUBING TO 1,500 PSI. -PRESSURE UP IA.WHEN IA PRESSURE EXCEEDED 1600 PSI,SAW TUBING PRESSURE INCREASE AT SAME RATE AS IA. -STOP PRESSURING UP IA AT 2,200 STOP PRESSURING UP IA. -BLEED DOWN IA TO 0 PSI.TUBING PRESSURE TRACKED WITH IA PRESSURE TO 0 PSI. -PRESSURED UP TUBING TO 1,600 PSI.0 PSI PRESSURE ON IA. -PRESSURED UP ON IA AGAIN.ONCE PRESSURE EXCEEDED 1,600 PSI,TUBING PRESSURE CAME UP AGAIN. -INCREASED PRESSURE ON IA AND TUBING TO 3,200 PSI AND START 30 MINUTES FOR MIT. -CONSULTED WITH ODE AND WTL FOR CLARIFICATION-APPROVAL TO PROCEED WITH MIT. —INITIAL PRESSURE ON IA FOR PACKER TEST=3,210 PSI,FIRST 15 MINUTE PRESSURE=3,200 PSI(10 PSI BLEED DOWN), SECOND 15 PRESSURE=3195 PSI(5 PSI BLEED DOWN)-GOOD TEST. -CALL WTL AND OBTAIN APPROVAL BEFORE PROCEEDING WITH PLAN FORWARD-APPROVAL GIVEN. -LINE UP TO BLEED DOWN IAAND TUBING. -BLEED DOWN TUBING THRU CHOKE MANIFOLD TO SHEAR DCR-VALVE. -INDICATIONS SHOWED DCR VALVE SHEARED. -LINE UP AND PUMP BOTH WAYS(TUBING TO IA AT 3 BBUMIN©2520 PSI,IA TO TUBING AT 3 BBUMIN @ 390 PSI)-GOOD TEST. -BLEED OFF ALL PRESSURE ON WELL. -CHECK FOR PRESSURE UNDER BLINDS-NO PRESSURE. 1-OPENED BLIND RAMS. 16:30 - 17:00 0.50 WHSUR P RUNCMP 1 RIG UP TO FREEZE PROTECT. -PJSM. -SUCK OUT STACK. -BLOW DOWN ALL LINES. -INSTALL LANDING JOINT. -RIG UP CIRCULATING LINES AND LIL RED SERVICES TO PUMP FREEZE PROTECT. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 13 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2,571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud Date/Time:7/18/1988 12:00:OOAM Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table©62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:00 - 20:30 3.50 WHSUR P RUNCMP FREEZEW PROTECT WELLHEAD. -PJSM. -LIL RED SERVICES PRESSURE TEST THEIR LINES TO 250 PSI LOW/3,500 PSI HIGH FOR 5 MINUTES EACH-GOOD TEST. -LRS PUMP 107 BBLS DIESEL DOWN IA TAKING RETURNS ON RIG THRU TUBING. -INITIAL CIRCULATING PRESSURE T 1 BBL/MIN=10 PSI,2 BBL/MIN=150 PSI,FINAL CIRCULATING PRESSURE AT 2 BBL/MIN=320 PSI. -SHUT DOWN PUMPING. -LINE UP AND U-TUBE FOR 1 HOUR. -OPENED UP LINES AND HAD LIL-RED SERVICES SUCK BACK DIESEL TO THEIR TRUCK. -RIG DOWN LINES,LAY DOWN CROSSOVERS, AND LANDING JOINT. 20:30 - 21:00 0.50 WHSUR P RUNCMP FLUSH STACK. -PJSM. -RIG UP TO FLUSH STACK. -FLUSH STACK. -VOID STACK OF ALL FLUIDS TO SET TWC. 21:00 - 21:30 0.50 WHSUR P RUNCMP INSTALL TWO WAY CHECK. -ASSEMBLE DRY ROD AND RUNNING TOOL. -DRY ROD IN TWO WAY CHECK VALVE INTO WELLHEAD. -RIG DOWN RUNNING TOO. 21:30 - 23:30 2.00 WHSUR P RUNCMP PRESSURE TEST TWO WAY CHECK VALVE. -PRESSURE TEST TWO WAY CHECK VALVE FROM BELOW TO 3,000 PSI FOR 5 MINUTES-GOOD TEST. -PRESSURE TEST TWO WAY CHECK VALVE FROM ABOVE TO 3,000 PSI FOR 5 MINUTES-GOOD TEST. 23:30 - 00:00 0.50 WHSUR P RUNCMP CHANGE BOTTOM RAMS TO 7-5/8"SOLID BODY RAMS. -PJSM. -VOID STACK OF FLUIDS. -BLOW DOWN KILL AND CHOKE LINES. -CHANGE OUT BOTTOM PIPE RAMS FROM 3-1/2"X 6"VARIABLE BORE RAMS TO 7-5/8" SOLID BODY RAMS. 5/23/2014 00:00 - 02:30 2.50 BOPSUR P RUNCMP -CHANGE OUT BOTTOM PIPE RAMS FROM 3-1/2"X 6"VARIABLE BORE RAMS TO 7-5/8" SOLID BODY RAMS 02:30 - 04:30 2.00 BOPSUR P RUNCMP NIPPLE DOWN BOPE. -PJSM. -NIPPLE DOWN BOP STACK,FLOWLINE, RISER. -STAND BACK BOP STACK ON STUMP. 04:30 - 06:30 2.00 WHSUR P RUNCMP NIPPLE UP ADAPTER FLANGE AND TREE -PJSM. -NIPPLE UP ADAPTER FLANGE AND TREE TO WELLHEAD. 06:30 - 08:00 1.50 WHSUR P RUNCMP TEST TUBING HANGER SEALS AND ADAPTER FLANGE. -TEST TUBING HANGER SEALS AND ADAPTER FLANGE TO 250 PSI LOW 5 MINUTES,5,000 PSI HIGH FOR 30 MINUTES-GOOD TEST. Printed 5/27/2014 2:01:31 PM North America-ALASKA-BP Page 14 of 14 Operation Summary Report Common Well Name:15-25 AFE No Event Type:WORKOVER(WO) Start Date:5/16/2014 End Date:5/27/2014 X4-00YHR-E:(2;571,000.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:DOYON 14 Spud DateTme:7/18/1988 12:00:00AM ;Rig Release:5/23/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292184200 Active datum:Kelly Bushing/Rotary Table @62.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 10:00 2.00 VVHSUR P RUNCMP PRESSURE TEST DRYHOLE TREE -PJSM. -RIG UP CIRCULATING EQUIPMENT TO TEST DRYHOLE TREE. -TEST DRYHOLE TREE TO 250 PSI LOW/5,000 PSI HIGH FOR 5 MINUTES ON CHART-GOOD TEST. -RIG DOWN CIRCULATING EQUIPMENT. 10:00 - 11:00 1.00 WHSUR P RUNCMP SECURE TREE AND CELLAR. -PJSM. -INSTALL GAUGES ON TREE. -CHECK PRESSURES ON TREE:TUBING=0 PSI,IA=0 PSI,OA=0 PSI. **RELEASE RIG FROM 15-25B AT 11:00 AM 5/23/2014 Printed 5/27/2014 2:01:31 PM TREE= FMC WELLHEAD= FARC 15-2 5 B SAF )TES: WELL MAX—_...LEG 88.95°@ ANGLE3 '*SEE PGS 2 &3 ACTUATOR= BAKER C OKB.ELEV= 67 FOR PREVIOUS WELLBORES"" BF.ELEV= KOP= 4800' I 2216' —I3-1/2-HES X NP,D=2.813" Max Angle= 104"@ 11701' 20"CONDUCTOR, OM= Datum MD= N►A 91.5#.1440, CAS LFT MANDRELS Datum ND= -8800 ID=19.124" ST NO TVD DEV TYPE V LV LATCH PORT' DATE 3 3191 3191 1 MMG DOME RK 16 05/26/14 10-3/4'CSG,45.5#,L-80 BUTT,D=9.953" H 3521' 2 5559 5507 30 MMG SO RK 20 05/26/14 1 8270 7750 32 MMG DMY RK 0 05122/14 Minimum ID = 1.81" @ 8465' 3-1/2" BAKER KB LNR TOP PKR I 1 8303' —{3-1/2"HES XNIP.D=2.813" x ,Q 8334' --17-5/8.X 3-1/2"HES TNT PKR,D=2.90" 1.__8369_ 1+-1/2"HES X NP,D=2.813" 1 3-1/2"TBG,9.2#,13CR-85 VAM TOP, H 8432' �\ .0087 bpf,D=2.992" 8447 ]—{7_5/8"X 3-1/2"UNIQUE MACHNE OVERSHOT 3-1/2"TBG STUB(05/19/14) H 8440' --------f 1.---------- W2:1 �� 8465' —3-1/2'BKR KB LIP.ID=1.81'(08115/08) ] 8471' —12.70*BKR DEPLOY SLV,ID=2.390" NON-PTIVEGASLFTMANDRILS :6 ST MD ND DEV TYPE VLV LATCH FORT DATE 3 8489 7937 32 MMG DMY RK 0 08/02/03 8549' —{3-1/2"FES X MP,D=2.813" 8593' —I3-1/2"TTN LOCATOR SEAL ASSY,ID=2.982" 5-1/2'LNR HGR ASSY w/6'T1i3ACK — 8697' i 4 " 8597' —{7-5/8"TTN SS86 PKR(1988),D=4.00" 8610' —5'MLLOUT EXTENSION,ID=? BEHIND 8616' —5"X 3-1/2"xo,ID=2.992" CT LNR I - 8683' —3-1/2'OTIS XN M',MLLE)TO 2.74'(04/05108) 3-1/2'TBG-PC,9.2#,L-80,.0087 bpf,ID=2.992" — 8718' 8718' H3-1/2"WLEG,D=2.992" IND 8688' HELA+DTTLOGGED 10/13/88 CT LNR 7-5/8"CSG,29.7#,L-80 NSCC/BTC,ID=6.875' H 8935' ----Al , 5-1/2'GEN I WHPSTOCK(04/04/08) H 9006' w/RA TAG 0 9014' 5-1/2"LNR, 17#,L-80 FL4S,.0232 bpf,ID=4.892" —I 9768' v't iti% ff. W. SIDETRACK WNDOW(15-25B) 9013'-9029' ORATION SUMMARY 14 REF LOG:SWS MCNJGR ON 04/14/2008 *�*�* '4*. ANGLE AT TOP PERF:96'@ 9890' h4• ,4 Note:Refer to Ffioduction DB for historical pert data �4�.k SIZE SPF INTERVAL Opn/Sqz SHOT SOZ .'1♦1'.'.♦1... 1.56" 6 9890-9920 0 04/14/08 1'1'.x.'.'.'.'., 1.56" 6 9970-10120 0 04/14/08 •��A����' 1.56" 6 10200-10750 0 04/14/08 _P3TD — 11619' 1.56" 6 10850-11470 0 04/14/08 1.56" 6 11590-11610 0 04/14/08 11 s, 2-3/8"LNR,4.7#,L-80 SIL, H 11658' " 01' .0039 bpf,ID=1.995" DATE REV BY COWAENTS DATE REV BY COM TS PRUDHOE BAY (.NIT 08/02/88 N-28E INTIAL COMPLETION 05/27/14 TBD/PJC PULL CS/GLV CIO(05/26/14) WELL: 15-258 10/16/99 ? CTD SIDETRACK(15-25A) 05/28/14 RS/PJC PULL LTTP(05/27/14) PERI T No: 2080240 04/15/08 NORDIC 1 CTD SIDETRACK(15-25B) 06/10/14 TR/JMD CORRECTIONS TO 3-1/2"TBG API No: 50-029-21842-02 05/23/14 D-14 RWO SEC22,T11N,R14E, 1821'FNL&1414'FWL 05/27/14 PJC DRLG DRAFT CORRECTIONS 05/27/14 CK/PJC FNAL ODE APPROVAL BP Exploration(Alaska) {I WELL LOG TRANSMITTAL PROACTIVE Diagnostic SERvicES, INC. To: AOGCC Christine Shartzer 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 SCANNED JUL 05 2013 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Point'"' Survey 09- Sep-12 15-25B BL/ CD 50-029- 21842 -02 2) Signed : UZ�� 664L( Date : l 0/42 Print Name: S)I� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245 -8952 E-MAIL : POSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Tmnsmit.docx P 15 - Zs-& Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] ' ee Sent: Thursday, August 09, 2012 7:25 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Lee, Timothy Cc: AK, D &C DHD Well Integrity Engineer Subject: NOT OPERABLE: Producer 15 -25B (PTD #2080240) MIT -IA Failed All, Producer 15 -25B (PTD # 2080240) failed an MIT - IA after dummy gas lift valves were set. The failed test confirms a lack of two competent barriers in the well. The well has been loaded with kill weight fluid and is reclassified as Not Operable until competent barriers are restored. Thank you, Mehreen Vazir SCANNED iAY 4 7 2013 BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Tuesday, July 17, 2012 9:06 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, 0' FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline a perations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Le-, Timothy Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Producer 15 -25B (PTD #2080240) S ained IA Casing Pressure Above MOASP All, Producer 15 -25B (PTD #2080240) has confirmed sustained casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV /2090NAC on 07/15/2012 he well has been reclassified as Under Evaluation while diagnostics are performed to evaluate integrity. Plan forward: 1. DHD: TIFL 2. WIE: Pending TIFL result, evaluate gas 1'. valve change out A TIO plot and wellbore schematic hay: been included for reference. « File: 15 -25B TIO Plot 07 -17- .docx » « File: 15- 25B.pdf» Please call if you have any qu: tions or concerns. Thank you, 1 DATA SUBMITTAL COMPLIANCE REPORT 2/1/2010 Permit to Drill 2080240 Well Name/No. PRUDHOE BAY UNIT 15-256 Operator BP EXPLORATION (ALASF(~ INC API No. 50-029-21842-02-00 MD 11738 ND 8755 Completion Date 4/15/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATbN Types Electric or Other Logs Run: MWD DIR, GR, MCNL / GR /CCL, MCBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr rata Digital Dataset Loa Loa R,~n Interval (1N ~ Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 8984 11738 Open 5/23/2008 ~ ~t Directional Survey 8984 11738 Open 5/23/2008 apt L IS Verification 8808 11748 Open 7/10/2008 LIS Veri, GR, ROP E~ D C Lis 16575 'Gamma Ray 8808 11748 Open 7/10/2008 LIS Veri, GR, ROP og Gamma Ray 25 Col 9009 11738 Open 7/10/2008 ND GR og Gamma Ray 25 Col 9009 11738 Open 7/10/2008 MD GR og See Notes 2 Col 8790 11720 Open 7/10/2008 Depth Shift Monitor Plot C Lis 16576 °~eutron 8272 11552 Open 7/10/2008 LIS Veri, GR, CNT Neutron 5 Blu 8250 11546 Open 7/10/2008 MCNL, Mem Lee, CCL, GR 13-Apr-2008 og Cement Evaluation 5 Col 8306 11569 Case 7/18/2008 MCBL, Mem PSP, GL, CCL, CBL, VDL 13-Apr- 2008 D C Pds 16627 dement Evaluation 8306 11569 Case 7/18!2008 MCBL, Mem PSP, GL, CCL, CBL, VDL 13-Apr- 2008 Nell CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • DATA SUBMITTAL COMPLIANCE REPORT 2/1 /2010 Permit to Drill 2080240 Well Name/No. PRUDHOE BAY UNIT 15-25B MD 11738 TVD 8755 ADDITIONAL INFORV~~ION Well Cored? ''~~. Chips Received?-_~`ff-IQ~ Analysis -1'9-I~_ Received? Completion Date 4/15/2008 Operator BP EXPLORATION (ALASI(A) INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? / N Formation Tops / API No. 50-029-21842-02-00 UIC N Comments: Compliance Reviewed By: Date: ? ~ 2 ~ _~?`~~~.:~ -- - j r BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, ~O$-~~~' a~~ ~5 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • r BP Exploration (Alaska) Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 naro• nvnswn Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement um ed cement date inhibitor sealant date ft bbls ft na al 15-016 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 18203b0 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-O8C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-128 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11111/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8!2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11(9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-318 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 07/14/08 ~chfumberger NO.4779 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & GaS COrIS COmm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wull .Inh 1k 1 nn rlnecrinfinn nafn RI CnInY Cn L1-09 11968948 LDL J~a~ 06/19/08 1 G-26B 11978455 MEM PROD PROFILE 04/24/08 1 15-256 12005210 MEM CBL O,LY 04/13/08 1 1 C-19B 12031482 USIT Q - 06/08!08 1 1 J-056 12083400 MEM SBHP - ~ 07/05/08 1 1 04-28 11968951 LDL ~ / 06/29/08 1 1 Z-06 11975781 GLS 07/08/08 1 1 Li-09 11962605 USIT ~ S -(~Q I ~ 06/28/08 1 1 L1-09 12017501 SONIC SCANNER ~ 07/06/08 1 1 04-43, 12031490 INJECTION PROFILE ' ~ j - ~~ `~ 07/08/08 1 1 I'LCAtit AI:KNUWLCUIat Fitl:tlF l I3T ,Il9NINli ANU F{CI UFiNINIa VNt I:VYT CHlirt I V: BP Exploration (Alaska) Ina - Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503- 38 ATTN: Beth '~ Received by: C~ + ! ,~~/ ' ~ STATE OF ALASKA ALASKA LAND GAS CONSERVATION COM SIGN ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~' S ~~ MAY 0 9 2008 it & Gas Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class:AnChQ[~ 13 ®Development U~ploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 4/15/2008 y 12. Permit to Drill Number 208-024- 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/6/2008 ~ 13. API Number ~ 50-029-21842-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/10/2008 - 14. Well Name and Number: PBU 15-256 1821 FNL, 3866 FEL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 1316' FNL, 1330' FEL, SEC. 22, T11 N, R14E, UM 8. KB (ft above MSL): 62' i Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1567' FNL, 683' FWL, SEC. 23, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11619' 8779' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 677361 y- 5959693 Zone- ASP4 10. Total Depth (MD+TVD) 11738' - 8755' 16. Property Designation: ADL 028307 TPI: x- 679884 y- 5960258 Zone- ASP4 Total Depth: x- 681903 y- 5960056 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information r 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information pe 20 AAC 25.0 1): MWD DIR, GR, MCNL / GR / CCL, MCBL !~///1~QD~,JJ~ 3it~J.l} ~~(S'TJ~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 112' Surface 112' 30" 2150# Poleset 10-3/4" 45.5# J-55 / L-80 Surface 3521' Surface 3521' 13-1/2" 1000 sx CS 111 600 sx Class 'G' 7-5/8" 29.7# L-80 Surface 8935' Surface 8313' 9-7/8" 630 sx Class 'G' -1 /2" 17# L-80 8597' 802 ' 8377' 6-3/4" 20 sx Class 'G' 2-3/8" 4.7# L-80 8465' 11658' 7916' 8773' 3" 77 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. Tue1NG RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MO 1.56" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 8718' 8597' MD TVD MD TVD 9890' - 9920' ~ 8821' - 881 T ' 9970' - 10120'' 8814' - 8810' - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10200' - 10750'" 8$09' - 8510'' ° DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 10850' - 11470' 8808' - 8784' ' 11590' - 11610'- 8782'•- 8780' - 2500' Freeze Protect w/ McOH 26. PRODUCTION TEST Date First Production: April 30, 2008 Method of Operatioh (Flowing, Gas Lift, etc.): Flowing Date Of Test: 4/30/2008 HOUrS T @Sted: 4 PRODUCTION FOR TEST PERIOD OIL-BBL: 324 GAS-MCF: 635 WATER-BBL: -0- CHOKE SIZE: 79 GAS-OIL RATIO: 1,960 Flow Tubing Press. 