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200-186
roject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing !~,~ ~ [] RESCAN [] Color items: Grayscale items: Poor Quality Originals: Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) D Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) D Logs of various kinds BY: BEVERLY ROBIN VINCENT L~MARIA) SHERY WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYI,~INDY [] Other Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~ YES ____. NO y lNCENT SHERYL MARIA WINDY DATE: ' SI Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA~E FOUND: ...... ~ NO RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: /si Quality Checked 12/10/02Rev3N OTScanned.wpd STATE OF ALASKA AL .KA OIL AND GAS CONSERVATION CO, iSSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAY 0 2014 1. Operations Performed: .A/`"1*-{GCC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing 0 Pull Tubing 0 Stimulate-Frac ❑Waiver 0 Other ElChange Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Jet Pump Conversion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 200-186 , 3. Address: 0 Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22867-01-00 • 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025518&380110 MPE-24A 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Schrader Bluff 11. Present well condition summary: Total depth: measured 12860' feet Plugs:(measured) None feet true vertical 4204' feet Junk:(measured) None feet Effective depth: measured 12860' feet Packer: (measured) 9135' feet true vertical 4204' feet Packer: (true vertical) 4204' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1490 470 Surface 10041' 9-5/8" 36'- 10077' 36'-4309' 5750 3090 Intermediate Production 9517' 7" 28'-9545' 28'-4316' 7240 5410 Liner 3432' 4-1/2" 9428'-12860' 4282'-4204' 8430 7500 Perforation Depth: Measured Depth: Slotted Liner:9532'-12816' feet True Vertical Depth: Slotted Liner:4312'-4204' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# 13Cr85 9267' 4240' Packers and SSSV(type,measured and true vertical depth): 7-5/8"x 4-1/2"HES TNT Packer 9135' 4204' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: SCANNED MAY 2 9 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 500 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 0 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 IN 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: J.E.B.Bolen,564-5110 N/A Email:J.E.B.Bolen@bp.com Printed Name: Joe Lastufk rA Title: Drilling Technologist Signature: 564-4091 Date: 5/A I'I 4 Form 10-404 Revised 10/2012 V,L F 57o/i4 p�@ubr�itOri���i Onl ��•:; e��/y R 6rM�7 1 tett °°° North America-ALASKA-BP Page 1 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102)-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM 'Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table©57.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/10/2014 09:00 - 10:00 1.00 MOB P PRE MOBILIZE EQUIPMENT IN PREPARATION FOR RIG MOVE. MOVE CREW TRAILER. 10:00 - 11:00 1.00 MOB P PRE PJSM.PULL OFF MPE-19. 1-NOTIFY MPE PAD OPERATOR. 1-DAY TOOLPUSHERS AND WSL ON LOCATION. PULL OFF OF MPE-19 AND MOVE TO ,MPE-24A. 11:00 - 12:00 1.00 MOB P PRE I MOVE RIG FROM MPE-19 TO MPE-24A. -LAY MATS AND PREP TO BACK OVER WELL. DAY TOOLPUSHER AND WSL ON LOCATION. NOTIFY MPE PAD OPERATOR. -BACK RIG OVER MPE-24A. -SHIM UP AROUND RIG AND LEVEL SAME. '-SPOT CUTTINGS TANK AND CREW CHANGE TRAILER. -TAKE ON 120°F,8.5 PPG BRINE. ACCEPT DOYON 16 ON MPE-24AAT 12:00 HRS ON 04/10/2014. 