376 CaSing PfesS: 1,575 CALCULATED Z4-HOUR RATE• OIL-BBL: 1,945 GAS-MCF: 3,812 WATER-BBL: -0- OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^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 per 20 AAC 250.071. OMPLE 0 None ~ ~ Form 10-407 Revised 02/2007 ~ ~ pg"~-^~,y ~ `1 ~ C NTINUED ON REVERSE SIDE ~~~ J~L ~ ~ ~ooo ~' ~~OLO~~~AL 0 ~'~(~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD WeIlTested. Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 42SB /Zone 4A 9044' 8404' None Top CGL /Zone 3 9125' 8476' Base CGL /Zone 2C 9206' 8549' 23S6 /Zone 26 9270' 8604' 22TS 9330' 8651' 21TS /Zone 2A 9417' 8711' Zone 1 B 9505' 8759' TDF /Zone 1 A 9599' 8796' Formation at Total Depth (Name): TDF /Zone 1A 9599' 8796' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego'ng is true and correct to the best of my knowledge. D Signed Terrie Hubble Title Drilling Technologist Date ~~~~ PBU 15-25B 208-024 Prepared ey NameMumber.~ Terrie Hubble, 564-4628 Well Number Drilling Engineer: Greg Sarber, 564-4330 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: 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 02/2007 Submit Original Only BP EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~, Hours Task !, Code' NPT Phase I Description of Operations 4/3/2008 00:00 - 06:00 6.00 MOB P PRE Move rig from G-11 to DS-15. 16 mile derrick up move. 8 hours pad to pad. 06:00 - 06:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. 06:15 - 07:00 0.75 MOB P PRE Back rig over well and set down. 07:00 - 09:30 2.50 BOPSU P PRE ACCEPT RIG AT 0700 HRS 04/03/2008. PJSM, Review procedure, hazards and mitigation for BOP pressure testing. N/U BOPE and spot tanks and trailers. 09:30 - 15:30 6.00 BOPSU P PRE Pressure /Function test BOPE. Test witness waived by AOGCC inspector, Lou Grimaldi. Send test report to AOGCC. 15:30 - 17:00 1.50 BOPSU P PRE SAFETY SHUTDOWN. Paul Foreman visited the rig and conducted a safety meeting with entire crew. Reviewed field safety performance and Nordic 1 safety performance. 17:00 - 17:15 0.25 BOPSU P PRE SAFETY MEETING. Reviewed procedure, hazards and mitigation to ria up lubricator and pull B_PV with valve crew. 17:15 - 18:45 1.50 BOPSU P PRE Pull PV 't I 18:45 - 19:25 0.67 BOPSU P PRE RD lubricator. 19:25 - 20:30 1.08 BOPSU P PRE Bleed off WHP to tiger tank. 50 psi initial WHP, 500 psi WHP after 5 min. Shut in. 20:30 - 20:40 0.17 BOPSU P PRE SAFETY MEETING. Review procedures, hazards, and mitigations to PT inner reel valve, to lift fishing tool to rig floor, RU nozzle, and well kill. 20:40 - 22:15 1.58 KILL P DECOMP Lift fishin tool to ri floor, PT inner reel valve, and RU nozzle. Stab injector onto lubricator. 22:15 - 00:00 1.75 KILL P DECOMP 1500 psi initial WHP, bullhead 33bb1 at surface, 688 psi final WHP. RIH with nozzle ~ 105 ft/min pumping at 0.33 bpm, holding 750 psi on the choke. Divert gas & fluid returns to tiger tank. 4/4/2008 00:00 - 01:20 1.33 KILL P DECOMP RIH with nozzle to 8447'. 01:20 - 03:20 2.00 KILL P DECOMP Pump 144 bbl ~ 0.5 - 1.3 bpm. 03:20 - 05:00 1.67 KILL P DECOMP POH to surface at 50-100 ft/min, pumping 1.3 - 1.65 bpm with 115 - 125 psi backpressure. 05:00 - 05:25 0.42 KILL P DECOMP Flowcheck at surface. Well is dead. 05:25 - 05:30 0.08 KILL P DECOMP PJSM covering procedures, hazards, and mitigations to RD nozzle BHA & PU Fishing BHA 05:30 - 05:45 0.25 KILL P DECOMP RD nozzle BHA 05:45 - 06:15 0.50 FISH P DECOMP M/U BTT Fishin BHA--Dual Back Pressure Valve, 2 Weight Bars, Bower Up/Down Jars, HYD DISC, 3" GS Spear. BHA OAL = 20.69'. 06:15 - 08:00 1.75 FISH P DECOMP RIH with BTT pump off GS spear fishing BHA. Circ at 0.3 bpm. Up Wt at 8450' = 23.2K. RIH and to to of 2-3/8" liner fish at 8602' CTD. Pick u with 28K u Stack 4K on fish. Pick u a ain with 28K u wt. 08:00 - 10:00 2.00 FISH P DECOMP POH with fi h. Circ across the top holding 200 psi on choke to prevent swabbing. 5K over pull at 8100'. POH clean after that at 70 fpm. 10:00 - 10:15 0.25 FISH P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out recovered liner. Printetl: 5/122008 11:33:10 AM BP EXPLORATION Operations Summary Report Page 2 of 13 ~ Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 4/4/2008 10:00 - 10:15 0.25 FISH P DECOMP Flow check well. Well is dead. 10:15 - 12:00 1.75 FISH P DECOMP La out 2-3/8" recovered liner. Recovered 15-1/2 jts of 2-3/8" liner in oor condition. several jts had many 1/2" holes in each jt and most of the pin threads were 1/2 missing. fiecovered 100% of fish down to iet cut end. 12:00 - 12:15 0.25 EVAL P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for R/U slickline and logginh caliper log. 12:15 - 13:15 1.00 EVAL P DECOMP R/U SWS slickline unit with PDS caliper logging tool 13:15 - 14:50 1.58 EVAL P DECOMP RIH with Caliper logging tool on slickline. 14:50 - 16:00 1.17 EVAL P DECOMP Memory Log up with caliper. 9090 - 88500'. POH. 16:00 - 17:00 1.00 EVAL P DECOMP Lay out logging BHA. Rig down slickline unit. Down load caliper data and sent to Anc. Eng. 5-1/2" liner in good shape. Best joint to set whipstock in isat 8988-9038' based on cali er to . 17:00 - 17:15 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for Pumping SWS coil pickle procedure and blowing down coil with N2. 17:15 - 18:15 1.00 WHIP P WEXIT Circ. 40 bbls rig water, 10 bbl corrosion inhibitor, and 5 bbl MEOH thru coil. 18:15 - 19:45 1.50 WHIP P WEXIT Press test N2 line. Slowdown coil with N2 to Tiger tank and bleed pressure to zero. 19:45 - 20:00 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards, safe work practices to standback the injector and remove nozzle, and install grapple. 20:00 - 20:50 0.83 WHIP P WEXIT standback injector, remove nozzle, install grapple, and pull test. 20:50 - 21:05 0.25 WHIP P WEXIT SAFETY MEETING. Review detailed procedure, hazards, and mitigations for pulling the CT stub across and attaching it to the reel. 21:05 - 23:20 2.25 WHIP P WEXIT Pull CT stub across and attach to the reel. 23:20 - 23:35 0.25 WHIP P WEXIT SAFETY MEETING. Review hazards, mitigations, and procedures for reel swap. 23:35 - 00:00 0.42 WHIP P WEXIT Lower 2" a-free reel. 4/5/2008 00:00 - 02:50 2.83 WHIP P WEXIT Swa r Ito 2" a-coil. 02:50 - 03:05 0.25 WHIP P WEXIT SAFETY MEETING. Cover the procedures, hazards, and mitigations for pulling the coil across into the injector and cutting off the grapple 03:05 - 04:00 0.92 WHIP P WEXIT Pull coil across. Cut off the grapple. 04:00 - 05:00 1.00 WHIP P WEXIT Stab injector. Reverse fluid into the coil. 05:00 - 08:45 3.75 WHIP P WEXIT standback injector, Pump slack. Trim coil to find cable. Install CTC and pull test. Install BHI UOC cable head and test, OK. Install 3 PIP to s inside whi~tstock and check, OK. 08:45 - 09:00 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation making up Baker whipstock and Coiltrak BHA. 09:00 - 10:15 1.25 WHIP P WEXIT M/U BTT Whiptock and CoilTrak BHA #3. Orient TF. BHA OAL = 70.45'. Surface test CoilTrak tools. 10:15 - 12:00 1.75 WHIP P WEXIT RIH with Whipstock BHA #3. Circ at 0.20 bpm, Up wt at 8900' = 25.3K. 12:00 - 12:45 0.75 WHIP P WEXIT Log down tie-in with GR at 8900'. 0 ft correction. Printed: 5/12/2008 17:33:10 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: i Date !From - To Hours ',, Task Code NPT Phase Description of Operations 4/5/2008 12:00 - 12:45 0.75 WHIP P WEXIT RIH and to PBTD at 9088'. 12:45 - 12:55 0.17 WHIP P WEXIT Set whi stock to at 9010'. Lowside TF, 176 deg LOHS. 12:55 - 15:45 2.83 WHIP P 15:45 - 16:00 0.25 STWHIP P 4/6/2008 16:00 - 17:30 17:30 - 00:00 00:00 - 02:00 02:00 - 05:15 05:15 - 07:00 07:00 - 07:15 07:15 - 08:45 1.50 STWHIP P 6.50 STWHIP P 2.00 STWHIP P 3.25 STWHIP P 1.75 STWHIP P 0.25 DRILL P 1.50 DRILL P 08:45 - 10:20 1.58 DRILL P 10:20 - 10:45 0.42 DRILL P 10:45 - 13:00 2.25 DRILL P 13:00 - 15:30 2.50 DRILL P 15:30 - 18:30 3.00 DRILL P 18:30 - 18:45 0.25 DRILL P 18:45 - 19:50 1.08 DRILL P 19:50 - 21:00 1.17 DRILL P 21:00 - 00:00 3.00 DRILL P 4/7/2008 100:00 - 01:20 I 1.331 DRILL I P Close EDC. Setting tool sheared at 3200 psi. Up wt = 23.6K. Whipstock is set. WEXIT POH. Circ at 1.2 bpm, 2600 psi. WEXIT UO BTT Whipstock running tools. M/U Window milling BHA #4 with a 2.74" HCC window mill, string reamer, Xtreme motor, 2 jts 2-1/16" CSH, 2 wt Bars and CoilTrak to I AL = 108.95'. WEXIT RIH with 2.74" Window milling BHA #4. Tag whipstock pinch point at 9016' and correct depth to 9013'. WEXIT Mill 2.74" window to 9019.2' thru 5-1/2", 17#, L-80 Liner. 1.4 bpm, 3250 - 3700 psi, 0.3-2.7K WOB, 1 fph. WEXIT Mill 2.74" window to 9029.0' thru 5-1/2", 17#, L-80 Liner. 1.4 bpm, 3000 psi, 0.3-2.7K WOB, 1 fph. WEXIT Back ream and ream down the window three times between 9029 & 9010 at 1.4 bpm, 3100-3300 psi, 5 - 17 fph. Dry tag. No motor work while pulling through window. Small pressure variation RIH through window. Ream window once more. WEXIT POH PROD1 SAFETY MEETING. Review hazards, mitigations, and procedures for UD whipstock BHA and PU Build BHA. PROD1 UO milling BHA. Window mill gauged at 2.73 Go/2.72 no-go, String mill gauged 2.74 Go/2.73 No Go. M/U HYC Used BC Bit #1, 1.1 deg W FD Motor and CoilTrak BHA. BHA #5 OAL = 60.98'. PRODi RIH with CoilTrak Build BHA #5. Circ at 0.15 bpm, 1200 psi, RIH to 8920'. PROD1 Log down with GR and tie-in with PDS/GR log. -3 ft CTD. PROD1 Drill build section, 1.4 bpm, 3250-4100 psi, 160E TF, 10.3 ecd, 30 fph, Drilled to 9091'. PROD1 Drill build section in Zone 3, 1.4 bpm, 3050-4100 psi, 90L TF, 10.3 ecd, 10 fph, Slow drilling in Zone 3. Drilled to 9125'. PROD1 Drill build section in Zone 3, 1.4 bpm, 3000-4000 psi, 90L TF, 10.3 ecd, 10 fph, Slow drilling, Drilled to 9156'. PRODi Wiper trip to above window. Clean hole. 24K up wt. PROD1 Log down from 8840' with GR to Tie-in with RA tag in whipstock. -2 ft correction. RA tag ~ 9013.5'. PROD1 Drill build section to 9156' in Zone 3, 1.4 bpm, 3200 psi, 90-100L TF, 10.4-10.5 ecd, 6-13 fph, Slowing drilling. Frequent stalling. Decrease flowrate to 1.2 bpm. PROD1 Drill build section to 9160' in Zone 3, 1.2 bpm, 2800-3000 psi, 90-100L TF, 10.3-10.4 ecd, 0-7 fph. Slow drilling with frequent stalling. PROD1 Drill build section to 9164' in Zone 3, 1.4 bpm, 3300 psi, 90L TF, 10.4 ecd, 0-5 fph. Slow drilling with frequent stalling. Printed: 5/12/2008 11:33:10 AM • BP EXPLORATION Page 4 of 13 '~ Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code I NPT ~'~ Phase I Description of Operations 4/7/2008 01:20 - 03:15 1.92 DRILL P PROD1 POH to inspect bit and motor d_u_e to slow ROP, 03:15 - 03:25 0.17 DRILL P PRODi SAFETY MEETING. Review hazards, mitigations, and procedures to UD BHA, change bits, and PU BHA. 03:25 - 04:20 0.92 DRILL P PROD1 Standback injector, L/D BHA. BO worn bit, M/U HYC Rebuilt BC Bit, 1.1 deg WFD Motor and CoilTrak BHA; PU BHA, stab injector. BHA #6 OAL = 60.98'. 04:20 - 06:15 1.92 DRILL P PROD1 RIH w/ CoilTrac Build BHA #6. 06:15 - 06:30 0.25 DRILL P PROD1 Log GR tie-in at RA tag, -1.5' CTD. RIH clean and tag bottom at 9164'. 06:30 - 09:30 3.00 DRILL P PROD1 Drilling Zone 3 build section, slow drilling, 1.3 bpm, 3250-4200 psi, 80R TF, 10.6 ecd, 13 fph, Drilled to 9200'. 09:30 - 14:45 5.25 DRILL P PROD1 Drilling Zone 2 build section, 1.3 bpm, 3250-4000 psi, 40R TF, 10.5 ecd, 15 fph, Drilled to 9305'. 14:45 - 15:00 0.25 DRILL P PROD1 Wiper trip to window. Clean hole. Pull up to 8970'. 15:00 - 16:00 1.00 DRILL N MISC PROD1 Perform maintenance on traction motor for SWS power pack. Hayden electrical out of Anchorage, performing inspection on traction motor. Isolate traction motor in SCR room and follow Nordic 1 isolation procedure for traction motor. Performed PJSM and hazard analysis before inspecting traction motor. Traction motor tested OK. 16:00 - 16:15 0.25 DRILL P PROD1 RIH clean thru window and to bottom. 16:15 - 18:00 1.75 DRILL P PROD1 Drilling Zone 2 build section, 1.3 bpm, 3250-4000 psi, 50R TF, 10.6 ecd, 15 fph, Drilled to 9318'. 18:00 - 21:30 3.50 DRILL P PROD1 Drill to 9360' in Zone 2 build section, 1.3 bpm, 3200-4000 psi, 40L-50R TF, 10.6 ecd, 8-22 fph, FS=3400psi, Swap to new mud system. New Flo-Pro out the bit at 9347'. 21:30 - 00:00 2.50 DRILL P PROD1 Drill to 9405' in Zone 2 build sections, 1.3 bpm, 3000-3100 psi, 40L TF, 10.2 ecd, 20-32 fph. 4/8/2008 00:00 - 02:00 2.00 DRILL P PROD1 Drill to 9450' in Zone 2 build section, 1.4 bpm, 3000-3100 psi, 40-60L TF, 10.2 ecd, 20-30 fph. IA=137psi, OA=502psi, 02:00 - 02:35 0.58 DRILL P PROD1 Wiper trip to window. 02:35 - 04:10 1.58 DRILL P PROD1 Drill to 9516' in Zone 2 build section, 1.4 bpm, 3060-3300 psi, 50-60L TF, 10.3 ecd, 18-75 fph, 04:10 - 05:45 1.58 DRILL P PROD1 Drill to 9600' in Zone 1 B build section, 1.4 bpm, 3500-3750 psi, 60R, 10.4-10.5 ecd, 65-80 fph. 05:45 - 06:15 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. 06:15 - 06:30 0.25 DRILL P PROD1 Log GR tie-in at RA tag. -1/2 ft correction. 06:30 - 06:45 0.25 DRILL P PROD1 RIH clean to bottom. 06:45 - 09:30 2.75 DRILL P PROD1 Drill Build /Turn section in Zone 1 B. 1.3 bpm, 3250-4100 psi, 2K wob, 80 fph, 10.4 ecd, Drilled to end of build section at 9753'. 09:30 - 11:00 1.50 DRILL P PROD1 POH lean to window. POH to surface. 11:00 - 11:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing out BHA. 11:15 - 13:00 1.75 DRILL P PROD1 L/O Bit, motor and CoilTrak DGS. Bit was gradded at 3,2,1, 1 plugged port on reamer. M/U CoilTrak Lateral BHA #7 with rebuild HC BC Bit #3, 0.9 deg Weatherford motor and CoilTrak. Printed: 5/12/2008 11:33:10 AM BP EXPLORATION Operations Summary Report Page 5 of 13 ~ Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date ~ From - To Hours j Task Code NPT Phase Description of Operations 4/8/2008 111:15 - 13:00 1.75 DRILL P I I PRODi BHA OAL = 61.02' 13:00 - 14:30 1.50 DRILL P 14:30 - 14:45 0.25 DRILL P 14:45 - 15:15 0.50 DRILL P 15:15 - 17:30 2.25 DRILL P 17:30 - 19:10 I 1.671 DRILL I P 19:10 - 19:40 0.50 DRILL P 19:40 - 22:10 2.50 DRILL P 22:10 - 23:10 1.00 DRILL P 23:10 - 00:00 0.83 DRILL P 4/9/2008 100:00 - 02:15 2.251 DRILL P 02:15 - 03:10 0.92 DRILL P 03:10 - 05:00 1.83 DRILL P 05:00 - 05:40 0.67 DRILL P 05:40 - 05:55 0.25 DRILL P 05:55 - 06:30 0.58 DRILL P 06:30 - 08:40 2.17 DRILL P 08:40 - 09:30 0.83 DRILL P 09:30 - 11:30 2.00 DRILL P 11:30 - 12:30 1.00 DRILL P 12:30 - 13:45 1.25 DRILL P 13:45 - 14:15 I 0.501 DRILL I P PROD1 RIH with CoilTrak lateral BHA. Circ at 0.2 bpm, 1100 psi. Went thru window clean. PROD1 Log GR tie-in at RA tag. -1.5' CTD. PROD1 RIH clean to bottom. PROD1 Drill Z1 Lateral, 1.3 bpm, 3100-3900 psi, 1-2K wob, 10.6 ecd, 80L. Drilled to 9790'. PRODi Drill Z1 Lateral. GEO decided to drill up out of shale at 94 deg incl, Orient TF to 20L, Drilling in shale with 1.3 bpm, 3200-4000 psi, 20L TF, 10.6 ecd, PROD1 Continue drilling past 9,800 ft, slow drilling continue building angle at 10L toolface to climb out of transition zone. PROD1 Pull a 200 ft wiper trip, then resume drilling at 9,827 ft. ROP slowly increases as inclination increass past 90 deg. 21:40 - 1,200 psi motor work and drill off at 9,879 ft. Decision b Geo to turn u to 95 - 96 de inc th I after 10 ft TVD ain. Drill to 9,901 ft. PROD1 Wiper trip from 9,901 ft to window. Up weight is 27 Klbs off bottom, clean pickup. PROD1 Drill from 9,900 ft to 9,952 ft. Start taking slight losses around 0.1 b m after 9 900 ft. Stacking weight at 9,935 ft, pickup is 30 Klbs. 23:50 - 1,100 psi motor work and drill off at 9,945 ft. PROD1 Continue drilling from 9,952 ft at 1.35 / 1.23 bpm, ROP is 50 - 80 ft/hr. Maintain 90 - 91 deg inclination at 8,750 - 8,753 ft ND. PROD1 Wiper trip from 10,052 ft to window. Up weight is 25 Klbs off bottom, clean pickup. PROD1 Drill from 10,052 ft at 1.36 / 1.28 bpm. ROP is 50 - 90 ft/hr. 03:50 -Start taking 0.2 bpm losses at 10,123 ft. Drill to 10,200 ft. PROD1 Wiper trip from 10,200 ft back to window. Up weight is 26 Klbs, clean pickup. PROD1 Log GR down from 9,020 ft at 3 ft/min. Correct -1.5 ft. PROD1 Resume wiper trip back to bottom. RIH clean to bottom. PROD1 Drill Zone 1A 1.3 bpm, 3450-4200 psi, 1.8K wob, 70L TF, 10.9 ecd, 120 fph, Drilled to 10378'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Drill Zone 1A lateral, 1.3 bpm, 3450-4200 psi, 2-3K wob, 40L TF, 10.9 ecd, 120 fph, Drilled to 10,550'. PRODi Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Drill Zone 1A lateral, 1.3 bpm, 3450-4200 psi, 2-3K wob, 90R TF, 11.0 ecd, 120 fph, Swap to new FloPro at 10,650'. Total of 1300' on last FloPro system. Drilled to 10,650'. PRODi Drill Zone 1A lateral, 1.3 bpm, 3200-4000 psi, 2-3K wob, 90R Printed: 5/12/2008 11:33:10 AM BP EXPLORATION Page 6 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date. ;From - To Hours I! Task Code NPT Phase Description of Operations 14/9/2008 13:45 - 14:15 0.501 DRILL P 14:15 - 14:45 0.50 DRILL P 14:45 - 15:15 0.50 DRILL P 15:15 - 15:45 0.50 DRILL P 15:45 - 17:00 1.25 DRILL P 17:00 - 19:10 I 2.171 DRILL I P 19:10 - 20:50 I 1.671 DRILL I P 20:50 - 22:50 I 2.001 DRILL I P 22:50 - 00:00 I 1.171 DRILL I P 4/10/2008 00:00 - 01:20 1.33 DRILL P 01:20 - 02:00 0.67 DRILL P 02:00 - 02:20 0.33 DRILL P 02:20 - 02:55 0.58 DRILL P 02:55 - 04:30 ~ 1.58 ~ DRILL ~ P 04:30 - 04:40 0.17 DRILL P 04:40 - 05:40 1.00 DRILL P 05:40 - 07:00 1.33 DRILL P 07:00 - 08:30 1.50 DRILL P 08:30 - 09:30 1.00 DRILL P 09:30 - 11:30 2.00 DRILL P 11:30 - 12:50 1.33 DRILL P 12:50 - 13:30 I 0.671 DRILL I P 13:30 - 15:00 1.50 DRILL P 15:00 - 15:15 0.25 DRILL P PROD1 TF, 10.5 ecd, 120 fph, Drilled to 10685'. PROD1 Wiper trip to window. Clean hole. PROD1 Log GR tie-in at RA tag. Zero ft correction. PROD1 RIH clean to bottom. PROD1 Drill Zone 1A lateral, 1.3 bpm, 3200-4000 psi, 2-3K wob, 110R TF, 10.5 ecd, 60 fph, Drilled to 10,770'. PROD1 Drill Zone 1A lateral, 1.3 bpm, 3200-4000 psi, 2-3K wob, 110R TF, 10.5 ecd, 60 fph, PROD1 Wiper trip from 10,850 ft to window. Up weight is 26 Klbs off bottom, clean pickup. Circ pressure 3,100 psi off bottom. PROD1 Drill from 10,850 ft, 1.34 / 1.22 bpm at 3,200 - 3,600 psi. ECD = 10.50 ppg. ROP is 60 - 100 fUhr. Target inclination is now 92 deg as per Geo. 21:50 -Stacking weight at 10,926 ft. Pickup is 50 Klbs, 24 Klbs overpull off bottom. 22:30 -Stacking weight at 10,950 ft, up weight is 35 Klbs, circ pressure 3,250 psi off bottom. Resume drilling at 1.36 / 1.22 bpm at 3,400 - 3,800 psi. ECD = 10.63 ppg, ROP = 90 - 120 Whr when not stacking weight. Drill to 11,000 ft. PROD1 Wiper trip from 11,000 ft to window. Up weight is 27 Klbs off bottom, clean pickup. Circ pressure 3,250 psi off bottom at 1.37 bpm. PROD1 Continue wiper trip. PROD1 Drill from 11,000 ft at 100 - 150 fUhr. 1.37 / 1.2 bpm at 3,500 - 4,000 psi. ECD = 10.70 ppg. PROD1 400 ft wiper from 11,074 ft. Circ pressure 3,400 psi off bottom. PROD1 Drill from 11,074 ft at 100 - 150 fUhr, 1.38 / 1.23 bpm, circ pressure 3,600 - 4,000 psi. Drill to 11,150 ft. Maintain 92 - 93.5 deg inc as per Geo. PROD1 Wiper trip from 11,150 ft to window. Up weight is 28 Klbs off bottom, circ pressure 3,400 psi at 1.37 bpm. PROD1 Log GR down at 100 ft/hr from 9,020 ft. Correct +0.2 ft. PROD1 Resume wiper trip back to TD. PROD1 Drill from 11,150 ft at 130 ft/hr, circ pressure 4,000 psi, 1.32 / 1.23 bpm. ECD = 10.92 ppg. Drilled to 11,295'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Drill Z1A lateral, 1.3 bpm, 3500-4200 psi, 120 rop, 92 deg incl, ECD = 10.8 ppg. Stacking wt in shale, no progress. Drilled to 11,397'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Drill Z1A lateral, 1.3 bpm, 3500-4200 psi, 120 FPH, 120R TF, 92 deg incl, ECD = 11.1 ppg. Swapped to new FloPro at 11,500'. Drilled to 11,500'. PROD1 Drill Z1A lateral, 1.3 bpm, 3200-4000 psi, 120 FPH, 110R TF, 92 deg incl, ECD = 10.6 ppg. Drilled to 11,558'. PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. PROD1 Log GR tie-in, added 1 ft to CTD. Printed: 5/12/2008 11:33:10 AM BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: ~ I Phase ! Description of Operations NPT Date From - To Hours Task Code 4/10/2008 15:15 - 16:30 1.25 DRILL P PROD1 RIH clean to bottom. 16:30 - 18:00 1.50 DRILL P PROD1 Drill Z1A lateral, 1.3 bpm, 3100-4000 psi, 90 FPH, 20R-90R TF, 97 deg incl, ECD = 10.6 ppg. Anc. GEO decided to drill u dri lin incl = 100 de then h Id Stacking wt at 11,650', unable to drill further without another wiper. Drilled to 11650'. 18:00 - 19:15 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. 19:15 - 19:35 0.33 DRILL P PROD1 Log GR down from 9,025 ft to tie in depth. Zero correction. 19:35 - 20:50 1.25 DRILL P PROD1 Resume wiper trip back to bottom. 20:50 - 23:30 2.67 DRILL P PROD1 Tag bottom at 11,647 ft and drill ahead. Difficult weight transfer, have to run into bottom at speed and let it drill off, is the only way to make progress. 21:30 - 1,300 psi motor work and drill off. Drill past 11,730 ft continued weight stacking problems, and difficult shales in last 30 ft of hole. Confirm with Anc. Geo that enou h hole was drilled to satis geologic objectives, and call TD at 11,740 ft. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip back to window. 4/11/2008 00:00 - 01:00 1.00 DRILL P PROD1 Continue wipertrip to window. 01:00 - 01:10 0.17 DRILL P PROD1 Log GR down from 9,025 ft to tie in depth. Zero correction. 01:10 - 04:10 3.00 DRILL P PROD1 Continue wiper trip back to bottom. Bottom is found at 11,738 ft. POOH. 04:10 - 05:30 1.33 DRILL P PROD1 Pull through window and shut down pump to open circ sub. After EDC is open bring pump back to 1.4 bpm and POOH. 05:30 - 05:40 0.17 DRILL P PROD1 Tag stripper. SAFETY MEETING. Discuss procedures, hazards and mitigations for laying down BHA. 05:40 - 06:15 0.58 DRILL P PRODi Break off well and stand back injector. Lay down BHA.. Fill up well, prepare for function test of BOP. 06:15 - 06:30 0.25 BOPSU P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for performing BOPE function test. 06:30 - 07:30 1.00 BOPSU P PROD1 Function test BOPE. Send test report to AOGCC. 07:30 - 07:45 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for Pumping pickle procedure and blowdown reel with N2. 07:45 - 10:00 2.25 CASE P RUNPRD Pump 40 bbl fresh water, 10 bbl inhibitor, 5 bbl MEOH. Press test N2 line. Blow down reel with N2 Tiger tank and bleed off press to zero. 10:00 - 10:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for Pulling coil stub back to reel. 10:15 - 13:00 2.75 CASE P RUNPRD Pull test inner grapple. Pull coil stub to reel and secure coil on reel with cross bar and chain. 13:00 - 14:00 1.00 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for lowering and picking reels with bridge crane. 14:00 - 16:00 2.00 CASE P RUNPRD Lower 2" E-Coil to trailer. Secure on trailer. Back in E-Free Coil on trailer and pick with bridge crane. Secure reel in reelstand. Install hardline inside reel. M/U internal grapple, pull test grapple. Pull coil stub into Printed: 5/12/2008 11:33:10 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 4/3/2008 Rig Release: 4/15/2008 Rig Number: Page 8 of 13 ~ Spud Date: 7/18/1988 End: 4/15/2008 Description of Operations Date ~ From - To Hours ' Task Code NPT I Phase 4/11/2008 14:00 - 16:00 2.001 CASE P 16:00 - 18:00 I 2.001 CASE I P 18:00 - 18:20 0.33 CASE P 18:20 - 19:00 0.67 CASE P 19:00 - 19:20 I 0.331 CASE I P 19:20 - 22:30 3.171 CASE P 22:30 - 23:05 0.581 CASE P 23:05 - 00:00 I 0.921 CASE P 4/12/2008 00:00 - 01:30 1.50 CASE P RUNPRD injector. Cut off grapple. Install new CT packoff. RUNPRD Weld on SWS CTC with HB&R welder. Pull test CTC. Fill coil with FloPro. Press test inner reel valve and hardline. Press test weld on CTC with 3600 psi. OK. RUNPRD Insert dart and circ dart to catcher. RUNPRD Pressure to 1,000 psi and open reel valve to launch dart. Pump dart around CT into dart catcher, lands at 42.0 bbls. RUNPRD SAFETY MEETING. Discuss procedures, hazards and mitigations for rigging up and running liner, and opening and filling the well. RUNPRD Rig up to run liner. Open swab and master valve and fill well, takes 8.0 bbls to fill. Pick up first joint and verify X-over on stabbing valve is correct. Run liner and float equipment as per program, drift first 5 connections with 1.875" drift. Liner run: 2-3/8" Guide shoe, Float collar, 1 jt 2-3/8" STL L-80 liner, Float collar, 2-3/8" pup joint, 2-3/8" Latch collar, 99 it of 2-3/8" L-80 STL 4.7# liner, BTT deployment sleeve with 3.0 GS profile. Total Liner BHA length is 3,186.7 ft includin runnin tools. RUNPRD MU liner running tools to CT and liner. MU CT riser to well. RUNPRD RIH, pump minimum rate. Getting gas bubbles back intermittantly while RIH. RUNPRD Continue RIH. Weight check at 8,800 ft is 27 Klbs. At 11,665 ft, CT weight is -5 Klbs, Circ pressure 1,500 psi at 0.2 bpm. Pick up and try another run, up weight is 30 Klbs. Still getting gas bubbles back. 01:30 - 02:40 1.17 CASE P RUNPRD Continue trying to pass 11,665 ft. Stack weight with no pump, try to circulate and advance into hole. Hold 100 psi back pressure with choke. 02:40 - 03:15 0.58 CASE P RUNPRD Stuck at 11 645 ft not able to o u or d wn Push /pull several times with pumps on and off, not able to move. Shut down pump, drop ball to release from liner. Try to pick up for ball drop, CT is free. Decide to try and get deeper. RIH to 11,662 ft and stack weight, then pick up to 11,658 ft. Not abl t advance an furth r 03:15 - 04:30 1.25 CASE P RUNPRD Drop ball to release liner at 11,658 ft. Liner shoe is 80 ft short of TD at 11,738'. Chase ball at 1.56 bpm. Ball seated at 31.7 bbls, pressure up to 4,100 psi to shear. Up weight is now 19 Klbs, liner is released. Stack weight back down and circulate a bottoms up at 1.52 / 1.39 bpm. Good returns, no gas. 04:30 - 07:30 3.00 CASE P RUNPRD Swap well to 2% double slick KCL water. 1.5 / 1.3 bpm, No gas. 12% fluid loss while circ KCL, so added 1.6 bbl to calc 14.4 bbl Printetl: 5/12/2008 11:33:10 AM BP EXPLORATION Page 9 of 13 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 5-25 5-25 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task PLET A Code E NPT 4/12/2008 04:30 - 07:30 3.00 CASE P 07:30 - 07:45 0.25 CEMT P 07:45 - 08:55 1.17 CEMT P 08:55 - 10:20 1.42 CEMT P 10:20 - 12:00 1.67 CEMT P 12:00 - 12:30 0.50 CEMT P 12:30 - 12:45 0.25 EVAL P 12:45 - 17:00 4.25 EVAL P Spud Date: 7/18/1988 Start: 4/3/2008 End: 4/15/2008 Rig Release: 4/15/2008 Rig Number: Phase Description of Operations RUNPRD cement job. Will pump 16.0 bbls cement to place cement top 100' above window. Mix 2# Biozan pill in pill pit. Coil capacity = 42.0 bbls from pumping dart. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. RUNPRD Batch mix 15.8 PPG, G cement. At weight at 0836 hrs. Pump 3 bbl water and press test cement line with 5500 psi. RUNPRD Stage 16.0 bbl, 15.8 PPG, G Cement. 1.5 bpm, 3500 psi, Stop pump at 16.0 bbls. Isolate coil from cementers. Pump 5 bbl Biozan to cementers and purge line with air. Insert mini dart into coil. Stage 30 bbl 2# Biozan behind dart. 20 bbl displ, 1.8 bpm, 1.5 returns, 2800 psi, 30 bbl displ, Swap to slick KCL water, 1.8 bpm, 1.5 returns, 2800 psi 38.3 bbl displ, zero out totalizer, cement at shoe, 1.1 bpm, 1.0 returns, 1120 psi. 40 bbl displ, 1.1 bpm, 0.8 returns, 1200 psi Dart landed at 41.9 bbls. sheared at 3400 psi. 45 bbl displ, 1.0 bpm, 0.9 returns, 2500 psi 47 bbl displ, 1.0 bpm, 0.7 returns, 3000 psi, fluid loss increasing 48 bbl displ, 0.7 bpm, 0.5 returns, 2800 psi, slow pump to get better returns 50 bbl displ, 0.7 bpm, 0.6 returns, 3500 psi, better returns 52 bbl displ, 0.7 bpm, 0.6 returns, 3900 psi, steady returns 53 bbl displ, 0.7 bpm, 0.6 returns, 3900 psi, steady returns Bumped liner wiper plug at 54.4 bbls, 54.1 calc. Hold 4400 psi on plug, no leak off. 12.6 bbls returns based out totalizer. Lost 3.4 bbl cement to formation. Bleed off press. Check floats, OK. Press up 500 psi, sting out. Circ 2 bbls at top of deployment sleeve at 0.5 bpm, 340 psi pump press. Full returns. Cement job went well. RUNPRD POH with liner running tools. Replace CT voidage. 0.6 bpm, 240 psi. Bumped up at surface on depth. RUNPRD Lay out BTT CTLRT BHA. Well is full and holdin solid fluid level. Cement looks good. LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U Mill and motor cleanout BHA. LOWERI M/U cleanout BHA #9 with 1.875" mill, motor, MHA and 53 stds of 1"CSH. BHA OAL = 3290.94". We had to strap all of 1" CSH because SWS will no longer allow us to tag PBTD with the MCNL/GR logging tools. This still provides poor depth control because the CTD depth is not tied-in. Printed: 5/12/2008 11:33:10 AM • • BP EXPLORATION Page 10 of 13 Operations .Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours !, Task Code NPT Phase Description of Operations 4/12/2008 17:00 - 18:30 1.50 EVAL P LOWERi RIH with 1.875" mill, motor, MHA and 1" CSH workstring. circ at 0.2 bpm. Cement in place at 10:00 hrs. 9 hrs for cement sample to reach 500 psi. RIH to 8600' to ensure top of 2-3/8" liner is clean. 18:30 - 19:00 0.50 EVAL P LOWERI WOC until 1900 hrs. 19:00 - 21:00 2.00 EVAL P LOWERI RIH for cleanout to PBTD. No cement seen at top of liner. No cement strin ers seen while RIH. Ta at 11 620 ft Latch collar is 11,619.3 ft based on tall ). Up weight is 24 Klbs, clean pickup. 21:00 - 21:10 0.17 EVAL P LOWERI Mill on liner wiper plug for 5 min with no progress to verify it is not a cement stringer. 21:10 - 00:00 2.83 EVAL P LOWERI POOH pumping 1.0 bpm. Traces of cement water coming back. Stop and paint flag at 10,290.9 ft (7,000 ft EOP). Drop a 1/2" circ ball at 8,435 ft. No indication of ball landing on seat, continue POOH at 1 bpm. 4/13/2008 00:00 - 00:30 0.50 EVAL P LOWERI Tag stripper, stand back injector. 00:30 - 00:45 0.25 EVAL P LOWERi SAFETY MEETING. Discuss hazards and mitigations for standing back CSH. 00:45 - 01:10 0.42 EVAL P LOWERI Drop a second 1/2" ball into the CSH to open the circ sub and rig up to pump it open, shears at 2,400 psi. 01:10 - 03:00 1.83 EVAL P LOWERI Pull 53 stands of CSH and stand back. 03:00 - 03:30 0.50 EVAL P LOWERI Break off disconnect, circ sub motor and mill. Recover 2nd 1/2" ball from circ sub in BHA. Fill well with 1 bbl and close master valve. Hook up blocks to injector and MU swizzle stick. Recover 1st 1/2" ball from nozzle that was on CT while circulating. 