12:00 - 14:30 2.50 WHSUR P DECOMP f PJSM.R/U CIRCULATING EQUIPMENT. R/U HARD LINE TO FLOW BACK TANK. R/U LINES IN CELLAR. -R/U KILL MANIFOLD IN CELLAR. -PRESSURE TEST ALL SURFACE LINES TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED _ MINUTES EACH.GOOD TESTS. 14:30 - 16:00 1.50 WHSUR P DECOMP SAFETY MEETING WITH BP WTL,BP SUPERINTENDENT,DOYON SUPERINTENDENT AND RIG CREW. 16:00 - 18:00 2.00 WHSUR P DECOMP R/D HARD LINE AND STEAM IN CELLAR DUE j TO ICE PLUG. -R/U HARD LINE TO FLOW BACK TANK. -PRESSURE TEST HARD LINE TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. 18:00 - 20:30 2.50 WHSUR P DECOMP PJSM.PULL BPV. -R/U WELL SUPPORT LUBRICATOR. -PRESSURE TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. -PULL BPV. UD LUBRICATOR. Printed 4/28/2014 9:53:52AM North America-ALASKA-BP Page 2 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 1 Spud Date/Time:1/14/2001 12:00:00AM Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. I UW:500292286700 Active datum:Kelly Bushing/Rotary Table©57.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 00:00 3.50 WHSUR P DECOMP PJSM.WELL KILL. -REVIEW DOYON WELL KILL S.O.P. I -DISCUSSED INDIVIDUAL ROLES AND RESPONSIBILITIES WITH CREW. I-WSL AND TOOL PUSHER PRESENT FOR OPERATION. -REVIEWED PRESSURE CROSSCHECK PRIOR TO WELL KILL. SITP=400 PSI,SICP=450 PSI,OA=0 PSI. KWF=8.5 PPG,120°F BRINE. -WSL AND TOOL PUSHER VERIFY VALVE I ALIGNMENT BY PRESSURE CROSSCHECK BLEED GAS ON THE IA FROM 450 PSI TO 0 PSI IN 10 MIN.SITP=400 PSI. 'PUMP 55 BBLS 8.5 PPG KWF DOWN THE TUBING UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK ICP=3 BPM,480 PSI. I-FCP=3 BPM,350 PSI. 24 HOUR FLUID LOSS=498 BBLS 8.5 PPG BRINE. CUMULATIVE FLUID LOSS=498 BBLS 8.5 PPG BRINE. OUTER ANNULUS PRESSURE=0 PSI. Printed 4/28/2014 9:53:52AM • North America-ALASKA-BP Page 3 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) 11 Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM .Rig Release:4/16/2014 Rig Contractor DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table @57.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations • (hr) (usft) 4/11/2014 00:00 06:00 6.00 WHSUR P DECOMP PERFORM SPCC AND EQUIPMENT CHECKS. CROWN-O-MATIC CHECK. BULLHEAD 100 BBLS 8.5 PPG KWF DOWN THE TUBING ON THE FLY. -ICP=3 BPM,350 PSI. FCP=3 BPM,390 PSI. •SHUT DOWN AND MONITOR FOR 10 MINUTES. -SITP=0 PSI. -SICP=150 PSI. PUMP 410 BBLS 8.5 PPG KWF DOWN THE TUBING UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK. -ICP=5 BPM,1220 PSI. -FCP=5 BPM,1290 PSI. • -NO CLEAN 8.5 PPG BRINE IN RETURNS AFTER PUMPING 410 BBLS. '-CALL ODE TO PERFORM BULLHEAD KILL •SIMULTANEOUSLY DOWN THE TUBING AND 'IA. 'BULLHEAD 550 BBLS 8.5 KWF DOWN TUBING • AND IA. -ICP=7 BPM,250 PSI. • -FCP=7 BPM,290 PSI. SHUT DOWN AND MONITOR WELL FOR 45 MINUTES. -IA ON A VACUUM AFTER 15 MINUTES. • -TUBING ON A VACUUM AFTER 40 MINUTES. BLOW DOWN AND RIG DOWN SURFACE LINES. -START FILLING HOLE AT 20 BPH. TOTAL LOSSES DURING WELL KILL=1050 BBLS 8.5 PPG BRINE. 06:00 - 07:30 1.50 WHSUR P DECOMP PJSM.INSTALL TWC. -R/U WELL SUPPORT LUBRICATOR. -PRESSURE TEST TO 250 PSI LOW,4000 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. INSTALL TWC. 07:30 - 09:00 1.50 WHSUR P DECOMP PRESSURE TEST TWC. -ATTEMPT ROLLING TEST FROM BELOW TWC TO 500 PSI FOR 5 MINUTES. -PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW,4000 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. 09:00 - 10:30 1.50 WHSUR P DECOMP PJSM.NIPPLE DOWN TREE. -FMC BLEED VOID. -N/D 2-9/16"TREE. -INSPECT HANGER THREADS:2"LH-ACME 5-3/4 TURNS. • Printed 4/28/2014 9:53:52AM North America-ALASKA-BP Page 4 of 9 4 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table©57.10usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 110:30 - 14:00 3.50 BOPSUR P DECOMP PJSM.NIPPLE UP FOUR PREVENTER 13-5/8" BOPE. -N/U 13-5/8"BOPE STACK. -INSTALL TURNBUCKLES AND FLOW NIPPLE. -RE-ENERGIZE ACCUMULATOR SYSTEM. -FUCNTION TEST ALL RAMS. 14:00 - 20:00 6.00 BOPSUR P DECOMP PJSM.TEST FOUR PREVENTER 13-5/8"BOPE AND RELATED EQUIPMENT. -TEST BOPE ACCORDING TO AOGCC REGULATIONS,BP AND DOYON PROCEDURES. INSTALL 7-1/16"X 13-5/8"SPACER SPOOL 1-TEST ANNULAR WITH 2-7/8"TEST JOINT TO .250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST UPPER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4-1/2"TEST JOINT TO 250 PSI,4000 PSI HIGH FOR 5 CHARTED MINUTES. -TEST LOWER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4-1/2"TEST JOINT TO 250 PSI,4000 PSI HIGH FOR 5 CHARTED MINUTES. TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,4000 PSI HIGH FOR 5 CHARTED MINUTES. -TEST WITH FRESH WATER. -PERFORM ACCUMULATOR DRAW DOWN TEST. -NO FAILURES. BOB NOBLE OF AOGCC WITNESSED BOPE TEST. 20:00 - 22:30 2.50 BOPSUR P DECOMP PJSM.PULL TWC. -R/U WELL SUPPORT LUBRICATOR. -PRESSURE TEST TO 250 PSI LOW,4000 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. PULL TWC. L/D LUBRICATOR. 22:30 - 23:00 0.50 BOPSUR P DECOMP PJSM.PULL HANGER TO RIG FLOOR. -FMC BOLDS. -PUW=105K,SOW=88K.INCLUDES 40K TOP DRIVE. CUT ESP CABLE 1 JOINT BELOW HANGER. 23:00 - 00:00 1.00 BOPSUR P DECOMP PJSM.BULLHEAD TUBING VOLUME. -RIH AND SET SLICK PIPE ACROSS STACK -CLOSE ANNULAR PREVENTER. -BULLHEAD 55 BBLD DOWN TUBING. -4.5 BPM=960 PSI,5 BPM=1300 PSI. -SHUT DOWN AND MONITOR FOR 10 MINUTES. -WELL ON A VACUUM. -L/D HANGER. 24 HOUR FLUID LOSS=1019 BBLS 8.5 PPG BRINE. CUMULATIVE FLUID LOSS=1517 BBLS 8.5 PPG BRINE. OUTER ANNULUS PRESSURE=0 PSI. Printed 4/28/2014 9:53:52AM • North America-ALASKA-BP Page 5 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:OOAM Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table©57.10usft(above Mean Sea Level) Date From-To Hrs 1 Task Code 1 NPT 1 NPT Depth 1 Phase 1 Description of Operations (hr) (usft) 4/12/2014 00:00 - 00:30 0.50 BOPSUR P DECOMP PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. UD LANDING JOINT. -BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD. 00:30 - 15:00 14.50 BOPSUR P DECOMP PJSM.POH WITH 2-7/8"6.5#EUE 8RD L-80 'ESP COMPLETION. -PULL ESP CABLE OVER WINDWALL TO SPOOLING UNIT. -CONTINUOUS HOLE FILL AT 20 BPH. COMMUNICATION BETWEEN DRILLER AND SPOOLER OPERATOR AT ALL TIMES. -CENTRILIFT REPRESENTATIVE REMOVE 'AND RECORD ALL CLAMPS RECOVERED. -POH FROM 9,180'MD TO SURFACE. UD PUMP AND MOTOR ASSEMBLY. RECOVERED:LASALLE CLAMPS=203,FLAT GUARDS=3,PROTECTOLIZERS=5. 15:00 - 16:00 1.00 BOPSUR P DECOMP PSJM.R/D ESP SHEAVE. R/D E-TRUNK. -CLEAN AND CLEAR RIG FLOOR. 16:00 - 18:30 2.50 EVAL P INTERV PJSM.PICK UP SCHLUMBERGER EQUIPMENT. -INSTALL TEST PLUG. -PRESSURE UP AND SEAT TEST PLUG. -INSTALL DUTCH RISER,RILDS. 18:30 - 00:00 5.50 EVAL P INTERV PJSM.RIG UP SCHLUMBERGER FULL PRESSURE CONTROL EQUIPMENT. -PRESSURE TEST LUBRICATOR AND DUTCH RISER TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. BOLDS,PULL LUBRICATOR AND DUTCH RISER. PULL TEST PLUG. INSTALL LUBRICATOR AND DUTCH RISER, RILDS. 24 HOUR FLUID LOSS=513 BBLS 8.5 PPG BRINE. CUMULATIVE FLUID LOSS=2030 BBLS 8.5 PPG BRINE. OUTER ANNULUS PRESSURE=0 PSI. 4/13/2014 00:00 - 00:30 0.50 EVAL P INTERV PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. -SERVICE TOP DRIVE AND DRAWWORKS. 00:30 - 03:00 2.50 EVAL P INTERV M/U PDS TOOLS AND RIH AND LOG FROM 1000'MD TO SURFACE. 