03:30 - 04:15 0.75 EVAL P LOW ER1 Jet BOPs and tree down to master valve with swizzle stick at 2.9 bpm. Make 3 passes up and down. 04:15 - 04:30 0.25 EVAL P LOWERI SAFETY MEETING. Discuss procedure, hazards and mitigations for opening BOP stack to check for cement. 04:30 - 06:10 1.67 EVAL P LOW ER1 Stand back injector on legs and circulate. Oven BOP doors to clean anv cement residue. Large pieces of 06:10 - 07:45 1.58 EVAL P LOW ERi Button up doors on BOPs. Function test rams that were taken out. Fill BOPs and pressure test to 250 / 3,500 psi 07:45 - 08:00 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS memory CBL and CNL/GR/CCL logging tools and running 53 stds of 1" CSH workstring. 08:00 - 11:15 3.25 EVAL P LOWERi M/U SWS Memory Logging BHA #10 with MCBL and MCNL logging tools, hyd disconnect, 106 jts of 1" CSH and MHA. BHA OAL = 3,336.46'. 11:15 - 12:20 1.08 EVAL P LOWERi RIH with Memo to in BHA #10. circ at 0.3 bpm, 300 psi. 12:20 - 16:15 3.92 EVAL P LOWERI Log down from 8300' at 30 fpm to 11595'. Log up to 8300' at 30 fpm while laying in new FloPro pert pill. 16:15 - 17:30 1.25 EVAL P LOWERI POH with logging tools. 17:30 - 17:45 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for Standing back 1"CSH. 17:45 - 19:00 1.25 EVAL P LOWERI Perform visual inspection of elevators and slips. Stand back 1"CSH. Printed: 5/12/2008 11:33:10 AM i BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2008 19:00 - 19:25 0.42 EVAL P LOWERI SAFETY MEETING. PJSM with night tour for standing back remaining 1"CSH. Discuss crew responsibilities, stabbing valve, hazards and mitigations. 19:25 - 20:00 0.58 EVAL P LOWERI Stand back remaining 1" CSH, except for 1 stand. 20:00 - 20:15 0.25 EVAL P LOWERI SAFETY MEETING. Discuss procedures, crew placements, hazards and mitigations for pulling logging tools. 20:15 - 21:20 1.08 EVAL P LOWERI Pull last stand of CSH and mem logging tools. Rig up to run 1-1/4" CSH. (Needs to be sent out for inspection) Fill well with 2.1 bbls. 21:20 - 21:35 0.25 EVAL P LOWERI SAFETY MEETING. Discuss procedures, hazards and I~ mitigations for running and laying down 1-1/4" CSH. 21:35 - 23:10 1.58 EVAL P LOWERI Run 1-1/4" CSH doubles into well. 23:10 - 00:00 0.83 EVAL P LOWERI Lay down 1-1/4" CSH singles into pipe shed. 4/14/2008 00:00 - 00:30 0.50 EVAL P LOWERI Continue laying down 1-1/4" CSH in pipe shed. 00:30 - 00:50 0.33 EVAL P LOWERI Stop and fill well with 4.1 bbls. 00:50 - 01:40 0.83 EVAL P LOWERI Lay down rest of 1-1/4" CSH. Fill well with 3 bbls. 01:40 - 03:05 1.42 PERFO P LOWERI Perform liner lap test while loading out 1-1/4" CSH and loadi~ 03:05 - 03:45 0.67 PERFO P LOWERI 03:45 - 04:00 0.25 PERFO P LOWERI 04:00 - 07:15 3.25 PERFO P LOWERI 07:15 - 07:30 0.25 PERFO P LOWERI 07:30 - 09:00 1.50 PERFO P LOW ER1 09:00 - 11:25 2.42 PERFO P LOWERI 11:25 - 12:30 1.08 PERFO P LOWERI 1,974 psi C~? 0 min 1,898 psi C~? 5 min 1,846 psi ~ 10 min 1,798 psi ~ 15 min 1,747 psi @ 20 min -Test has failed, pump it up again. Baker choke was leaking, shut it in. 1,963 psi ~ 0 min 1,912 psi ~ 5 min 1,871 psi ~ 10 min 1,831 psi @ 15 min 1,794 psi ~ 20 min 1,758 psi ~ 25 min -Test has failed, bleed off. Continue to lay out 1.56" pert guns in pipe shed. SAFETY MEETING. Discuss hazards and crew placement for MU perf guns. MU SWS 1.56" pert puns, 1370' loaded at 6 SPF, 1606PJ, as per program, SAFETY MEETING. Review procedure, hazards and mitigation for running and strapping 1"CSH workstring. RIH with 25 stds of 1" CSH. Strap each jt while running. M/U BTT Hyd Disc, Locking swivel, Dual BPV and SWS Weld on CTC. Perforating BHA OAL = 3283.64'. RIH with SWS perforating BHA #11 with 1370' of 1.56" PJ perf guns, loaded at 6 SPF. Circ. at 0.2 bpm, 240 psi. PBTD from completion and from Memory CNL/GR is 11,619'. Tagged PBTD at 11,621' down depth. Pick up free at 11,617' and correct up depth to 11,619'. Circ. 10 bbl new FloPro perf pill ahead of ball. Insert 1/2" AL ball and displace with 10 bbl FloPro. Position bottom shot 2' below planned perforating depth of 11,610'. Circ 1.0 bpm at 2800 psi, slow pump at 30 bbls to 0.5 bpm at Printed: 5/12/2008 11:33:10 AM • i BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Spud Date: 7/18/1988 Event Name: REENTER+COMPLETE Start: 4/3/2008 End: 4/15/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/15/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/14/2008 11:25 - 12:30 1.081 PERFOBI P LOW ER1 1000 psi it uns on de th on the fl No over ull. U wt = 29K. G 12:30 - 14:15 1.75 PERFO P LOWERI POH with pert guns. Circ. at 0.6 bpm, 950 psi. Flow check at top of 2-3/8" liner. No flow. POH. Flow check at surface. No flow. 14:15 - 14:30 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for standing back 1" CSH workstring. 14:30 - 16:00 1.50 PERFO P LOWERI Stand back 25 stds of 1"CSH workstring. 16:00 - 16:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired pert guns and blanks. 16:15 - 18:00 1.75 PERFO P LOWERI Lay out SWS fired pert guns and blanks. 81 total. All shots fired. PERFORATED INTERVALS: 9,890 - 9,920 ~ 9,970 - 10,120 ~ 10,200 - 10,750 - 10,850 - 11,470 11,590 - 11,610 ~ 1370' TOTAL PERFS AT 6 SPF 18:00 - 18:30 0.50 PERFO P LOWERI SAFETY MEETING. Tour change and PJSM with night tour. Fill well with 2.0 bbls. 18:30 - 21:15 2.75 PERFO P LOWERI Lay out remaining pert guns. After LD 52 guns fill well with 1.4 bbls. 21:15 - 22:00 0.75 PERFO P LOWERI All 81 guns laid out. Fill well with 0.4 bbls. Clear rig floor of pert gun running equipment. Load pert guns out of pipe shed. Prepare to run liner top packer. 22:00 - 22:15 0.25 PERFO P LOWERI SAFETY MEETING. Discuss procedure, hazards and mitigation for picking up and running liner top packer. 22:15 - 22:35 0.33 PERFO P LOWERI MU BHA #12 -Liner To Packer. 22:35 - 00:00 1.42 PERFO P LOWERI RIH, pumping minimum rate. 4/15/2008 00:00 - 00:30 0.50 PERFO P LOWERI Continue RIH. 00:30 - 00:45 0.25 PERFO P LOWERI Weight check at 8,400 ft is 22.5 Klbs. Pressure increse seen going into deployment sleeve at 8,477 ft, shut down pump. RIH to 8,479 ft and stack down 10 Klbs to 8,484 ft. Pick up to get weight back to 8,479 ft. Pull out of deployment sleeve at 8,472 ft and pull up to 8,466 ft to circulate ball around. 00:45 - 01:25 0.67 PERFO P LOWERI Drop a 5/8" Aluminum ball, and launch with 1,200 psi. Chase with 30 bbls at 1.9 bpm then shut down pump to let it fall onto seat. RIH to sting into deployment sleeve then 3 ft further to land on no-go. Pick up to get weight back, and pick up a further 0.5 ft to 8,478.7 ft to get correct space out. Wait for ball to land on seat for 15 min. 01:25 - 02:05 0.67 PERFO P LOWERI Pressure u to 2,500 si to start acker set and shut down pump. Pressure bleeds off slowly. Printed: 5/12/2008 11:33:10 AM BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 15-25 Common Well Name: 15-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ;From - To Hours Task Code NPT 4/15/2008 ~ 01:25 - 02:05 0.671 PERFO P Spud Date: 7/18/1988 Start: 4/3/2008 End: 4/15/2008 Rig Release: 4/15/2008 Rig Number: Phase Description of Operations LOWERI Bleed down and pressure up again to 2.500 nsi and shut down., pump, holding steady this time. Slack 10 Klbs down to 8,843.1 ft, and bleed off pressure. Line up to pump down CT x tbg annulus to pressure test packer. Pressure up annulus to 1,915 psi after 5 min / 1,849 psi 10 02:05 - 03:55 I 1.831 PERFOBI P 03:55 - 04:10 0.25 PERFO~ P 04:10 - 08:00 3.83 DEMOB P 08:00 - 08:15 I 0.251 BOPSUR P 08:15 - 12:00 I 3.751 BOPSUR P LOWERI Bleed off annulus pressure, and line up to pump down the CT. Pressure up to 4,400 psi and shear off packer. Pick up off packer and POOH. Freeze protect top 2,500 ft with McOH at 50/50. Stop at 200 ft and pump until 100% McOH at surface. LOWERI Tag stripper, lay down LTP running tools. POST t BPV. Remove fusible cap, close master and swab valves. Rig up to blow CT back with air. Spot trucks, clean rig pits and cuttings box. POST SAFETY MEETING. Review procedure, hazards and mitigation for N/D BOPE. Filled out unit work permit for using hammer wrenches while N/D. POST Grease master and swab valves with Clare grease. N/D BOPE. N/U Tree cap and pressure test. RELEASED RIG AT 1200 HRS DAYS, 5 HRS. WAS 12 ALL FURTHER DIMS RIG INFORMATION WILL BE IN 07-01B DIMS REPORTS Printed: 5/12/2008 11:33:10 AM bP ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P ~~ u....,~ Company: $P Amoco Date:. 4/11'12008' -- Time: 14:40:01 Page: 1 ? Field: Prudhoe. Bay Co-ordinate(NE) Reference: .. Well: 15-25, True North Site:.. PB DS 15 Vertical (TVD) Reference: 37:25 7/18/1988 00:00 62.0 Well: 15-25 "; Section (VS) Reference: Well (O.OON,O.OOE,86.SOAzi) WeOpatb: 15-25B Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-25 Slot Name: 25 15-25 Well Position: +N/-S 830.85 ft Northing: 5959693.35 ft Latitude: 70 17 43.407 N +E/-W 1083.84 ft Easting : 677360.97 ft Longitude: 148 33 49.623. W Position Uncertainty: 0.00 ft Wellpath: 15-256 Drilled From: 15-25 500292184202 Tie-on Depth: 9029.95 ft Current Datum: 37:25 7/18/1988 00:00 Height 62.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/23/2008 Declination: 23.46 deg Field Strength: 57670 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 31.00 0.00 0.00 86.80 Survey Program for Definitive Wellpath Date: 1/23/2008 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 40.00 8984.89 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 9006.00 11738.00 MWD (9006.00-11738.00) MWD MWD -Standard Annotation MD TVD ft: ft 9029.95 8391.70 TIP 9006.00 8371.65 KOP 11739.00 0.00 TD Survey: MWD Start Date: 4/7/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD ft Incl deg Azim deg TVD ft Sys TVD ft N/S ft ` E/W ft- MapN ft MapE ft VS ft bLS Tooi deglOOft 8984.89 34.13 82.01 8354.23 8292.23 297.07 2206.93 5960042.40 679560.13 2220.06 0.00 MWD 9006.00 34.66 81.68 8371.65 8309.65 298.76 2218.73 5960044.37 679571.89 2231.94 2.66 MWD 9040.78 30.35 74.79 8400.99 8338.99 302.50 2237.01 5960048.54 679590.08 2250.40 16.32 MWD 9069.58 26.48 67.95 8426.32 8364.32 306.83 2249.99 5960053.16 679602.95 2263.60 17.54 MWD 9108.78 25.57 56.80 8461.56 8399.56 314.74 2265.18 5960061.44 679617.95 2279.21 12.68 MWD 9135.62 26.00 46.77 8485.74 8423.74 321.95 2274.32 5960068.85 679626.91 2288.74 16.32 MWD 9173.05 25.74 33.25 8519.45 8457.45 334.38 2284.76 5960081.52 679637.06 2299.86 15.75 MWD 9201.21 25.92 44.16 8544.81 8482.81 343.91 2292.41 5960091.23 679644.48 2308.02 16.87 MWD 9233.35 30.34 50.98 8573.16 8511.16 354.07 2303.62 5960101.65 679655.44 2319.78 16.99 MWD 9263.87 34.17 56.86 8598.97 8536.97 363.61 2316.79 5960111.51 679668.39 2333.46 16.21 MWD 9293.81 37.26 62.62 8623.28 8561.28 372.38 2331.89 5960120.63 679683.27 2349.03 15.24 MWD BP Alaska by Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 4/11/2008 Time: 14:40:01 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-25, True North Site: PB DS i5 Vertieal (TVD) Reference: 37:25 7/18!1 988 00:00 62.0 Well: 15-25 Section (VSjReference: Well (O.OON,O.OOE,86.80 Azi) Wellpath: 15-256 Survey.Calcula tionMethod: Minimum Curvature Db: Oracle Survey MD IncL Azim - TVD Sys TVl) N!S E/W MapN MapE V S DLS Tool ft deg 'deg ft $ ft ft tt ft ft - - deg/100ft 9323.53 40.19 68.58 8646.47 8584.47 380.03 2348.81 5960128.67 679700.01 _. 2366.35 15.95 MWD 9354.03 43.68 72.72 8669.16 8607.16 386.75 2368.04 5960135.85 679719.07 2385.93 14.60 MWD 9384.27 47.65 65.56 8690.31 8628.31 394.48 2388.20 5960144.05 679739.05 2406.49 21.41 MWD 9414.27 52.09 61.04 8709.64 8647.64 404.81 2408.67 5960154.86 679759.26 2427.50 18.75 MWO 9444.57 55.42 54.14 8727.57 8665.57 417.92 2429.26 5960168.45 679779.53 2448.79 21.39 MWD 9474.47 59.21 48.33 8743.72 8681.72 433.68 2448.85 5960184.67 679798.74 2469.22 20.68 MWD 9505.45 62.36 43.85 8758.85 8696.85 452.44 2468.30 5960203.88 679817.75 2489.70 16.20 MWD 9537.91 65.35 49.57 8773.16 8711.16 472.39 2489.51 5960224.32 679838.48 2511.99 18.30 MWD 9569.05 68.18 54.11 8785.45 8723.45 490.05 2512.01 5960242.51 679860.55 2535.43 16.19 MWD 9601.15 71.20 60.36 8796.60 8734.60 506.32 2537.31 5960259.37 679885.47 2561.61 20.54 MWD 9633.60 74.85 65.28 8806.08 8744.08 520.48 2564.91 5960274.17 679912.72 2589.95 18.35 MWD 9667.36 78.48 70.22 8813.87 8751.87 532.90 2595.31 5960287.31 679942.81 2620.99 17.84 MWD 9699.29 82.62 75.60 8819.11 8757.11 542.14 2625.40 5960297.26 679972.67 2651.55 21.08 MWD 9731.74 88.59 83.27 8821.60 8759.60 548.06 2657.17 5960303.92 680004.29 2683.60 29.89 MWD 9760.90 86.84 85.72 8822.76 8760.76 550.85 2686.17 5960307.40 680033.22 2712.71 10.32 MWD 9791.26 86.38 82.46 8824.56 8762.56 553.97 2716.31 5960311.23 680063.27 2742.98 10.83 MWD 9821.60 90.09 80.85 8825.49 8763.49 558.37 2746.31 5960316.34 680093.16 2773.18 13.33 MWD 9851.30 94.27 79.85 8824.36 8762.36 563.35 2775.56 5960322.00 680122.28 2802.66 14.47 MWD 9881.52 ~ 95.84 76.06 8821.70' 8759.70 569.63 2804.99 5960328.97 680151.56 2832.40 13.53 MWD 9911.92 96.93 72.55 8818.32 8756.32 577.80 2834.07 5960337.82 680180.44 2861.89 12.02 MWD 9942.08 94.03 72.83 8815.44 ~ 8753.44 586.73 2862.73 5960347.43 680208.87 2891.00 9.66 MWD 9972.20- 90.83 74.02 8814.16 8752.16 595.31 2891.57 5960356.69 680237.50 2920.27 11.33 MWD 10002.00 91.94 78.31 8813.44 8751.44 602.43 2920.49 5960364.49 680266.24 2949.55 14.87 MWD 10033.20 92.03 84.42 8812.36 8750.36 607.11 2951.30 5960369.90 680296.93 2980.57 19.57 MWD 10064.46 91.60 87.44 8811.37 8749.37 609.33 2982.46 5960372.85 680328.03 3011.81 9.75 MWD 10094.98 92.00 90.96 8810.41 8748.41 609.76 3012.96 5960373.99 680358.51 3042.28 11.60 MWD 10126.20 91.54 96.84 8809.45 8747.45 607.64 3044.08 5960372.61 680389.67 3073.23 18.88 MWD 10158.09 91.04 101.60 8808.73 8746.73 602.53 3075.54 5960368.24 680421.24 3104.36 15.00 MWD 10190.99 - 89.48 105.87 8808.58- 8746.58 594.72 3107.49 5960361.19 680453.36 3135.83 13.82 MWD 10227.07 89.02 101.74 8809.05 8747.05 586.11 3142.52 5960353.41 680488.58 3170.32 11.52 MWD 10258.57 90.00 97.33 8809.32 8747.32 580.90 3173.57 5960348.93 680519.75 3201.03 14.34 MWD 10290.13 88.77 93.13 8809.66 8747.66 578.02 3204.99 5960346.80 680551.23 3232.24 13.87 MWD 10320.89 87.63 89.78 8810.62 8748.62 577.24 3235.72 5960346.74 680581.96 3262.88 11.50 MWD 10351.47 87.36 86.18 8811.96 8749.96 578.32 3266.25 5960348.54 680612.45 3293.42 11.79 MWD 10395.81 87.14 79.16 8814.09 8752.09 583.96 3310.15 5960355.22 680656.20 3337.57 15.82 MWD 10426.66 90.65 76.44 8814.69 8752.69 590.48 3340.29 5960362.45 680686.18 3368.03 14.39 MWD 10464.00 90.98 72.42 8814.16 8752.16 600.50 3376.25 5960373.31 680721.89 3404.49 10.80 MWD 10495.26 91.38 75.61 8813.51 8751.51 609.10 3406.29 5960382.62 680751.72 3434.96 10.28 MWD 10527.46 90.12 80.01 8813.09 8751.09 615.90 3437.75 5960390.16 680783.01 3466.75 14.21 MWD 10557.02 89.42 84.04 8813.21 8751.21 620.00 3467.02 5960394.95 680812.17 3496.21 13.84 MWD 10586.86 92.92 89.27 8812.60 8750.60 621.74 3496.79 5960397.39 680841.89 3526.02 21.08 MWD 10615.44 90.52 93.49 8811.74 8749.74 621.05 3525.34 5960397.38 680870.44 3554.49 16.98 MWD 10648.40 88.40 97.31 8812.05 8750.05 617.95 3558.14 5960395.05 680903.31 3587.07 13.25 MWD 10675.80 93.13 102.25 8811.69 8749.69 613.30 3585.13 5960391.04 680930.39 3613.75 24.96 MWD 10705.44 91.97 105.06 8810.37 8748.37 606.31 3613.90 5960384.73 680959.32 3642.09 10.25 MWD 10734.94 89.69 109.03 8809.94 8747.94 597.67 3642.09 5960376.75 680987.71 3669.76 15.52 MWD 10766.84 89.72 114.11 8810.10 8748.10 585.94 3671.75 5960365.73 681017.63 3698.71 15.92 MWD 10796.94 89.48 118.47 8810.31 8748.31 572.62 3698.72 5960353.05 681044.91 3724.91 14.51 MWD 10827.22 92.67 120.49 8809.75 8747.75 557.72 3725.07 5960338.78 681071.61 3750.38 12.47 MWD 10858.44 94.12 125.03 8807.90 ~ 8745.90 540.86 3751.28 5960322.54 681098.20 3775.60 15.24 MWD 10889.48 93.81 127.16 8805.75 8743.75 522.62 3776.30 5960304.90 681123.64 3799.57 6.92 MWD 10919.96 91.90 123.89 8804.23 8742.23 504.94 3801.07 5960287.80 681148.82 3823.31 12.41 MWD 10952.74 91.60 120.04 8803.23 8741.23 487.59 3828.86 5960271.12 681177.01 3850.10 11.78 MWD bP ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P 1[NTEQ Company: BP Amoco Date: 4111!2008"° 'Time: 14:40:01 Page: 3 Ftield: Prudhoe"Bay Go-ordinate(NE)Reference: Wefl: 15-25, True North Site: PB DS 15 Vertical (TVD) Reference: 37 : 25`7!18/1988 00:00 62.0 Well: 15-25 Section (VS}Reference: Well (O.OON,O.OOE;86.80Azi) Wellpath:. 15-25B Survey Calculation Method: Minimum CuNature Db: Oracle Survey MD Iucl Azim TV1) Sys TVD N!S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft` ft ft ft degl100ft 10983.68 92.43 116.22 8802.14 8740.14 473.02 3856.12 5960257.20 681204.61 3876.50 12.63 MWD 11014.14 91.20 113.68 8801.18 8739.18 460.18 3883.72 5960245.01 681232.50 3903.34 9.26 MWD 11045.02 91.17 110.08 8800.54 8738.54 448.67 3912.37 5960234.19 681261.41 3931.30 11.66 MWD 11075.36 91.78 105.92 8799.76 8737.76 439.30 3941.21 5960225.50 681290.46 3959.57 13.85 MWD 11106.98 91.72 101.58 8798.79 8736.79 431.79 3971.90 5960218.72 681321.32 3989.80 13.72 MWD 11139.00 93.35 97.88 8797.37 8735.37 426.39 4003.42 5960214.06 681352.96 4020.97 12.62 MWD 11178.72 93.01 92.24 8795.17 8733.17 422.89 4042.91 5960211.49 681392.51 4060.20 14.20 MWD 11217.90 91.60 86.96 8793.59 8731.59 423.16 4082.04 5960212.69 681431.63 4099.29 13.94 MWD 11252.12 92.28 82.64 8792.43 8730:43 426.26 4116.09 5960216.59 681465.59 4133.46 12.77 MWD 11282.72 90.64 85.64 8791.65 8729.65 429.39 4146.52 5960220.43 681495.94 4164.01 11.17 MWD 11315.28 91.08 90.15 8791.16 8729.16 430.58 4179.04 5960222.39 681528.42 4196.56 13.92 MWD 11348.70 92.49 94.93 8790.12 8728.12 429.10 4212.40 5960221.70 681561.81 4229.78 14.91 MWD 11379.18 94.18 100.00 8788.35 8726.35 425.15 4242.56 5960218.46 681592.05 4259.67 17.51 MWD 11409.62 93.13 104.03 8786.41 8724.41 418.83 4272.27 5960212.84 681621.89 4288.98 13.65 MWD 11444.86 92.40 108.08 8784.71 8722.71 409.10 4306.09 5960203.91 681655.93 4322.20 11.66 MWD 11481.01 90.92 113.11 8783.66- 8721.66 396.39 4339.90 5960192.01 681690.03 4355.26 14.50 MWD 11515.82 92.12 118.69 8782.73 8720.73 381.20 4371.19 5960177.56 681721.67 4385.65 16.39 MWD 11545.69 89.14 121.19 8782.41 8720.41 366.29 4397.07 5960163.27 681747.89 4410.66 13.02 MWD 11581.92 91.66 122.52 8782.15 8720.15 347.17 4427.84 5960144.88 681779.10 4440.31 7.86 MWD 11611.76 95.63 123.72 8780.26 8718.26 330.91 4452.77 5960129.21 681804.41 4464.30 13.90 MWD 11642.07 101.17 124.43 8775.83 8713.83 314.11 4477.60 5960113.01 681829.63 4488.15 18.42 MWD 11673.19 101.43 128.54 8769.73 8707.73 295.97 4502.13 5960095.45 681854.58 4511.63 12.98 MWD 11701.05 103.67 132.34 8763.67 8701.67 278.34 4522.83 5960078.32 681875.68 4531.31 15.55 MWD 11738.00 103.67 132.34 8754.94 8692.94 254.16 4549.37 5960054.77 681902.78 4556.46 0.00 MWD TREE _ WELLHEAD = ACTUATOR = ~ AXEL KB. ELEV'= 62' BF. ELEV = ? KOP = 4800' Max Angle = 97 @ 11620' Datum MD = 9510' Datum TVD = 8700' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~-~ 35~ Minimum ID =1.81" @ 8465' Liner Top Packer Abbv. PERFORATION SUMMARY REF LOG: SWS MCNL/GR of 04/14/2008 ANGLE AT TOP PERF: 96 Deg @ 9890' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 9890-9920 Open 04/14/08 1.56" 6 9970-10120 Open 04/14/08 1.56" 6 10200-10750 Open 04/14/08 1.56" 6 10850-11470 Open 04/14/08 1.56" 6 11590-11610 Open 04/14/08 TOP OF 5-1/2" LNR 6' tieback rcptcl ~--~ $597' ~ 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" ~ TSAG 8828' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~~ $935' L i3 1/2" x 5 1/2"whipstock 9~~6' ~~ 2 3/8" cut and pull 9090' TOP OF LINER CEMENT (SCMT) 9100' TOP OF ~Ts`-- CEMENT ( : ; ) 9457' FMC FMC soN DRLG D FT 15-25A SIDETRACK WINDOW 9498' - 9503' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3182 3182 1 MMG DOME RK 16 04/18/08 2 5552 5439 30 MMG SO RK 20 04/18/08 3 8489 7876 32 DMY RK 0 08/02/03 $465' ~ 3 1 /2" KB LTP ID = 1.81 " er 2.70" OD Deployment Sleeve $549' 3-1/2" HES X NIP, ID = 2.813" I3-1/2" TMJ SEAL ASSY (1999) 7-5/8" TM/ SSBB PERM (1988) PKR (BEHIND CT LNR) ID=4.00" $' ~ 3-1/2" TUBING TAIL (BEHIND CT LNR) $' ELMD TT LOGGED 10/13/88 TOP OF Cement 9U~6' PBTD ~-~ 11619' ~ 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" ~ 2-3/8" LNR, 4.7#, STL, 0.00387 bpf, ID = 1.995" ~-{ 1165$' 2-3/8" LNR, 4.43#, FL4S, .0039 bpf, ID = 1.995" 11971' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/24/88 ORIGINAL COMPLETION 04115/08 NORDIC1 CTD SIDETRACK (15-256) 10/16/99 CTD SDTRCK 8 TBG REPLMT 04/16/08 /TLH CORRECTIONS 08/02/03 MHITLH GLV GO 05/04/08 DAV/PJC GLV GO (04/18/08) 11/27/03 KCF/TLP PERFS/NIP CORRECTIONS 01/07/05 CNJ/TLP TOC DEPTH CORRECTION 03/07/06 JCNUPJC DELETE X NIP @ 8583' PRUDHOE BAY UNff WELL: 15-256 PERMff No: 2080240 API No: 50-029-21842-02 SEC 22, T11 N, R14E, 980.66' FEL & 3583.52' FNL BP Exploration (Alaska) ETY NOTES: 70° @ 9575' 8 90° @ 9821' 15-25B • COMPANY BP EXPLORATION (ALASKA) INC COUNTY WELL NAME 15-25B STATE FIELD PRUDHOE BAY UNIT DATE NORTH SLOPE BOROUGH ALASKA 7/8/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1912088 Copies of p Digital Copi Copies Digital Each Log F~ Data Each of Film Da[a 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUTTE 802 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 Bv: BAKER ATLAS-PDC 17015 Aldine Wesffield, Houston, Texas 77073 This Distribution List Completed Bv: S~ '7~i~~ ~~~ ~,~~~~ lC~~ Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 15-25B Contains the following: 1 LDWG Compact Disc r (Includes Graphic Image files) 1 LDWG lister summary 1 color prints - GR Directional Measured Depth Log (to follow) 1 color prints - GR Directional TVD Log (to follow) ;F ':f P I LAC Job#: 1912088 _ ,~-- ~~t~-~~ ~ ~~~`~~ Sent by: Catrina Guidry ~ , Date: 07/08/08 % : ~ `~~ ~~'~f ' Received b Date: l; y i v - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ '~ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 07/10/08 l~{ill~~~l1U6~~1-s~ N0.4772 Alaska Data & Consulting Services Company: State of Alaska 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 Wpll .Inh # Lnn DESrriniinn Data l3L Celnr CD K-04C 12083398 MCNL -C)(a~ 05/14/08 1 1 14-33 11982433 RST 05/28/08 1 1 K-208 12021160 MCNL apa ^ a ~ c.( j °~ 05/24/08 1 1 15-256 12005210 MCNL ~ 04/13/08 1 1 YLtASt AI:KNUWLtULit IitGtlYl tlT 51Ci1V11V1a AIVU litl UFi1VI1Vti VIVt GUYT tAGFI I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: '- - - - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ~ ~/~~ ATTN: Beth ~ r f" i !i _,~ Received by: ``~--~__ ,, L.i 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for the following wells: P2-08APB 1 P2-08A G-11B 15-25B 07-O1B Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: Q ,State of Alaska AOGCC DATE: ~ 3 r~ ~.Q9_~ Cc: State of Alaska, AOGCC ~ 0 8 ~U~~ • ~ ~ ~ SARAH PAL/N, GOVERNOR cailC~-78A OII, AlsD ~ 333 W. 7th AVENUE, SUITE 100 CO1~TS~R'Q'ATIOrT COM1~II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Greg Sarber CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-25B BP Exploration Alaska, Inc. Permit No: 208-024 Surface Location: 1821' FNL, 3866' FEL, SEC. 22, T11N, R14E, UM Bottomhole Location: 1556' FNL, 823FWL, SEC. 23, T11N, R14E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill 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). incerely Daniel T. Seamount, Jr. Chair DATED thisf.,~ day of February, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~''~ -/o?-O~ ~ ALAS~IL AND GAS CONSERVATION COMMI~DN f~ ~I P-,, ~r PERMIT TO DRILL /~-~~ 20 AAC 25.005 ~7 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 15-25B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11850 TVD 8710ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028307 Pool 1821 FNL, 3866 FEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 1469' FNL, 1317' FEL, SEC. 22, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 18, 2008 Total Depth: 1556' FNL, 823' FWL, SEC. 23, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 28,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-677361 y-5959693 Zone-ASP4 10. KB Elevation (Height above GL): 62' feet 15. Distance to Nearest Well Within Pool: 1,100' 16. Deviated Wells: Kickoff Dept feet Maximum Hole An le• 94 de reel 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3653 Surface: 2391 18. Ca i Pr .ram: S cifi TQ - Se in De th - Bo m uanti of Cem nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 2.7" x 3" 2-3/8" 47# L-80 STL 3200' 8650' 8012' 11850' 8710' 63 sx Class 'G' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11971 Total Depth TVD (ft): 8812 Plugs (measured): None Effective Depth MD (ft): 11927 Effective Depth TVD (ft): 8810 Junk (measured): None :Casing Length ize Cement Volume MD TVD Conductor /Structural 112' 20" 2150# Poleset 112' 112' Surface 3521' 10-3l4" 1000 sx Coldset III 500 sx Class'G' 3521' 3521' Intermediate 8935' 7-5/8" 630 sx Class 'G' 8935' 8313' Pr duction Liner 901' S-1/2" 200 sx Class'G' 8597' - 9498' 8029' - 8750' Liner 3376' 2-3/8" 94 sx Class 'G' 8595' - 11971' 8028' - 8812' Perforation Depth MD (ft): 9827' - 11929' Perforation Depth TVD (ft): 8822' - 8810' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Greg Sarber, 564-4330 Printed Name eg Sar r Title CT Drilling Engineer / Prepared By Name/Number: Si nature ~( ~d Phone 564-4330 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: D O O API Number: 50-029-21842-02-00 Permitl~p royal See cover letter for Date: G- ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed meth ne, gas hydrates, or gas contained shales: Samples Req'd: Yes ~No Mud Log Req'd: ^ Yes ~No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~ ~`i~ ~~ ~ ~~~ ~ ~-~~ ~'. /~~~ APPROVED BY THE COMMISSION ` Date ,COMMISSIONER Form 10-401 Revised 12/2005 ~O ~ ~ ~ Submit In Duplicate INAL • i by BPXA Prudhoe Bay DS 15-25B CTD Sidetrack February 4, 2008 CTD Sidetrack Summary Pre-CT Rig Work: 1. MIT-IA 2. Drift 2-3/8" liner for CIBP 3. Run multifinger calliper in 2-3/8" liner and production tubing from 9,600' to surface. 4. Set CIBP in 2-3/8" liner C~ 9,500', and test to 3500 psi. 5. Jet cut 2-3/8" liner C~ 9,090'. 6. Pickup on cut section of liner with service coil to confirm pipe is cut and free. 7. Install a 2"d valve on the IA and PT. 8. AC-PPPOT-IC 9. Install a TWC. 10. Bleed production flow lines and GL lines down to zero and blind flange. 11. Change out tree and adapter flange from 3-1/8" to 4-1/16", PT as per SOP, but to include MV, SV, WV. 12. Remove wellhouse, level pad. -~-c~~- Rig Sidetrack Operations: (Scheduled to begin on April 18, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull TWC, load well with KW F. 'I. RIH with a GS s ear. Recover cut section of 2-3/8" liner. 5. Set Baker TT 3-1/2" x 5-1/2" whipstock wit top at 6. Mill 2.75"" window at 9,070'. 7. Drill build/turn section with 2.70" x 3.0" bicenter bit, and land well. 8. Drill lateral section to 11,850'. 9. Run and cement a 2-3/8" L-80 liner string, abandoning perfs in parent wellbore. 10. Make a cleanout run with mill and motor. 11. Make a logging run with a SWS GR-CNL logging tool. 1 ~~ 12. Perforate well. 13. Circulate well to KWF brine. FP well to 2000' with diesel. ~~ ~~~ ~~ 14. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 15. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Mud Program: • Well kill: 8.4 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 t~d 3 for disposal. • Hole size: 2.70"x3.0" (bi-center bits used) Casing Program: fully cemented liner • 2-3/8", L-80 4.70# STL 8,650' and -11,850' and • A minimum of 13 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 3.0" bit size and. TD C~ 11,850', with 40% excess in the open hole interval) • TOC planned at 9,070' (Only OH section cemented) Existing casing/tubing Information 10-3/4", L-80 45.5#, Burst 5210, collapse 2480 psi 7 5/8", L-80 29.7#, Burst 6890, collapse 4790 psi 5-1/2", L-80 17#, Burst 7740, collapse 6290 psi Well Control: • BOP diagram is attached. • 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 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 93.5 deg at 11,400'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 28,000 ft. • Distance to nearest well within pool -1,100 ft. (15-31 B, first perforation) Logging • MW D directional, Gamma Ray will be run over all of the open hole section. • Cased hole MCNL/GR/CCL, and SCMT logs will be run. Hazards • There are 2 close approaches to existing wells 15-10, and 15-31 A. Both are P&A'd. • The maximum recorded H2S level on DS 15-25 was 10 ppm on 9-10-2005. • The maximum recorded H2S level on DS 15 was 40 ppm on well 15-20C. • Lost circulation risk is high. Reservoir Pressure • The reservoir pressure on 15-25A was last recorded at 3,271 psi at 8,800' TVDSS on 12-16-2005. (7.15 ppg equivalent) • The greatest reservoir pressure on DS 15 is 3,653 psi at 8,800' TVDSS on well 15-11. (7.98 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,391 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE = FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV - fi BF. ELEV _ ~ KOP = 4800' Max Angle = 95 @11542' Datum MD = NA DatumTVD= 8800'SS ~ 15-25A NOTES: 70° @ 9575' & 90° @ 9901' 2192' I~ 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" 3521' Minimum ID =1.969" @ 8595' 2.7" DEPLOYMENT SLEEVE ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3182 3182 1 MMG DMY RK 0 08/02/03 2 5552 5439 30 DMY RK 0 08/02/03 3 8489 7876 32 DMY RK 0 08/02/03 3-1/2" HES X NIP, ID = 2.813" ~TOPOF 5-1/2" LNR I 8597' TOP OF 2-3/8" LNR 8600' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 8718' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" TOP OF CEMENT 8594' -~ 3-1/2" TMJ SEAL ASSY 8595' 2.70" DEPLOY SLV (5' LONG), ID = 1.969" 8597' 7-5/8" X 3-1/2" TM! SSBB PERM PKR (BEHIND CT LNR) I 8718' 3-1/2" TUBING TAIL (BEHIND CT LNR) 8688' ELMD TT LOGGED 10!13/88 9457' ' SID CK WINDOW 9498' - 9503' ice' ~ ~ ~ ~ 5-112" LNR, 17#, L-80, .0232 bpf, ID = 4.892" I-j 9758' PERFORATION SUMMARY REF LOG: BHCS ON 07/30/88 ANGLE AT TOP PERF: 89 @ 10320' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 4 10037 - 10062 O 11 /27/03 1.56" 4 10157 - 10182 O 11/27/03 2-3/8" 4 10320 - 10750 O 10/15/99 2-3/8" 4 10800 - 11030 O 10/15/99 2-3/8" 4 11084 - 11510 O 10/15/99 1-11116" 4 11676 - 11929 O 12/01 /99 1.56" 4 9827 - 9852 O 11 /26/03 1.56" 4 9897 - 9922 O 11 /26/03 PBTD I-i 11927' 2-3/8" LNR, 4.43#, FL4S, .0039 bpf, ID = 1.995" DATE REV BY COMMENTS DATE REV BY COMMENTS 09!24/88 ORIGINAL COMPLETION 10/16/99 CTD SDTRCK 8 TBG REPLMT 08/02/03 MH/TLH GLV C/O 11/27/03 KCFITLP PERFS/NIP CORRECTIONS 01/07/05 CNJ/TLP TOC DEPTH CORRECTION 03/07/06 JCM/PJC DELETE X NIP @ 8583' PRUDHOE BAY UNfT WELL: 15-25A PERMff No: 1990860 API No: 50-029-21842-01 SEC 22, T11 N, R14E, 980.66' FEL & 3583.52' FNL BP 6cploration (Alaska) tit= hAA.: UELLFfi4D = FNC ACTUATOR = AXELSON J9 t3EV = 82' ~ aEV = a oP - _ Aax Angie = ~itum !.