103:00 - 05:30 2.50 EVAL P INTERV R/D SCHLUMBERGER EQUIPMENT. CLEAN AND CLEAR RIG FLOOR. 05:30 - 15:30 10.00 WHSUR P INTERV PJSM.RIH WITH 7"HES RBP. P/U RBP AND RUNNING TOOL. -M/U RBP RUNNING TOOL TO 2-7/8"6.5#EUE 1 8RD L-80 TUBING. -RIH ON 2-7/8"STANDS FROM DERRICK, FROM SURFACE TO 4,896'MD. -RIH ON 4"DRILL PIPE FROM SHED,FROM - 1 4,896'MD TO 9,230'MD. Printed 4/28/2014 9:53:52AM North America-ALASKA-BP Page 6 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM Rig Release:4/16/2014 Rig Contractor DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table @57.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 17:30 2.00 DHB P INTERV PJSM.SET 7"HES RPB AND PERFORM MIT-IA. -CIRCULATE AT 3 BPM=160 PSI. -PUMP 30 BBLS TO SET RBP.COE=9,203' MD. FLUID PACK WELL WITH KWF. PRESSURE UP TO 3,800 PSI,6.9 BBLS TO PRESSURE UP. 0 MIN=3,800 PSI,15 MIN=3,790 PSI,30 MIN =3,785 PSI.MEETS CRT-AK-10-45 REQUIREMENTS. CONTACT WTL FOR APPROVAL TO PROCEED. -BLEED PRESSURE,7.0 BBLS BLED OFF. 17:30 - 19:30 2.00 DHB P INTERV PJSM.SET 7"HES RTTS. POH AND STAND BACK 5 STANDS OF 4" I DRILL PIPE. • -P/U HES RTTS AND RIH 1 STAND. -SET RTTS AT 107'MD. -PRESSURE TEST TO 1500 PSI FOR 5 'CHARTED MINUTES.GOOD TEST. DRAIN STACK AND BLOW DOWN LINES. 19:30 - 20:30 1.00 BOPSUR P INTERV PJSM.NIPPLE DOWN 13-5/8"BOPE. 20:30 - 00:00 3.50 WHSUR P INTERV PJSM.REPLACE TUBING SPOOL. •-N/D 7-1/16"X 11"TUBING SPOOL. • -REPLACE MANDREL PACK-OFF PER FMC REP. 24 HOUR FLUID LOSS=391 BBLS 8.5 PPG BRINE. CUMULATIVE FLUID LOSS=2421 BBLS 8.5 PPG BRINE. OUTER ANNULUS PRESSURE=0 PSI. 4/14/2014 00:00 - 02:00 2.00 WHSUR P INTERV PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. PJSM.N/U 11"X 11"TUBING SPOOL. -PRESSURE TEST PACK-OFF TO 3600 PSI FOR 30 CHARTED MINUTES.GOOD TEST. 02:00 - 05.00 3.00 BOPSUR P INTERV 11 PJSM.NIPPLE UP 13-5/8"BOPE. I-P/U RUNNING TOOL. • -SET TEST PLUG. H FUNCTION TEST ALL RAMS. -PRESSURE TEST BREAKS TO 250 PSI LOW, 4000 PSI HIGH FOR 5 CHARTED MINUTES. -PULL TEST PLUG. -INSTALL WEAR RING.ID=7-1/4" 05:00 - 05:30 0.50 CASING P INTERV PJSM.RETRIEVE 7"HES RTTS. -P/U RUNNING TOOL. -RIH AND SCREW INTO RTTS. -CLOSE ANNULAR PREVENTER. -PUW=97K,VERIFY NO PRESSURE BELOW RTTS. -OPEN ANNULAR PREVENTER. -POH AND UD RTTS AND RUNNING TOOL. Printed 4/28/2014 9:53:52AM • • North America-ALASKA-BP Page 7 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table @57.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 06:30 1.00 CASING P INTERV !PJSM.RETRIEVE 7"HES RBP. -RIH WITH STANDS FROM DERRICK TO 9,198' MD. -ENGAGE AND RELEASE RBP. PUW=101K,SOW=84K. -BULLHEAD 100 BBLS AT 8 BPM. -MONITOR WELL FOR 10 MINUTES. BLOW DOWN CHOKE AND TOP DRIVE. 06:30 - 10:00 3.50 CASING P INTERV PJSM.POOH UD 4"DRILL PIPE TO SHED. POOH FROM 9,187'MD TO 7,797'MD. 10:00 - 14:30 4.50 CASING N RREP INTERV PJSM.CHANGE OUT AND REPAIR SKATE CABLE. 14:30 - 17:30 3.00 CASING P INTERV PJSM.POOH UD 4"DRILL PIPE TO SHED. -POOH FROM 7,797'MD 4,886'MD. 17:30 - 23:00 5.50 CASING P INTERV PJSM.POOH LID 2-7/8"TUBING TO PIPE SHED. -CHANGE OUT EQUIPMENT FOR 2-7/8" TUBING. -POOH FROM 4,886'MD TO 93'MD. 1-MONITOR WELL BEFORE PULLING BHA THROUGH STACK. -L/D RBP AND RUNNING TOOL. PULL WEAR RING. 23:00 - 00:00 1.00 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR. -CHANGE BAILS. -R/U TO RUN 4-1/2"12.6#13CR-85 VAMPTOP COMPLETION. 24 HOUR FLUID LOSS=316 BBLS 8.5 PPG BRINE. CUMULATIVE FLUID LOSS=2737 BBLS 8.5 !PPG BRINE. OUTER ANNULUS PRESSURE=0 PSI. 4/15/2014 00:00 - 02:00 2.00 RUNCOM P RUNCMP PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. PJSM.R/U COMPLETION EQUIPMENT. -R/U TORQUE TURN AND COMPENSATOR. -BRING SCHLUMBERGER I-WIRE EQUIPMENT TO RIG FLOOR. -HANG I-WIRE SHEAVE. 