~ = 4aoa~ 9d ~ t 1542' _-_ NA 10-314" CSG. 45.5>K. L-80. O = 9.953" H 3' Minimum ID =1.969" ~ SS95' 2.7" DEPLOYMENT SLEEVE Abbv F'f3iFORATIONSUfi~}IWFaY REF LOG: BHCS ON 07130!88 ANGLE AT TOP PE3ZF: 89 ~ 103217 Note: Faster to Roductlon OB far n$tacal pert data SIZE Sf~F NfEFiVAL OprVSpz ^A fE 1 9827-11929 s T8A GA5 LFT f~1hNDRII-S iT h1i:1 TVD OI?V TYPE VLV LATCH PC+F 1 3182 3182 1 AR.1G OW1Y FaK 0 2 5552 5439 3D OMY W( 0 3 8489 7878 32 OM'f RK 0 TOPOF 5-112' LNR G tlebeCk ii7f'tJF 3-112" T13G. 9.2ar, L-80, .0)87 bpf, C 7.518° CSG 29iir. L-so. o • 3 t!2" r 5 tQ"'whipstock Z 3.8' cut anA pull TOP OF Lh£fi CO`ENr [3Ct1 $b97' 7-578' T1W SS8f3 PB~aM (1988) H(K (t3tNIfJO (:1 LNtt) IDN.OU' 8650' 3 t!2" KB LTP ID = 1 75" B660' ~-{2.76" OE3'LOY SLV [ 5' LOfdG). D ^ 1.9fi9' 8718' ~~3-t1YTU8NGTAl[BEN~DCTLNR} 8688' ELAIDT7l.0C3C'fIJtO1t3J'8$ TSAG 8828' 2 318" LNER ~ 1S-23A SIDETRACK WNDOVJ 9198' - X501' I ~ 5-112" LNR. 17ff. L-80. 0232 bpf, D = 4.897' ~ 2-318" LNR. 4.43fY, FL4S. 0039 bpf, D = 1.995' 11971' 2 ''8" L,~Ft 4 '# STL, 0.0038? bpf . O = ' .595' 11850' agTE FaEV BY Cc]h1fuFNfS GATE REV BY COMoQ~fTS 09124f88 OFDGINAL COMPLETK~AI 10NBf99 CTOSDTFlCKBTBGFlH+LMi 0&02103 M-Y1LH G1.V C10 11/27/03 KtxITLP PERFSrAIP CORRECTIOf•LS 01,07.+'05 CNJFiLP TOC DEPfN CORRECTION 03107,06 JChVP.JC OQ.ETE?C NP $~ 8583' 15 ~~ ~ ~ S~TM NOTES. 70' ~ 8575' 6 90' ~ 9901' Proposed CTD Sidetrack 2192' H 3-112" HE'S XNIP, D = 2.813" PFtUDFIOE 8AY UPNT 1NELL: 15-25A F'E7iA~1tT No. '1999560 Afa No 50-029-21842-01 SEC 22. Tt 1 N, R14E 980.E36- Fa 8 3583.52' FTC ~ Expbration (Ahaka) by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ Company: BP Amoco Date: 1!23/2008 ~ Tirne: 14:43:37 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-25, True North Site: PB DS 15 Vertical (1'VD) Reference: 37:25 7/18/1988 00:00 62.0 Well: 15-25 Section (VS) Reference: Well (O.OON,O.OOE,95.OOAzi) Wellpath: Plan 2, 15-258 Survey Calcula[ion Method: Minimum Curvature Db: Oracle ----- -- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i'i Geo Datum: NAD27 (Clarke 1866) Coordinate System: We ll Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 15 - ~I TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837 .36 ft Latitude: 70 17 35.236 N ~i ~! From: Map Easting: 676296 .98 ft Longitude: 148 34 21.213 W '~ Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-25 Slot Name: 25 15-25 '; Well Position: +N/-S 830.85 ft Northing: 5959693 .35 ft Latitude: 70 17 43.407 N +E/-W 1083.84 ft Easting : 677360 .97 ft Longitude: 148 33 49.623 W Position Uncertainty: 0.00 ft ', Wellpath: Plan 2, 15-256 Drilled From: 15-25 50029 Tie-on Depth: 9029.95 ft j Current Datum: 37:25 7/18/1988 00 :00 Height 62 .00 ft Above System Datum: Mean Sea Level I Magnetic Data: 1/23/2008 Field Strength: 57670 nT Declination: Mag Dip Angle: 23.46 deg 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction I ft ft ft deg ~ ', --- --- - _ _ --- 31.00 ---0.00 - - - - _-0.00-- -- -__ - - 95.00 - - - --------~,i Plan: Plan #2 Date Composed: 1/23/2008 copy Mary's plan 2 ~rincipal: Yes Version: 3 Tied-to: From: Definitive Path Targets Map Map <--- Latitude ---> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. _ ft ft ft ft ft - -- I -__- _ _ __ 15-256 Fault 2 I - 62.00 -- -- 412.13 - - - -- 2655.67 5960168.00 680006.00 70 17 47.456 N 1 148 32 32.216 W -Polygon 1 62.00 412.13 2655.67 5960168.00 680006.00 70 17 47.456 N 148 32 32.216 W -Polygon 2 62.00 471.54 3317.29 5960243.00 680666.00 70 17 48.037 N 148 32 12.930 W 15-256 Fault 1 62.00 804.36 4092.41 5960594.00 681433.00 70 17 51.307 N 148 31 50.331 W ~ -Polygon 1 62.00 804.36 4092.41 5960594.00 681433.00 70 17 51.307 N 148 31 50.331 W ~i -Polygon 2 62.00 -411.59 4411.83 5959386.00 681781.00 70 17 39.346 N 148 31 41.041 W -Polygon 3 62.00 -852.70 4706.53 5958952.00 682086.00 70 17 35.006 N 148 31 32.461 W ~' -Polygon 4 62.00 -1098.22 4597.69 5958704.00 681983.00 70 17 32.592 N 148 31 35.637 W -Polygon 5 62.00 -1722.17 4628.98 5958081.00 682029.00 70 17 26.456 N 148 31 34.736 W -Polygon 6 62.00 -1098.22 4597.69 5958704.00 681983.00 70 17 32.592 N 148 31 35.637 W -Polygon 7 62.00 -852.70 4706.53 5958952.00 682086.00 70 17 35.006 N 148 31 32.461 W -Polygon 8 62.00 -411.59 4411.83 5959386.00 681781.00 70 17 39.346 N 148 31 41.041 W ~~ j 15-25B Fault 4 62.00 973.19 3212.10 5960742.00 680549.00 70 17 52.972 N i 148 32 15.990 W -Polygon 1 62.00 973.19 3212.10 5960742.00 680549.00 70 17 52.972 N 148 32 15.990 W I -Polygon 2 62.00 709.67 4120.19 5960500.00 681463.00 70 17 50.376 N 148 31 49.523 W I II 15-256 Fault 3 62.00 752.91 2288.58 5960500.00 679631.00 70 17 50.808 N 148 32 42.913 W -Polygon 1 62.00 752.91 2288.58 5960500.00 679631.00 70 17 50.808 N 148 32 42.913 W i -Polygon 2 62.00 1076.97 3646.69 5960856.00 680981.00 70 17 53.990 N 148 32 3.320 W 15-256 Fault 5 62.00 1169.90 1659.21 5960902.00 678992.00 70 17 54.911 N 148 33 1.256 W -Polygon 1 62.00 1169.90 1659.21 5960902.00 678992.00 70 17 54.911 N 148 33 1.256 W i -Polygon 2 62.00 978.94 2120.86 5960722.00 679458.00 70 17 53.032 N 148 32 47.800 W -Polygon 3 62.00 842.54 2686.83 5960599.00 680027.00 70 17 51.689 N 148 32 31.303 W Polygon 4 62.00 978.94 2120.86 5960722.00 679458.00 70 17 53.032 N 148 32 47.800 W ep ~ BP Alaska Baker. Hu hes INTEQ Plannin Re ort g g P °s ......,~ Company: BP Amoco f Field: Prudhoe Bay Site: PB DS 15 Well: 15-25 Wellpath: Plan 2, 15-256 Targets Name Description TVD +N/-S Dip. Dir. ft ft 15-256 Fault 7 62.00 709.60 -Polygon 1 62.00 709.60 ', -Polygon 2 62.00 838.38 15-256 Fault 9 62.00 1874.52 -Polygon 1 62.00 1874.52 -Polygon 2 62.00 291.11 ' -Polygon 3 62.00 -500.74 ', -Polygon 4 62.00 291.11 ', 15-256 Polygon 62.00 285.19 ', -Polygon 1 62.00 285.19 ' -Polygon 2 62.00 509.39 -Polygon 3 62.00 545.99 II -Polygon 4 62.00 308.96 i -Polygon 5 62.00 -75.42 ~~ -Polygon 6 62.00 338.20 ' -Polygon 7 62.00 697.51 ~, -Polygon 8 62.00 703.39 -Polygon 9 62.00 528.58 15-25B Fault 8 62.00 1169.52 ', -Polygon 1 62.00 1169.52 -Polygon 2 62.00 334.85 ', -Polygon 3 62.00 -259.72 !i -Polygon 4 62.00 334.85 ~~, 15-25B Fault 6 62.00 385.64 ', -Polygon 1 62.00 385.64 '~ -Polygon 2 62.00 -85.19 III 15-256 Target 3 8772.00 266.15 ~ 15-256 Target 2 8807.00 524.34 15-25B Target 1 8832.00 558.29 Annotation MD TVD ft ft 9029.95 8391.27 9050.00 8407.56 9070.00 8423.94 9120.00 8466.53 9145.00 8488.64 9245.00 8577.48 9776.16 8832.15 10126.16 8824.44 10401.16 8817.36 10851.16 8807.54 11201.16 8794.21 11401.16 8782.13 11501.16 8778.12 11850.00 8772.20 TIP KOP End of 9 Deg/100' DLS 4 5 6 7 8 9 10 11 12 13 TD Date: 1!23/2008 ~ Time: 14:43:37 Page: 2 Co-ordinate(NE) Reference: Well: 15-25, True North Vertical (TVD) Reference: 37:25 7!18/1988 00:00 62.0 Section (VS);Iteference: Well (O.OON,O.OOE,95.OOAZi) Survey Calculation Method: Minimum Curvature Db: OraGe Map Map +E!-W Northing Easting ft ft ft 4123.19 5960500.00 681466.00 4123.19 5960500.00 681466.00 4558.38 5960639.00 681898.00 1388.74 5961600.00 678705.00 1388.74 5961600.00 678705.00 1764.51 5960026.00 679118.00 2000.90 5959240.00 679373.00 1764.51 5960026.00 679118.00 2269.54 5960032.00 679623.00 2269.54 5960032.00 679623.00 2773.00 5960268.00 680121.00 3426.09 5960320.00 680773.00 4059.71 5960098.00 681412.00 4705.86 5959729.00 682067.00 4685.62 5960142.00 682037.00 3575.72 5960475.00 680919.00 2860.61 5960464.00 680204.00 2214.26 5960274.00 679562.00 4218.07 5960962.00 681550.00 4218.07 5960962.00 681550.00 5166.70 5960150.00 682518.00 5944.94 5959574.00 683310.00 5166.70 5960150.00 682518.00 4794.78 5960192.00 682145.00 4794.78 5960192.00 682145.00 5246.82 5959732.00 682608.00 <-- Latitude ---> <-- Longitude --> Deg Min Sec Deg Min Sec 70 17 50.375 N 148 31 49.436 W 70 17 50.375 N 148 31 49.436 W 70 17 51.639 N 148 31 36.748 W ii 70 18 1.842 N 148 33 9.136 W 70 18 1.842 N 148 33 9.136 W 70 17 46.268 N 148 32 58.192 W ~ 70 17 38.480 N 148 32 51.308 W 70 17 46.268 N 148 32 58.192 W ~I 70 17 46.209 N 148 32 43.472 W ' 70 17 46.209 N 148 32 43.472 W II 70 17 48.412 N 148 32 28.795 W 70 17 48.769 N 148 32 9.758 W ' 70 17 46.435 N 148 31 51.292 W 70 17 42.651 N 148 31 32.466 W !~ 70 17 46.719 N 148 31 33.048 W 70 17 50.259 N 148 32 5.394 W ', 70 17 50.320 N 148 32 26.239 W '' 70 17 48.602 N 148 32 45.081 W i 70 17 54.898 N 148 31 46.662 W 70 17 54.898 N 148 31 46.662 W 70 17 46.683 N 148 31 19.026 W II 70 17 40.830 N 148 30 56.356 W 70 17 46.683 N 148 31 19.026 W 70 17 47.185 N 148 31 29.866 W 70 17 47.185 N 148 31 29.866 W 70 17 42.551 N 148 31 16.699 W 4686.92 5960070.00 682040.00 3707.68 5960305.00 681055.00 2693.13 5960315.00 680040.00 70 17 46.010 N 148 31 33.012 W 70 17 48.555 N 148 32 1.550 W 70 17 48.893 N 148 32 31.122 W by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P g" u.....,~ Company: BP Amoco Date: 1/23/2008 Time: 14:43:37 Page: 3 Field: P rudhoe Bay Co-ordinate(NE) Reference: Well: 15-25, T rue North Site: P B DS 15 Vertical (TVD) Reference: 37:25 7/18/1988 00:00 62.0 Well: 15-25 Section (VS) Reference: Well (O.OON,O. OOE,95.OOAzi) Wellpath: P lan 2, 15-25 6 Survey Calculation Method: Minimum Curvature Db: Oracle i Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/1OOft degi100ft deg/100ft deg i 9029.95 35.37 81.37 8391.27 300.79 2232.33 0.00 0.00 0.00 0.00 9050.00 35.92 81.19 8407.56 302.56 2243.87 2.79 2.74 -0.90 349.13 ' 9070.00 34.12 81.19 8423.94 304.32 2255.22 9.00 -9.00 0.00 180.00 ', 9120.00 29.06 75.01 8466.53 309.61 2280.83 12.00 -10.12 -12.35 210.00 '~ 9145.00 26.50 71.65 8488.64 312.94 2291.99 12.00 -10.24 -13.45 210.00 ~I 9245.00 28.91 46.18 8577.48 336.79 2330.75 12.00 2.41 -25.47 270.00 9776.16 91.00 64.93 8832.15 561.92 2703.13 12.00 11.69 3.53 21.00 10126.16 91.41 106.94 8824.44 586.19 3044.40 12.00 0.12 12.00 89.00 10401.16 91.46 73.93 8817.36 584.14 3315.52 12.00 0.02 -12.00 270.50 110851.16 90.86 127.94 8807.54 501.93 3741.06 12.00 -0.13 12.00 90.00 11201.16 93.31 85.98 8794.21 402.11 4068.13 12.00 0.70 -11.99 274.00 11401.16 1 93.51 110.02 8782.12 374.54 4264.37 12.00 0.10 12.02 88.80 11501.16 91.06 121.78 8778.12 330.98 4354.09 12.00 -2.45 11.76 101.50 111850.00 90.79 79.91 8772.20 266.82 4689.09 12.00 -0.08 -12.00 270.00 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft .deg deg ft ft ft ft ft deg/100ft ft deg 9029.95 35.37 81.37 8329.27 300.79 2232.33 5960046.71 679585.43 0.00 2197.61 0.00 MWD , 9050.00 35.92 81.19 8345.56 302.56 2243.87 5960048.75 679596.94 2.79 2208.97 349.13 MWD 9070.00 34.12 81.19 8361.94 304.32 2255.22 5960050.78 679608.23 9.00 2220.11 180.00 MWD 9100.00 31.05 77.70 8387.22 307.26 2271.09 5960054.09 679624.04 12.00 2235.67 210.00 MWD i 9120.00 29.06 75.01 8404.53 309.61 2280.83 5960056.67 679633.71 12.00 2245.16 212.94 MWD ~ 1 9145.00 26.50 71.65 8426.64 312.94 2291.99 5960060.26 679644.79 12.00 2255.99 210.00 MWD 9200.00 27.25 57.11 8475.76 323.65 2314.24 5960071.50 679666.78 12.00 2277.22 270.00 1 MWD i 9245.00 28.91 46.18 8515.48 336.79 2330.75 5960085.02 679682.97 12.00 2292.53 282.98 MWD ' ~, 9300.00 35.15 50.28 8562.09 356.13 2352.54 5960104.87 679704.30 12.00 2312.55 21.00 MWD li ~1 9400.00 46.71 55.22 8637.54 395.43 2404.76 5960145.39 679755.58 12.00 2361.15 17.52 MWD 'i 9500.00 58.42 58.55 8698.23 438.58 2471.23 5960190.09 679821.01 12.00 2423.61 13.77 MWD 9523.39 61.17 59.20 8710.00 449.03 2488.54 5960200.94 679838.06 12.00 2439.94 11.73 15-25B' 9600.00 70.19 61.12 8741.52 483.69 2549.05 5960237.02 679897.73 12.00 2497.19 11.41 MWD 9700.00 82.00 63.34 8765.51 528.79 2634.80 5960284.13 679982.39 12.00 2578.69 10.61 MWD !' 9776.16 91.00 64.93 8770.15 561.92 2703.13 5960318.86 680049.92 12.00 2643.87 10.08 MWD '! 9800.00 91.05 67.79 8769.73 571.47 2724.97 5960328.93 680071.52 12.00 2664.79 89.00 MWD '' ', 9900.00 91.22 79.79 8767.74 599.33 2820.80 5960359.04 680166.66 12.00 2757.83 89.05 MWD 10000.00 91.34 91.79 8765.49 606.65 2920.32 5960368.70 680265.97 12.00 2856.33 89.29 MWD ', 10100.00 91.41 103.80 8763.08 593.12 3019.19 5960357.51 680365.12 12.00 2956.00 89.56 MWD '~ 10126.16 91.41 106.94 8762.44 586.19 3044.40 5960351.17 680390.50 12.00 2981.73 89.85 MWD I 10200.00 91.47 98.07 8760.57 570.22 3116.39 5960336.91 680462.84 12.00 3054.84 270.50 MWD ~ 10300.00 91.50 86.07 8757.97 566.61 3216.11 5960335.66 680562.61 12.00 3154.49 270.28 MWD I 10400.00 91.46 74.07 8755.38 583.82 3314.40 5960355.18 680660.46 12.00 3250.90 269.96 MWD 10401.16 91.46 73.93 8755.36 584.14 3315.52 5960355.53 680661.57 12.00 3251.99 269.65 MWD ', 10500.00 91.43 85.79 8752.86 601.51 3412.60 5960375.18 680758.21 12.00 3347.19 90.00 MWD '~, 10600.00 91.33 97.79 8750.45 598.39 3512.34 5960374.41 680857.99 12.00 3446.83 90.30 MWD 10700.00 91.18 109.80 8748.24 574.59 3609.26 5960352.91 680955.43 12.00 3545.45 90.59 MWD 10800.00 90.98 121.80 8746.36 531.16 3699.11 5960311.61 681046.28 12.00 3638.74 90.85 MWD 10851.16 90.86 127.94 8745.54 501.93 3741.06 5960283.38 681088.91 12.00 3683.08 91.08 MWD 10900.00 91.26 122.09 8744.63 473.93 3781.04 5960256.33 681129.53 12.00 . 3725.35 274.00 MWD 11000.00 92.04 110.11 8741.74 430.03 3870.64 5960214.57 681220.14 12.00 3818.43 273.89 MWD 11100.00 92.73 98.12 8737.56 405.71 3967.36 5960192.54 681317.40 12.00 3916.90 273.55 MWD 11200.00 93.31 86.11 8732.28 402.03 4066.97 5960191.21 681417.06 12.00 4016.45 273.04 MWD 1, 11201.16 93.31 85.98 8732.21 402.11 4068.13 5960191.31 681418.21 12.00 4017.60 272.41 MWD i 11300.00 93.49 97.86 8726.33 398.82 4166.56 5960190.35 681516.69 12.00 4115.94 88.80 MWD I 11400.00 93.51 109.88 8720.20 374.94 4263.28 5960168.76 681613.94 12.00 4214.38 89.51 MWD ~, 11401:16 93.51 110.02 8720.12 374.54 4264.37 5960168.39 681615.04 12.00 4215.50 90.24 MWD ' by ~ BP Alaska ~ s Baker Hu hes INTEQ Plannin Re ort g g P INTEQ Company: BP Amoco Date: 1/23/2008 Time: 14:43:37 Page: 4 Field: Prudhoe Bay Go-ordinate(NE) Reference: Well: 15-25, True North Site: PB DS 15 Vertical (TVD) Reference: 37:25 7/18/1988 00:00 62.0 Well: 15-25 Section (VS} Reference: Well (O.OON,O.OOE,95.OOAzi) Wellpath: Plan 2, 15-25B Survey,Calculation Method: Minimum Curvature Db: Oracle Survc~ MD Inc! Azirn SS TVD N/S E/W MapN ft deg deg ft ft ft ft 11500.00 91.09 121.64 8716.14 331.59 4353.10 5960127.54 11501.16 91.06 121.78 8716.12 330.98 4354.09 5960126.95 11600.00 91.04 109.91 8714.29 287.97 4442.87 5960086.06 11700.00 90.97 97.91 8712.53 263.98 4539.74 5960064.36 11800.00 90.86 85.91 8710.92 260.65 4639.49 5960063.39 11850.00 90.79 79.91 8710.20 266.82 4689.09 5960070.72 MapE DLS VS TFO __., Tool ft deg/100ft ft deg ---. 