02:00 - 12:00 10.00 RUNCOM P RUNCMP PJSM.RUN IN HOLE WITH 4-1/2"12.6# 13CR-85 VAMPTOP COMPLETION. -TORQUE TURN EACH JOINT TO 4,440 FT-LBS. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -FILL TUBING EVERY 5 JOINTS. -INSTALL CANNON CLAMP ON EVERY JOINT. -VERIFY I-WIRE CONTINUITY EVERY 1,000'. -RIH TO 4132' 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -SERVICE PIPE SKATE 12:30 - 22:30 10.00 RUNCOM P RUNCMP RUN IN HOLE WITH 4-1/2"12.6#13CR-85 VAMPTOP COMPLETION -FROM 4132'TO 9244' MAINTAIN CONSTANT HOLE FILL AT 20 BPH WITH 8.5 PPG SEA WATER -FILL TUBING EVERY 5 JOINTS Printed 4/28/2014 9:53:52AM • North America-ALASKA-BP Page 8 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310.000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM •Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292286700 ---------- Active datum:Kelly Bushing/Rotary Table©57.10usft(above Mean Sea Level) Date From-To Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 RUNCOM P RUNCMP M/U LANDING JOINT TO HANGER,M/U HANGER TO TUBING STRING -TERMINATE I-WIRE AND TIE INTO HANGER -FMC REP TEST I-WIRE HANGER CONNECTION TO 5000 PSI -LAND HANGER,RUN IN LDS -OA=0 PSI -24 HOUR FLUID LOSS=595 BBLS,8.5 SEA WATER 4/16/2014 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM,RN CIRCULATING LINES IN CELLAR -TEST LINES TO 250-3700 PSI 01:30 - 03:00 1.50 RUNCOM P RUNCMP PJSM,PUMP COMPLETION FLUID -PRESSURE UP ON TUBING TO 1000 PSI, SHUT IN AND MONITOR -BULLHEAD 175 BBLS 100 DEGREE 8.5 PPG INHIBITED SEAWATER TO IA -3 BPM=80 PSI,BLEED TUBING TO LMAINTAIN 100 PSI 03:00 - 06:00 3.00 RUNCOM P RUNCMP TEST TUBING AND SET PACKER -250 PSI-5 MIN,3600 PSI 30 MINUTES, • CHART -OBSERVE PACKER SET AT 1950 PSI '-- -BLEED TUBING PSI TO 1500 PSI -MIT-I/A TO 3600 PSI,30 MIN,CHART -TEST PASS W/WiLAPPROVAL 06:00 - 06:30 0.50 RUNCOM P RUNCMP SHEAR DCK VALVE -PUMP BOTH WAYS THRU DCK VALVE -DRAIN BOP STACK 06:30 - 07:30 • 1.00 WHSUR P • RUNCMP FMC INSTALL TWC -TEST TWC BELOW AND ABOVE,250 PSI, 3500 PSI,5 MIN EACH,CHART • 07:30 - 08:00 0.50 BOPSUR P RUNCMP PJSM TO N/D BOP AND N/U TREE -BLOW DOWN ALL LINES AND CHOKE MANIFOLD 08:00 - 09:00 1.00 BOPSUR P RUNCMP N/D BOP AND RELATED EQUIPMENT 09:00 - 10:30 1.50 WHSUR P RUNCMP FMC CLEAN AND PREP HANGER -SLB REP INSTALL I-WIRE ADAPTER -N/U 11"X 4-1/16"ADAPTER FLANGE AND TREE 10:30 - 12:30 2.00 WHSUR P RUNCMP SLB REP TERMINATE I-WIRE AT ADAPTER -FMC REP TEST HANGER VOID AND SEALS TO 5000 PSI,30 MIN 12:30 - 14:30 2.00 WHSUR P RUNCMP PJSM,R/U WELL SUPPORT LUBRICATOR -TEST 250/3500 PSI,5 MIN,CHART -PULL TWC,R/D LUB 14:30 - 15:30 1.00 WHSUR P RUNCMP R/U CIRCULATING LINES FOR FREEZE PROTECT -BEGIN PREP RIG FOR MOVE 15:30 - 18:30 3.00 WHSUR P RUNCMP PJSM,R/U LITTLE RED AND TEST LINES -PUMP 85 BBLS DIESEL FREEZE PROTECT TO IA,TAKE RETURNS OUT TUBING -1.5 BPM=740 PSI f1{ 18:30 - 19:30 1.00 WHSUR P RUNCMP ALLOW DIESEL TO U-TUBE IN ELL 19:30 - 21:00 1.50 WHSUR WP RUNCMP PJSM,RN WELL SUPPORT LUBRICATOR -TEST 250/3500 PSI,5 MIN,CHART -INSTALL BPV,R/D LUB Printed 4/28/2014 9:53:52AM North America-ALASKA-BP Page 9 of 9 Operation Summary Report Common Well Name:MPE-24 AFE No Event Type:WORKOVER(WO) Start Date:4/10/2014 End Date:4/16/2014 X4-0102J-E:(2,310,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/14/2001 12:00:00AM Rig Release:4/16/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292286700 Active datum:Kelly Bushing/Rotary Table @57.