681704.76 __ 12.00 - 4307.64 101.50 MWD l 681705.76 12.00 4308.68 101.97 i MWD i 681795.52 12.00 4400.87 270.00 t MWD 681892.93 12.00 4499.46 269.78 MWD 681992.72 12.00 4599.12 269.57 MWD 682042.15 12.00 4647.99 269.38 2 3/8" _l~. i -T -~- - •,i.... ~.~~ WInLaHLI .aasH ie ueBOYY Lep1YYA ~ ~ .. _~-_.- - _ ..._. - ___ ~_,.._.~... 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LIY el HSLSL - r 00'OLLB ts'90>Y SLnei 9525[ Pu3 00'OLOB 18'L9LY Blp A0N8M 61^ ... ^Y ~ ~- 6 a aa p p N a0I1 arOS08 LL'StCB uoaM ' .T n i use Md [ass [ zee 009 iu ie,r dl S68L06 CBL[, L ilnee HSLSL / ~ w5 m-ia• s iN. c~. x...,, Ig0uuY OW 0111.. ^e - SNOI1tl1ONNY 5 avL - _ - - - - _ - .. . _- - E it e HSZSL - r~ll^ee HSL"SL Le,L rN ieM ~ ~LI F , ~ 1 4 L - ~~ ~ ~ ~ H~ 1 p 71^ed BSZ-SL i _ w 's xLw L }- T _ I ~ I i ~ ~ .1 ~- + .i I ` 4 _ {1 ' ~ v:L ~ i n t . _. i ,f _ . ; ..t j _, 10 II 0 w w .. a. ~. wu ...fi . ~~~ ~ ;. ~ ~ ~ .tL ~ ~ 1 I i I ~~. { ,vlrLw,elun H7,neeasLSL , ; i ~ l i f >i _ I r I ~ ~ - - __ a Ii { - ~ ~ CT ~ t ~1 _ : -1 `~ J L 11 ~ I i t { t I ;~ I: I r I i f i [' t ' ' ~ I I a,~le~,~,~,w~„ ~, WZ9 o0 B991/B LSZ [ o^joa yenapup nseayy iaooo NOO ~'sa l Isnl ~o l~s a . ~ - I ` I -. ~~ -{ i f L _ . ~ ~ t . --- I ~ I I . . ~t I t- 1 e M u I , e ton~I e•, uan e„ ~a.,s ~eaw~'~'gLS ~ a;ai an.l S2-Sl a eJ a as 13rN1 ale..p.oo woN y i 11 i 1[ I ' 1 ~ L L I I 1 { ~ 1 1 I ~ I } I 11 1 I ~ . E . _i~ l - } . t + ~L ~ + T i 4 { 1 ~y 1 I~ { ~ ~ .. f +-~ --F~ t - IT-f _ _ _ , ~ l ~1 I~ ~ i:. NU 1tlnbOfN 3UN3b3i3b - I 1 I D oe ~ 181yy00 LC 00~~aa0 00 0 Olutyel9 Y!BUO .. 0 100,"0 w~~~,..~~o.ae~~~: ,a e,~, ~~Z Ni s,s~a ~L e..LL a 9.s a ~osi a :,.H oo~le al iw I ,miw99a ,oo^ maNn ~0 . .. esLSe4~ ,~~~~w,,, Z„~eld dq ~~r~ „~l,p ~.. ~. ~ .+ ~~ ~ w~>y ( 9SZ-Sl'Z held lBdtlSZ-Sl)SZ-Sl (tlSZ-Sl l SZ-St ISZ-9t1 SZ-Sl -- ~~ 1HriM~ ~~~ III e~selb~ d8 N3`~3l _- BP Alaska LEGEND 15-09(15-09) 15-09A (15-09A) 15-10 (15-10) vui+~•x DeTUU 15-10A (15-1 OA) vt..:, +aau 15-25 (15-25) 'O°'9 15-25 (15-25A) 5 °i~ N Y 15-25 (15-25APB1) D: 90 98.9! TI. Sn 15-31 (15-31) D.."W.°~ ii ile inr+9w oo.ao o:.aon 9.r 15-31 (15-31 A) . 15-31(15-31B) v.9.9u9. ~ u,w °.i~a o.~-w °s,°9,u•"rerD 15-34(15-34) 9a.aa o.oo o.oo a+.oo 15-34 (15-34A) _ _ 15-49 (15-49) REFERENCE INFORMATION 15-49 1$-49A1L) 15-49 ~15-49AP81) ~~~ Co-ordinate N/E Reference: Well Centre: 15-25, True North ( 1 - 15-49(15-49PB1) Vertical (TVD Reference: 37:257/18/198800:0062.00 Section (VS~Reference: Slot-25 (O.OON,O.OOE) 15-49 Plan 15-498 ( ) Measuretl Depth Reference: 37:25 7/18/1988 00:00 62.00 Plan 2, 15-25B Calculatlon Method: Minimum CurvaWre Plan #2 9« ro rM ~ Tvo .w-9 .rl-w ow rs... v'-' r9. _ T Plan: Plan p2 (1 &26IPIan 2, 15-258) ~~~ M pzimulns to True NOdh Created By: BP Dale: 1/232008 BAKER Magneli gN~oriM1 23 Gfi' Ch9cked: Data: ~~lNE by So~oAn9°~8U93 ca.u~nmwmm~ ovte:lnyzo9e en NiUaelson EQ Mode1 9g9m1007 Ee~ iou~~naes .~~meawm • i WISLL DI'rAILS ANTI-COLLISION SETTINGS imc 'N/-S 'l./-W NUnhiUg !'asung Latitude Lm3giludc Slnl Interpuldtion MethuJMU Interval 5000 ?5 %30%5 1083.84 5959693.35 6777W.97 70°I7'43.4(17N 14%°33'49.6?3W >5 Depth Range From: 9029.95 TU. 11850.00 Maximum Range. 1381.90 Reference. Plnn_ Plan q2 IW 3' Iva / I _ inv \ n. 145 ~' ~ ~°~5-31A ISx _. i ~., )0541 ~, tuiSu Isu Im _ ` uo c u, I3x i3u - h° ~V05x4 ..x u3 les ~ ~" ~~ ,~ us - to 1\ Iu5 1 r° 'l 10619 d3 ~ ., - 110656 sn W - -. as. w 1 a5 3n - »~ ~ / i v IS G'7r X e + a ry ~0 „P ~' IS 33 , ryati \q `~\\ ~ lOd..l N 3tl a / ' \ l (/y~, ' .. s 75 1 ~, vx X36 ~ ~ ,r IUS / I.i 113 ` I n bse ¢u 136 - / - 17 i ~ ,35 0941 { 6y6. 143 Isu / -% ~~ I.n f,A ;; -, ~ ,~9x~ ~a ~r~ ~. tm mvdungl'y6n~4r.aru„~N nFtI'NJi4°el ,. c.iiv.mc.nv n i~„Its vm '1 PROfiRAM UrR fo Sun R ('y d ih I. - 9m 4.W P~ a- 47 1 ~ A. nnl, h.w .,s Hwn ue ~~~~Sii suz?Ys R~r-ou,u,,. 3~irinwlnaa Wrn 6zw4 vsrn°~ onRi„ Mglc n~.5 ~Ifr~K, InnJVU LEGEND ---- IS-10(15-10),Major Risk IS-l0A (IS-IOA), Major Risk - IS-25 (IS-25), Major Risk - I5-25 (I S-25A), Major Risk IS-25 (IS-25AP81),Major Risk - I5-31 (I 5-31), Major Risk IS-31(15-31A),Major Risk IS-31 (15-31 B),Ma~orRisk -- IS-49(15~9),Major Risk I5-49 (15-49A), Major Risk I5-49 (I S-49AP6I ), Major Risk I5-49 (I S-49P61), Major Risk I5-49 (Plan I S-49B), Major Risk - Plan 2, 15-25B Plan #2 `\ ~\1i \~~~`1~`1~~,t~1~~~1U!~, 1 I I,I n 11111 t ~.n nr uv wr .~.-w, ° I'~ ,~A°5 939( I 9448 by 954% 95q~~N ~~ ;' BAKER ae9e HUGHE ~,~~~~~ iNTEQ N~ ~~ SLCIION ULIAILS Sec MU Inc N.I 'IVU +N/-S -I:I-W ULeg TFace VS~w T~rgel I 9039-95 1517 8117 1{79117 300]9 ??3?33 000 U.W ?197.fi1 WSOW 35.9? 81.19 8407.56 302.Sfi ?243.87 2.79 14Y.13 ?211N Y7 3 W70.W 34.1? 81.IV 84?1.94 3043? 23551? Y110 180.W ???11.11 4 9120.W >>_Y.W 75(31 84fifi.53 1U961 ??8083 1?.00 ?IU.W ??45.Ih 5 9145W ?fi.SU 71.fi5 84%8.64 31?.Y4 ??91.99 12.W 210.W ?'_5599 6 924S.U11 2N.91 46-i% 8577,48 JJfi7Y 33311-75 12.(81 270.W 2?4?.S3 7 9776.16 91.W 64.91 8832.15 561,92 270.1-I1 1300 2100 ?641.87 R 10136.Ifi 91.41 IW.94 88?4.G1 586.IY 3U44.4U I2.W BY.W ?v81.73 Y I(14111.Ifi 91.4fi 73.93 881736 584.14 3.115.52 I?00 ?70.50 i?5199 10 10851.1 fi Y118fi I?].94 8807.54 501 Y3 3741 0h 1?.W W UO 1681 U8 11 II?Ol.lfi 93.31 85.Y8 87v4.21 40?.II 4068.11 130U ?74011 4111] W 1>_ 114111.Ifi 91.51 1111.0? 8782.1? 17451 4?64.17 1?UO 88.80 4?15.SU I1 115111-Ifi YI (Ifi 121.7X 877%-1? 330.Y% 4154.119 1?.Ib IIII.SU 4)U%.fi8 • BP Alaska by Anticollision Report ~' `.: 1NTEQ r- Company: BP Amoco Date: 1/23/2008 Time: 11:08:58 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 15 Co-ordinate(NE) Reference: Well: 15-25, True North Reference Well: 15-25 Vertical (T VDjRefere nce: 37:25 7!18/1988 00: 00 62.0 Reference Wellpath: Plan 2, 15-256 Db: Oracle ~ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'RYlf~aeells in this~elttfipal Plan & PLANNED PROGRAM it Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse it Depth Range: 9029.95 to 11850.0 Maximum Radius: 1381.90 ft 0 ft Scan Method: Error Surface: -- - - Trav Cylinder North I Ellipse + Casing -- Survey Program For Definitive Wellpath Date: 1/23/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 40 00 9029.95 1 : Schlumberge r GCT multishot GCT MS Schlumberger GCT multishot 9029 95 11850.00 Planned: Plan #2 V3 MWD MWD -Standard 1 Casing Points MD TVD Diameter Hole Size Name ft ft : - in - ih - _ _ - - _ r - - - ---- - - 'I 11850.00 8772.20 2.375 3.000 2 3/8" _ _ ------- - -- Summary <---------- Offset Wellpath -----------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 15 15-10 15-10 V1 10944.40 9825.00 353.37 498.86 -145.50 FAIL: Major Risk 'i PB DS 15 15-10A 15-10A V1 11212.96 9900.00 556.44 472.74 83.70 Pass: Major Risk I PB DS 15 15-25 15-25 V1 9050.00 9050.00 0.00 132.75 -132.75 FAIL: Major Risk PB DS 15 15-25 15-25A V3 9050.00 9050.00 0.00 132.62 -132.62 FAIL: Major Risk I PB DS 15 15-25 15-25APB1 V3 9050.00 9050.00 0.00 132.62 -132.62 FAIL: Major Risk ~I ', PB DS 15 15-31 15-31 V1 9042.00 9325.00 816.49 194.16 622.32 Pass: Major Risk ', PB DS 15 15-31 15-31A V4 10694.84 12000.00 64.15 245.81 -181.67 FAIL: Major Risk I ', PB DS 15 15-31 15-31 B V6 9042.00 9325.00 816.49 195.29 621.20 Pass: Major Risk ', PB DS 15 159 15-49 V2 10625.00 10725.00 948.32 321.30 627.02 Pass: Major Risk I '~, PB DS 15 15-49 15-49A V5 9852.93 10625.00 495.34 271.39 223.95 Pass: Major Risk 'I ~' PB DS 15 15-49 15-49AP61 V2 9994.08 9907.70 1012.91 283.10 729.81 Pass: Major Risk PB DS 15 15-49 15-49P61 V1 10009.82 10025.00 1048.86 289.14 759.72 Pass: Major Risk PB DS 15 15-49 Plan 15-496 VO Plan: 1 Out of range Site: PB DS 1 5 Well: 15-10 Rule Assigned: Major Risk Wellpath: 15-10 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable ~ MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglHSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft !I 10878.50 8807.07 8500.00 7489.34 25.10 109.21 141.15 16.49 9.625 1374.52 162.47 1212.05 Pass 10881.03 8807.02 8525.00 7513.69 25.21 109.87 141.00 16.64 9.625 1350.14 163.86 1186.27 Pass 10883.48 8806.98 8550.00 7538.06 25.31 110.51 140.87 16.80 9.625 1325.76 165.31 1160.45 Pass 10885.86 8806.93 8575.00 7562.47 25.42 111.13 140.75 16.97 9.625 1301.38 166.80 1134.57 Pass ~i, 10888.16 8806.88 8600.00 7586.90 25.52 111.75 140.65 17.15 9.625 1277.00 168.36 1108.65 Pass ' I ~I10890.42 8806.84 8625.00 7611.36 25.61 112.34 140.58 17.34 9.625 1252.66 169.99 1082.66 , Pass ii 10892.68 8806.79 8650.00 7635.87 25.71 112.93 140.52 17.55 9.625 1228.39 171.77 1056.62 Pass ~ 10894.95 8806.74 8675.00 7660.40 25.81 113.51 140.49 17.79 9.625. 1204.21 173.71 1030.50 Pass 10897.23 8806.69 8700.00 7684.96 25.91 114.10 140.48 18.06 9.625 1180.13 175.81 1004.32 Pass ~ i 10899.47 8806.64 8725.00 7709.56 26.00 114.67 140.50 18.35 9.625 1156.14 178.07 978.07 Pass 10901.64 8806.60 8750.00 7734.17 26.10 115.23 140.55 18.66 9.625 1132.18 180.44 951.75 Pass Iii 10903.72 8806.55 8775.00 7758.82 26.18 115.77 140.63 18.98 9.625 1108.28 182.93 925.35 Pass 10905.71 8806.51 8800.00 7783.50 26.27 116.29 140.74 19.33 9.625 1084.43 185:56 898.87 Pass 10907.62 8806.46 8825.00 7808.19 26.35 116.78 140.88 19.70 9.625 1060.63 188.31 872.32 Pass 10909.46 8806.42 8850.00 7832.91 26.42 117.25 141.05 20.10 9.625 1036.90 191.22 845.69 Pass 10911.23 8806.38 8875.00 7857.65 26.50 117.71 141.26 20.52 9.625 1013.25 194.29 818.96 Pass 10912.94 8806.34 8900.00 7882.41 26.57 118.15 141.50 20.96 9.625 989.69 197.54 792.15 Pass 10914.56 8806.30 8925:00 7907.19 26.64 118.57 141.78 21.44 9.625 966.21 200.96 765.24 Pass 10916.12 8806.26 8950.00 7931.98 26.70 118.97 142.10 21.94 9.625 942.83 204.59 738.24 Pass _10917.59 _8806_22 8975A0 7956.80 26.76 119.36 142.46 22.48 9.625 919.56 208.43 711.13 Pass I C~ • Rig Floor to Top of Well DS 15-258 2.25 9.23 •_ 5.00 ~- 12.65 ~'~ ~ 13.56 ~`- 21.•'16" 5000 psi , R-24 Mud ~~ross 14.89 HCR Choke Line 16.10 ~ ~ 16.66 ~- ~ L" ~- 7 1,'t6^ X 3 tis^ Flanged Adapter 20.04 • ~ Swab Valve Tree Size ~~ F w Tee -~ 22.88 p SSV 24.86 -- ~ Master Valve Lock Down Screws Ground Level Alaska Department of Natural Resources Land Administration System Page T of :~, - _ ... ~. -~~;,,",~~r ~ ~e~;ct~ Sfa#e CaE~ins r~~u["~ ~~~~ut's ~4laka A R Caste aunmr File Type: A~r_ File Number: 28307„ ~ - Printable Case Fite Summary See Township, Range, Section and Acreage? New Search ~' Yes ~" No ~.~.~._~... -- - __ ~._~ I.A`.S Men~~ ~ Case Abstract i Gase Detail ~ t_and Abstract ~. File: ;~DL 25307 - S~<~rch Fov Status ~'!at U}~dates ~~ of CC `~ ~'~p(1S Customer: 000] 07377 BP EXPLORATION (ALASKA) TNC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCI-IORAGE AK 995196612 Case Type E.=~ O1 L & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV O1L AND GAS Case Stators: 3~ ISSUED Status Dare: 09/14/196 Total Acres: 2560.000 Date Initiated : OS/2S/] 96~ Office ofPrimarv Responsibility: DOG DN O[L AND GAS Last Transaction Date: 12/04/2006 Case Subtype : NORTH SLOPE Last Ti•unsac°tion: AA-NRB ASSIGNMENT APPROVED 1(c~i~rdiufr: U Township: O'11N R«~age: 014E Section: 13 Sectirut ,lc~~r.i.~ 610 Search ~13t~ l<~i-<<lr~ur U Township: ill 1N Range: 014E ~'c°c~li~u~.~ I ~ ,5'~~~~li~~fr Acres: (i~~li ~l~ri~liu~l: U Township: (_)11N Range: OI~II; .1rclirur.~ '> ~'~~~~[ir~>> -4cres: 640 1lrricliurr: U l inrn~f~i~~: O 11N Kange: O1<~1~: ,~~~cti~~n: ~ 1 :S~e~cuon Ac3'es: 640 Legal llescrii~tion OS-2~-1965 *St1LENOTICE LI'GAL DESCRIPTION* CI ~-12~ 11 N 1 ~IE U1LI 13,1 ~1, 23, Z=t 2560. DO U- 3- 7 Last updated on 02/12/2008. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28307&... 2/ 12/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME /~.Q'L/ /S v?S/~ PTD# c~0 ~O~~D / ~'~i ~. Development Service Exploratory Stratigraphic Test Non-Conventional Well ~~~ FIELD: ~i4lOE''' ~,~~ POOL: ~,e!/,Oh~O~' Ay ~OOG 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), alt 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 throu h tar et zones. Non-Conventional Well pease note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv 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 ro ram. Rev: I/1 I/2008 >~~ ~~ ~~~~((~~'( Field 8 Pool PRUDHOf BAY, PRUDHOE OIL •640150 Well Name: PRUDHOE BAY UNIT 15-258 Program DEV Well bore seg ^ PTD#:2060240 Company RP ~xpi ORATION (ALASKA} INC Inftial Class(i•ype D EV I PEND GeoArea 890 Unif 11650 On10ff Shore ~- Annular Disposal ^ Administration 1 P®tmftfa@attached ----- ------ --- ---- -- --- ---~--- ----- - ------ ------ - --- - --- -- --- ------ 2 Lease numberePPropriate---- ---- -- -- --- - ----- -Yes--- ---- -- ---- - - ------ -------- - - - -- - - - -- 3 tJniqueweltnameandnumber.----- ----- -- - - ---- ---Yes- ------ - -- - -- ----- - ------ - ----- - ---- ------ - 4 Wslilocakedina-defined-pool - -- - -- -- -- ----- - YeS- - ------------------------------ - - -- ----- ------ ------ 5 Welllocakedproperdistanoeftomdriilingunikboundary------------- ------- ---Yes--- ------------------------------------------------------------------ 6 _V~elllccatedPtoPardiskancaframotherwells--- --- - - - -- ----- Y®s -- ------ - ----- -- -- --- -- -- --- - -- - -- ---- 7 Suft'iiciantacrsaEeavai~blaindriilingunJt-----.-------------- ----------Yes--- ----------------------------------------------------------------------- 8 If deviated,iewellboreplat_included ------- --- - -- -- - -- -Yes--- - -- ------ -- -- - --- -- --- --- -- -- ---- -- ---- 9 OpetatoronlyaffectedDa~Y----- ---------- -- ~ ---- - ------ Yes--- -- ----- -- -- -- ---- ---------- - -- ------- 10 _Operatorhas_apptopriatebondinforce____--------------_- -----_-----Yes--- -.-Qlaoket6ond#6154193--.------------------------------------------------- 11 PetmitoanbeisauedwRhautconsenrationorder----------------- ---_-___--Yes.-- -----------------------------------------------------.------------------ Appr Date 12 PetmikcanbaisauadwithoutacMinisttatnte_apP[oval-------------- -----------Yes--- ------------------------------------------------------------------------ 211212008 X 13 Canpermlibaapprovedbaforal5-daywait------------------- -----------Yes--- --------------------------------------------------------------------- ACS 14 _1NeIIIQCatadwlthinareaendatratasuthorizodbyJnjaGtion9td®t#(putlp#in_commenis)-(For-NA____ ________________________________.__.__________--_______-__--------- 15 Ali walls-wl~in114_mileataaoftavigwidentifiad(Fotservicewelicnly)---- ---------- NA--- ---------------------------------------------------------------------- 16 Pre•producedinjec~or. durati°n_ofP~-~~uctlcntessihan3monihs_(Farsgrv~ewellonly).--NA--- -------------------------------------------------------------------- 17 ryonconven.gas_ccoform tcAS31,05,034(~1•A),4.2•A•D)- --- - -~- -----!`~---- ----- - -- - -- --- -- ----- --- ---- ---- -- -- ---- Engineering 18 Conductorat[ing_provlded__.---_---____.-._---------- ----------t~A._ ____ConductorsetinpSl6.25(1136.060).----------------.-.-----------------------_-- 19 SutfacecasingprotectsallknownUSRWs____________________ _________.NA____ ____NOaquifers, A1046,_conclusion5,_________________--_____-__----__---_---_-- 20 GMTvoladequatetocirculateoncondu~or_8,surf_csg------------- ----___--NA__ _.__Sur-acecasUgaetJnt5~25,._______._-__________--______.---________---_-- 21 GMT-vo(adgquatetctie"in long stringioss~rfcsg----------------- ----------- NA--- ----Ute[mediatecasingsetin_15-2~,--------------------------------.----------- 22 GMT_v~illCoverallknawnprodu°tivebor4xona------------------ -----------Y~s--- ------.------------------------.---------------------------~-------- 23 Casing designs adequatefotC,T,B&_permafCoat---------------- -------- --Yes--- -------------------------------------------------------------~--------- 24 -Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ Rig equipped with steel pits, ~lo_raserva pit planned•_ All waste_to approved disposal well(s), - _ _ _ - . _ _ - _ _ _ _ 25 If-a_ro•dtfl{ahas.al0.403 forabandcnmenibaenaPRroved----------- -----------Yes--- ----30&047-----------------.-------------------------------------------- 26 Adequate-wellbore s®paraUon_ptopcsed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ . Proximity analysis performed, Nearest segment is abandoned portion of 15.25A and.pakhs diverge. _ _ _ _ _ _ _ _ 27 If.divedar-required, doesJtmeetregulations__---------------- -----_-._-- NA____ ___BQPStackwillalteady.beinplace.----------------------------------------------- Appr Date 28 Drilling fluid program sctramatic & equip list adequate_ - _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ - _ _ Maximum expected formation pressure X7.2 E_MW._ Planned MVy 8.6 pp9• - - , - - - - - - - - - - - - - - - - - - - - TEM 2!131008 29 BOPEs,-do theymeetregulation_____._--____._--__--__ .----__---Yea--- ------------------------------------------------------------------ 1/ ~ 30 BOPI=_prass rating appropriate; teat to-(put psig in c°mments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ t~OP testpianned, _ _ _ _ MASP calculated sf 2391 psi, 3500_psi 31 Choke-manlfoidcomPJieawlAPtRP•53(May84)_________________ ___________Yes_-_ _ _ _ _ - _____-__-_ 32 !Ncrkwiltoccu[with9ui_oparationsbuidown------------------- --------_Yes--- ----------------------------------------------------~----------------- 33 Js presence of H25 gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ .. _ _ _ _ _ _ - _ _ - _ _ Yes . _ _ _ H2S is repQded_at DS 15•_ Mud should preclude H2S_on_rig, Rg.has sensors and alarms._ _ - - _ . - _ _ _ _ _ _ _ 34 _Mechenicakcooditlonofv~ellawithinAORverlfled(Forsetvlcewellonly)--- -------.- NR---- ---------------------------------------------------------------------- t3eolagy 35 Petmitcan be issued wlo hydrogenaulfide meassares _ _ - - . - - - - - - - - - - - - _ _ - - - - No- _ _ _ _ _ _ _ Max. H2S well 15~20C= 40Ppm; well t5-25=10Ppm= - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 36 Data_preseMedonpotentl81ove1pressurezones----- - -- - ------ -NA--- -- -- -- -- - ---- -- ------- - ----- - --~ ---- Appr Data 37 Seismlcanalyais-ofshallowgas_z9nes-- ---- - -- --- -~ ~---- ----~-- ----- -- ---- -- ----- ------ -- --- --- - - ------ ACS 211212006 38 SaabedcondJtionsurvey.(1foPf-share)----------------------- ----------- NA--- -.--------------------- 39 Coniacinamelphoneforweekly_Progresarapods_(exploratoryonly]______ ________--Yes--- ----GtegSarber-•564.4330----------------------------------------------------- Geologic Comm~sioner: Engineering Data; Co real er: Date mis Date ~~~~a~~ ~~ -i 3 • o g • Welt 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. • **** REEL HEADER **** MWD 08/07/07 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/04/11 1912088 01 2.375" CTK *** LIS COMMENT RECORD *** ~~~!!!!!!!!!!!!!!!~ Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8808.0000: Starting Depth STOP.FT 11748.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 15-25B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 43.407"N 148 deg 33' 49.623"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 11 Apr 2008 API API NUMBER: 500292184202 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 22 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 62 DMF DF EKB .F 0 EDF .F 62 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ao~-oa`"l ~- J~~~ i • (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 PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 11 Apr 2008 per Doug Stoner with BP Exploration (Alaska),. Inc. (8) Tied to 15-25B at 8984 feet MD (8992.2 feet TVDSS). (9) The sidetrack was drilled from 15-25A through a milled window in 5 1/2 inch liner. Top of window 9009 ft.MD (8312.1 ft.TVDSS) Bottom of window 9015 ft.MD (8317.1 ft.TVDSS) (13) The interval from 11714 feet to 11738 feet MD (8698.6 feet to 8692.9 feet 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 RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8812.24, 8812.44, ! 0.207031 8827.37, 8827.58, ! 0.207031 8832.76, 8832.97, ! 0.207031 8835.66, 8836.08, ! 0.414062 8873.59, 8873.38, ! -0.207031 8877.16, 8877.37, ! 0.208008 8882.55, 8883.17, ! 0.62207 8888.04, 8887.83, ! -0.207031 8901.93, 8902.55, ! 0.621094 8905.66, 8906.28, ! 0.621094 8910.01, 8910.64, ! 0.62207 8916.23, 8916.23, ! 0 8919.14, 8919.14, ! 0 8922.25, 8922.66, ! 0.415039 8924.32, 8924.73, ! 0.414062 8926.6, 8926.18, ! -0.415039 8928.46, 8928.46, ! 0 9012.55, 9012.55, ! 0 9013.59, 9014, ! 0.414062 9015.66, 9015.87, ! 0.207031 9021.26, 9021.67, ! 0.414062 9025.2, 9024.99, ! -0.207031 9027.68, 9027.68, ! 0 9029.14, 9029.55, ! 0.415039 9035.56, 9035.56, ! 0 9044.68, 9044.27, ! -0.414062 9049.04, 9048.83, ! -0.207031 9057.37, 9057.37, ! 0 9063.59, 9063.38, ! -0.207031 • 9069.19, 9068.77, 9075.82, 9076.03, 9093.02, 9091.99, 9096.34, 9095.51, 9098.21, 9097.79, 9100.07, 9099.45, 9105.97, 9104.31, 9114.88, 9114.26, 9120.69, 9119.24, 9123.17, 9121.52, 9126.7, 9124.83, 9128.36, 9126.91, 9134.99, 9130.64, 9155.51, 9155.93, 9201.47, 9201.88, 9235.55, 9235.97, 9247.37, 9247.58, 9270.38, 9270.38, 9279.03, 9278.61, 9289.81, 9290.22, 9294.58, 9293.95, 9296.03, 9295.4, 9297.68, 9297.27, 9300.17, 9299.34, 9301.42, 9301, 9303.28, 9302.66, 9313.43, 9313.02, 9316.13, 9315.09, 9319.24, 9319.03, 9326.91, 9325.87, 9331.67, 9330.64, 9332.71, 9332.29, 9337, 9337, ! 9339.49, 9338.87, 9343.22, 9341.98, 9347.37, 9346.13, 9348.2, 9347.58, 9350.48, 9349.44, 9388.2, 9387.58, 9393.17, 9391.93, 9395.66, 9394.62, 9399.19, 9398.77, 9445.55, 9444.1, 9447.83, 9445.97, 9450.94, 9449.7, 9464.42, 9462.76, 9470.22, 9468.36, 9480.74, 9477.83, 9484.05, 9481.57, 9503.43, 9502.39, 9510.06, 9508.41, 9513.8, 9512.55, 9515.66, 9514.42, 9518.77, 9517.53, 9521.26, 9520.22, 9546.28, 9544.62, 9550.43, 9549.19, 9555.4, 9553.12, 9558.1, 9556.44, 9560.59, 9559.34, 9563.9, 9562.25, 9566.18, 9564.32, 9569.09, 9566.6, 9575.1, 9573.23, 9584, 9582.55, 9591.88, 9589.81, 9600.17, 9598.31, ! -0.414062 ! 0.207031 ! -1.03613 ! -0.829102 ! -0.414062 ! -0.62207 ! -1.6582 ! -0.621094 ! -1.45117 ! -1.6582 ! -1.86621 ! -1.45117 ! -4.35352 ! 0.414062 ! 0.415039 ! 0.415039 ! 0.207031 ! p ! -0.415039 ! 0.414062 ! -0.62207 ! -0.62207 ! -0.414062 ! -0.829102 -0.414062 ! -0.62207 ! -0.415039 ! -1.03613 ! -0.207031 ! -1.03613 ! -1.03613 ! -0.415039 0 ! -0.621094 ! -1.24316 ! -1.24414 ! -0.62207 ! -1.03711 ! -0.62207 ! -1.24316 ! -1.03711 ! -0.414062 ! -1.45117 ! -1.86523 ! -1.24316 ! -1.6582 ! -1.86523 ! -2.90234 ! -2.4873 ! -1.03711 ! -1.6582 ! -1.24414 ! -1.24414 ! -1.24414 ! -1.03711 ! -1.6582 ! -1.24414 ! -2.28027 ! -1.6582 ! -1.24414 ! -1.6582 ! -1.86523 ! -2.4873 ! -1.86523 -1.45117 ! -2.07324 ! -1.86523 • 9604.73, 9602.87, ! -1.86523 9611.78, 9609.71, ! -2.07324 9616.34, 9615.93, ! -0.415039 9620.49, 9619.04, ! -1.45117 9622.56, 9621.52, ! -1.03711 9627.95, 9627.33, ! -0.62207 9633.22, 9632.39, ! -0.829102 9637.78, 9637.16, ! -0.62207 9643.17, 9642.76, ! -0.414062 9648.98, 9648.36, ! -0.62207 9654.37, 9653.95, ! -0.415039 9669.86, 9669.86, ! 0 9681.88, 9682.09, ! 0.207031 9701.98, 9703.22, ! 1.24316 9713.8, 9715.25, ! 1.45117 9731.05, 9728.98, ! -2.07324 9734.37, 9732.5, ! -1.86621 9738.72, 9736.44, ! -2.28027 9741, 97 39.55, ! -1.45117 9747.01, 9745.35, ! -1.6582 9750.95, 9749.09, ! -1.86621 9753.23, 9751.57, ! -1.65918 9760.28, 9758.41, ! -1.86621 9763.39, 9761.52, ! -1.86621 9771.89, 9769.4, ! -2.4873 9776.66, 9773.55, ! -3.10938 9784.48, 9782.4, ! -2.07324 9785.93, 9784.06, ! -1.86523 9790.28, 9788.41, ! -1.86621 9796.49, 9794, ! -2.48828 9800.22, 9798.77, ! -1.4502 9807.68, 9805.2, ! -2.4873 9816.18, 9814.32, ! -1.86523 9818.88, 9816.6, ! -2.28027 9821.16, 9819.09, ! -2.07324 9823.44, 9821.78, ! -1.6582 9826.76, 9824.89, ! -1.86523 9831.32, 9829.04, ! -2.28027 9833.39, 9831.11, ! -2.28027 9834.63, 9832.35, ! -2.2793 9847.84, 9845.56, ! -2.28027 9865.88, 9863.8, ! -2.07324 9867.95, 9865.67, ! -2.28027 9874.53, 9873.7, ! -0.829102 9883.65, 9880.74, ! -2.90234 9886.13, 9883.85, ! -2.28027 9888.62, 9886.34, ! -2.28027 9891.11, 9889.24, ! -1.86621 9937.32, 9935.45, ! -1.86621 9946.03, 9944.16, ! -1.86523 9962.76, 9961.1, ! -1.6582 9973.12, 9970.43, ! -2.69434 10126.5, 10125.1, ! -1.45117 10133.4, 10132.3, ! -1.03711 10147.7, 10143.1, ! -4.56055 10152, 10149.1, ! -2.90234 10155.5, 10151.8, ! -3.73145 10159.2, 10156.1, ! -3.10938 10164.6, 10161.9, ! -2.69434 10169, 10166.1, ! -2.90234 10180.2, 10177.9, ! -2.2793 10187.9, 10185.9, ! -2.07227 10230.3, 10229.9, ! -0.414062 10254.9, 10251.4, ! -3.52441 10260.1, 10256.2, ! -3.93945 10273.2, 10272.8, ! -0.414062 10280.4, 10277.5, ! -2.90234 • i 10285.6, 10283.3, ! -2.28027 10312.9, 10309.8, ! -3.10938 10320.3, 10318.7, ! -1.6582 10322.6, 10320.7, ! -1.86523 10327.6, 10324.7, ! -2.90234 10350.6, 10347.5, ! -3.10938 10358.9, 10356.2, ! -2.69531 10392, 10389.3, ! -2.69531 10399.1, 10396.4, ! -2.69434 10426.1, 10423.8, ! -2.28027 10470.2, 10469.2, ! -1.03613 10476.9, 10476.6, ! -0.207031 10510, 10505.7, ! -4.35254 10513.3, 10509.6, ! -3.73145 10737.8, 10733.2, ! -4.56055 10767, 10761.6, ! -5.38965 10770.5, 10764.9, ! -5.59766 10802.4, 10799.5, ! -2.90137 10807.8, 10805.5, ! -2.28027 10815.7, 10810.7, ! -4.97461 10821.7, 10815.7, ! -6.01172 10823, 10818.2, ! -4.76758 10845.6, 10843.7, ! -1.86621 10860.7, 10855.9, ! -4.76758 10885.6, 10882.5, ! -3.11035 10927.1, 10924.8, ! -2.28027 11181.4, 11176.6, ! -4.76758 11259, 11254.4, ! -4.56055 11284.7, 11279.7, ! -4.97461 11287.2, 11282.4, ! -4.76855 11356.9, 11350.1, ! -6.84082 11360, 11354.8, ! -5.18262 11367.1, 11359.8, ! -7.25488 11373.1, 11365, ! -8.08398 11388.6, 11385.3, ! -3.31641 11392.6, 11388.4, ! -4.14551 11399.6, 11394.4, ! -5.18262 11444.2, 11438.4, ! -5.80469 11447.5, 11442.3, ! -5.18262 11459.1, 11453.3, ! -5.80371 11470.1, 11463.9, ! -6.21973 11482.5, 11474.4, ! -8.08398 11487.1, 11479.2, ! -7.87695 11491, 11484.2, ! -6.84082 11494.1, 11487.7, ! -6.42676 11527.7, 11524.6, ! -3.10938 11538.3, 11535.1, ! -3.10938 11546.1, 11543, ! -3.10938 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 285 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 r *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 15-25B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 15-25B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** i !!!!!!!!!!!!!!~~~!! Remark File Version 1.000 Data presented here is final and has been depth adjusted to a PDC (Primary Depth log provided by Schlumberger GR CNL dated 11 Apr 2008 per Doug Stoner with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 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 8 Total Data Records: 70 Tape File Start Depth = 8808.000000 Tape File End Depth = 11738.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 79 records... 54 bytes 4124 bytes *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 15-25B.xtf LCC 150 CN BP Exploration (Alaska) WN 15-25B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!~~!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 Curves: Name Tool Code Samples Units Size Length r • 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 140 Tape File Start Depth = 8809.000000 Tape File End Depth = 11737.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 149 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/04/11 1912088 O1 **** REEL TRAILER **** MWD 08/07/07 BHI O1 4 4 4 4 8 n Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 8808.0000 -999.2500 -999.2500 8808.5000 -999.2500 -999.2500 8900.0000 67.2479 -999.2500 9000.0000 -999.2500 -999.2500 9100.0000 33.4599 31.7319 9200.0000 22.1472 15.4358 9300.0000 120.7430 30.3357 9400.0000 34.5112 25.2795 9500.0000 25.4105 76.5695 9600.0000 89.8064 55.8658 9700.0000 66.8703 104.3108 9800.0000 113.7591 42.1237 9900.0000 61.6271 52.2146 10000.0000 61.8201 28.3674 10100.0000 54.9269 95.2658 10200.0000 71.6600 68.0393 10300.0000 62.6441 112.2480 10400.0000 57.0870 70.3880 10500.0000 75.9583 134.0868 10600.0000 54.7872 161.1830 10700.0000 47.4226 112.2729 10800.0000 127.5170 247.2253 10900.0000 60.0251 102.3449 11000.0000 57.9439 163.1347 11100.0000 55.8881 129.1760 11200.0000 70.9947 115.9428 11300.0000 61.3599 124.6040 11400.0000 56.7077 114.2871 11500.0000 66.7795 164.9334 11600.0000 54.8605 130.0324 11700.0000 127.4570 97.2414 11738.0000 -999.2500 -999.2500 Tape File Start Depth = 8808.000000 Tape File End Depth = 11738.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GR ROP 8809.0000 -999.2500 -999.2500 8809.2500 -999.2500 -999.2500 8900.0000 66.2000 -999.2500 9000.0000 -999.2500 -999.2500 9100.0000 40.2000 39.8000 9200.0000 24.2000 15.6000 9300.0000 149.9000 25.5000 9400.0000 31.1000 25.1000 9500.0000 23.9000 78.1000 9600.0000 178.9000 78.9000 9700.0000 67.9000 171.4000 9800.0000 117.1000 36.9000 9900.0000 61.1000 62.0000 10000.0000 60.4000 64.1000 10100.0000 57.5000 92.4000 10200.0000 78.4000 85.2000 10300.0000 57.7000 112.8000 10400.0000 54.0000 127.7000 10500.0000 62.1000 130.8000 10600.0000 53.6000 151.2000 10700.0000 52.3000 114.8000 10800.0000 109.4000 81.0000 10900.0000 60.6000 101.6000 11000.0000 53.4000 126.7000 11100.0000 56.8000 130.1000 11200.0000 72.2000 121.5000 11300.0000 58.6000 124.2000 11400.0000 95.0000 105.5000 11500.0000 66.9000 174.6000 11600.0000 49.9000 98.4000 11700.0000 176.7000 107.9000 11737.7500 -999.2500 -999.2500 Tape File Start Depth = 8809.000000 Tape File End Depth = 11737.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • Tape Subfile 4 is type: LIS