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 22:00 1.00 WHSUR P RUNCMP LRS TEST BPV FROM BELOW i-250/3500 PSI,5 MIN,CHART -R/D LRS 22:00 - 22:30 0.50 WHSUR P RUNCMP BLOW DOWN AND R/D ALL CIRC LINES IN CELLAR -COMPLETE PIT CLEANING 22:30 - 00:00 1.50 WHSUR P RUNCMP PJSM,CUT AND SLIP 48'OF DRILLING LINE RELEASE RIG FROM MPE-24 AT 23:59 ON ,4-16-2014 Printed 4/28/2014 9:53:52AM Tree:4 1/16"Cameron /LI KB e,�v.=57.1'(N-27E) ~ Wellhead:Gen 5a system.11"csg 4 1/2"CIW BPV Profile MPE-24a GL elev.=24.3'(N-27E) spool,7 1/16"x 11"5M FMC tbg. spool w/7"mandrel hgr&packoff 7"X 4 1/2"hgr.installed 4 1/2 TCII X 4 1/2 TCII Blast Ring Installed 113' 20"91.1 ppf,H-40 9-5/8"Howco ES cmt stage collar. 2147' 0 M 4.5""X"Nipple 9Cr(3.813 ID.") 2,221' KOP @ 400' 4.5"X 1"9Cr GLM KBG-4-5 Wellbore Angle:70-90 DegreeAi W/DCK-2 Shear Valve 2,499' 3,300'-9400' Hole angle through perfs=90° ; I-Wire with clamp every Collar 31 "";'^ ' a 4.5"SLB PXP NDPG-C Multidrop 11 ' 9,044' 1Discharge Gauge(3.864"ID) 4.5"HES L-80"XD"Dura sliding sleeve i....,j Hyd 521 BxP(I-Wire) (3.813"ID) 9,057' ® i I 1110 4.5"SLB NDPG-C Single Drop Intake 9,069' _ Gauge(Vamtop PxP) (3.864 ID) M 7 5/8"x 4.5"HES TNT L-80 Packer. 9,135' I 1 4.5"HES X Nipple(3.813"ID) 9,211' 4.5"12.6#13 CR-85 VamTop TubingIII (drift id=3.958"cap=.0152 bpf) MI WLEG w/TC-II and 5.00 OD. 9,267' 7"26 ppf,L-80,Btrcproduction casingRA tag at 9256' (drift ID=6.151",cap=0.0383 bpf) "OA"window from 9385'-9397' (cap w/tbg=.02758) Above "OB"window from 9545-9557' 9375' , Baker 7"Hook Wall Hanger System Below 9397' II 4.5"12.6#,L-80 IBT tubing. 9397. Baker Float shoe at' 12850' 4-1/2"SLOTTED INTERVALS , OA-9447'-12731'MD(3284') OB-9532'-12816'MD(3284') III T 26ppf,L-80 mod BTC shoe 9772' 9428' 4.5"12.6#,L-80 IBT tubing. 12860' Baker Float shoe at' 15 bbls(200')of class G cement above retainer 9-5/8"Howco EZSV 10009' ' 33 bbls of class G cement below retainer 9-5/8"40ppf,L-80 mod.shoe. 10077' Top of cement=13343' 51 bbls of class G cement 8.5"hole drilled to 14366'. Kuparuk sand wet. DATE -REV.BY COMMENTS MILNE POINT UNIT 04/04/98 JBF Drilling&Temp P&A Nabors 27-E WELL MPE-24a 02/02/01 M.Linder Horizontal multi-lateral sidetrack into Schrader API NO: 50-029-22867-00 02/15/01 MDO 22 E ESP completion 07/24/04 Lee Hulme ESP Changeout Nabors 4ES 4/17/14 B.Bixby Doyon 16 Convert to Jet Pump Completion BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ic o \ (7 1 S December 30, 2011 E .: ` - A 4 4 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ti ° ,.;`° , : <r i;mis ict Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad 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, Gerald Murphy, at 659 -5102. Sincerely, ter S'C,N4NED FEB 2 2. a) Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE-05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 - ---> MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE-30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA _ 7.65 8/23/2011 '~!"''''''''- """: .~..... . .."('t " ".\\\ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _ Inserts\Microfilm _Marker .doc ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISS~iECEIVED REPORT OF SUNDRY WELL OPERATI9trff62004 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. . Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 53.70' 8. Property Designation: ADL 380110 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 113' Surface 10041' Intermediate Production 9517' Liner 3432' Perforation Depth MD (ft): Perforation Depth TVD (ft): H Repair Well 0 Plug Perforations 0 Stimulate H Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: H Development 0 Exploratory 0 Stratigraphic 0 Service 200-186 6. API Number: 50-029-22867-01-00 12860 4204 12860 4204 9. Well Name and Number: MPE.24A 10. Field / Pool(s): Milne Point Unit / Schrader Bluff feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 113' 113' 1490 470 9-5/8" 10077' 4304' 5750 3090 7" 9545' 4316' 7240 5410 4-1/2" 9428' - 12860' 4281' - 4204' 8430 7500 Slotted Liner 9532' - 12816' Slotted Liner 4312' - 4204' 2-7/8" 6.5#, L-80 9180' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BF L AUG 1 'f 1'11\\\ Treatment description including volumes used and final pressure: 13. Oil-Bbl Tubin Pressure Re resentative Dail Gas-Met Water-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run H Daily Report of Well Operations H Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory H Development 0 Service 16. Well Status after proposed work: H Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL my no e ge. Sundry Number or N/A if C.O. Exempt: Printed Name Sondra Stewman Title Technical Assistant P Date œ-¡ Y Prepared By Name/Number: Sandra Stewman, 564-4750 Submit Original Only ~ ~ KB elev. = 57.1' (N-27E) GL elev. = 24.3' (N-27E) Tree: 2-7/8"" Cameron ~: Gen 5a system. 11" csg spool, 7-1/16"x 11" 5M FMC tbg. spool wl7"mandrel hgr & packoff 7">. 27/8"tbg hgr.installed. 20" 91.1 ppf, H.40 ITill 9-5/8" Howeo ES cmt stage collar. ~ KOP @ 400' Well bore Angle: 70" to 76" 3,300' - 9400' Hole angle through perfs = 900 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) 7" 26 ppf, L-80, Btrc. production casing (drift ID =6.151", cap =0.0383 bpf) (cap w/ tbg = .02758) RA tag at 9256' Above I 9375' Below I 9397' 4-1/2" SLOTTED INTERVALS OA- 9447'- 12731' MD (3284') OB- 9532'-12816' MD (3284') 7" 26ppf, L-80 mod BTC shoe ~ 15 bbls (200') of class G cement above retainer 9-5/8" Howco EZSV 110009' I 33 bbls of class G cement below retainer 9-5/8" 40ppf, L-80 mod. shoe. 110077' 1 Top of cement= 13343' 51 bbls of class G cement 8.5" hole drilled to 14366'. Kuparuk sand wet. DATE REV. BY 04/04/98 JBF 02102101 M. Linder 02115101 MDO 07/24104 Lee Hulme COMMENTS Drilling & Temp P&A Nabors 27-E MILNE POINT UNIT WELL MPE-24a API NO: 50-029-22867-00 MPE-24a\L\ Camco 2-7/8" x1" KBMM Gas lift mandrel 133' Camco 2-7/8" x1" KBMM Gas lift mandrel I 2513' Camco 2-7/8" x1" KBMM Gas lift mandrel I 8959' HES XN-Nipple (2.205" id) I 9101' Tandem Pump, 26 stg. FC1800 134 stg. FC1800, 16 stg. GPMTAR / GPMTAR 1:1 I 9117' Tandem Intake - Gas Separator Model - GRSFTXAR Tandem Seal Section, Model- GSB3 DB UT/LT IL H6 PFS AFLAS / HSN 9146' I 9151' I Motor, 190 KMH 2415 volt /48 amp, I 9165' PumpMate w/6 fin centralizer I 9175' "OA" window from 9385'-9397' "DB" window from 9545'-9557' ~ 4.5" 12.6#, L-80 IBT tubing. Baker Float shoe at' 112850' I ~ 4.5" 12.6#, L-80 IBT tubing. Baker Float shoe at' ~ Horizontal multi-lateral sidetrack into Schrader 22 E ESP completion ESP Changeout Nabors 4ES BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ ~ BP EXPLORATION Operations Summary Report MPE-24 MPE-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Task Code NPT From - To Hours Phase ~_...._......__.._--..---- ---- 1--- ------. 7/23/2004 7/24/2004 7/25/2004 09:00 - 11 :00 11 :00 - 12:00 12:00 - 14:00 14:00 - 15:30 15:30 - 16:00 16:00.. 18:00 18:00 - 18:30 18:30.. 21:30 21 :30 . 22:00 22:00 . 23:00 23:00 - 01 :00 00:00 - 01 :00 01 :00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 .. 07:30 07:30 - 09:00 09:00 .. 13:30 13:30 - 16:00 16:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 .. 04:30 04:30 - 08:00 08:00 - 09:30 09:30 - 12:30 2.00 MOB P 1.00 MOB P 2,00 MOB P 1.50 RIGU P 0.50 WHSUR P 2.00 WHSUR P PRE PRE PRE PRE DECOMP DECOMP 0.50 KILL 3.00 KILL P P DECOMP DECOMP 0.50 WHSUR P 1.00 WHSUR P 2.00 BOPSUF P 1.00 BOPSUF P 3.00 BOPSUF P DECOMP DECOMP DECOMP DECOMP DECOMP 1.50 WHSUR P DECOMP 0.50 BOPSUF P 0.50 BOPSUF P 0.50 BOPSUF P 0.50 PULL P DECOMP DECOMP DECOMP DECOMP 1.50 PULL P DECOMP 4.50 PULL 2.50 PULL P P DECOMP DECOMP 4.50 CLEAN P 0.50 CLEAN P 3.00 CLEAN P CLEAN CLEAN CLEAN 2.50 CLEAN P CLEAN 1.00 CLEAN P CLEAN 1.00 CLEAN P 3.50 CLEAN P 1.50 RUNcm p 3.00 RUNcm p CLEAN CLEAN RUNCMP RUNCMP Page 1 of 2 Start: 7/23/2004 Rig Release: 7/26/2004 Rig Number: Spud Date: 1/14/2001 End: 7/26/2004 Description of Operations -'"-..--.. -..-..-............-..-..------ Scope & lower derrick. RID rig. Move from MPE-18 to MPE -24. Spot rig over well head. Berm around rig. Raise & scope up derrick. Rig up rig. P/U lubricator & pull BPV. UD lubricator. RIG ACCEPTED @ 1600 hrs. RlU lines to tree & tiger tank. Test lines to 3500 psi. Hold Pre-Spud & PJSM wi all hands. Open well. SITP 100 psi. SICP 290 psi. Bleed off pressure to 80 psi & bring on pump. Kill well, 4 BPM @ 1800 psi. Pumped 470 Bbls of heated seawater. SID & monitor well. Well dead. Recovered 199 Bbls of oil in tiger tank. Install & test TWC. Blow down & RID lines to tree. Bleed off void. N/D X-mas tree. N/U BOPE. Finish N/U BOPE. Test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by John Spaulding wi AOGCC. P/U lubricator & Attempt to pull TWC. appears to have junk on top of TWC. UD lubricator. Attempt to fish out piece of rubber. No Joy. Pick up BOP stack & remove junk on top of TWC. Retrieved (3) pieces rubber....Iooks like from the annular preventor. PJSM. PT flange & kill line 350 13500 psi, OK. PJSM. Pull 2 way check. UD lubricator & extension. PJSM. M/U landing jt. BOLDs. Pull hanger to floor. 55-60K up wi, drag to 75K max. PJSM. Circulate & fill hole, (60) bbls to fill. Continue circulating seeing oil in returns. Circulate (100 bbls) @ 1 1/2 - 2 bpm 1500 .. 1000 psi. Monitor well, fluid level dropping quickly. PJSM. POOH spooling control line & double displacing hole. PJSM. Lay down pump assembly. Pup above pump had slot approximately 1 1/2' long & 1/2" wide. M/U muleshoe on bottom of tbg. RIH wi 2 7/8' tbg. P/U 3 1/2" DP 1 x 1 & RIH.Tag up on fill @ 9431'. M/U circulating head, fill hole. Reverse circulate & Clean out wellbore to 9560'. Con't to reverse circulate & clean out well bore from 9560 to 10056'.5 BPM @ 400 psi. Appear to have entered in lower lateral. (Calc PBTD +1-9800') Last 300' had no fill that took weight. Circulated out very fine sand & heavy black oil. Collected sand sample for town. Pump sweep. Reverse circulate bottoms up. 6 BPM @ 350 psi. Losses estimated @ 70%. Total losses whole cleaning out well bore & circulating bottoms up = 1085 Bbls. POOH & UD 3 1/2" DP. POOH & stand back 2 7/8' tbg. PJSM. Prep to run 2 7/8' ESP completion. Pick up ESP assembly. PJSM. M/U service & check ESP. Printed: 7/27/2004 10:44:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~ . ------ BP EXPLORATION Operations Summary Report MPE-24 MPE-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES I From - To ¡ Hours , , Task Code NPT Phase --'--""-"" .---.-. 7/25/2004 12:30 - 17:30 RUNCMP 17:30 .. 19:30 RUNCMP 19:30 - 20:30 RUNCMP 20:30 - 21 :00 RUNCMP 21 :00 - 23:00 RUNCMP 23:00 - 23:30 0.50 RUNCO RUNCMP 23:30 - 00:00 0.50 BOPSU P RUNCMP 7/26/2004 00:00 .. 00:30 0.50 BOPSU P RUNCMP 00:30 .. 01 :30 1.00 WHSUR P RUNCMP 01 :30 - 03:00 1.50 WHSUR P RUNCMP 03:00 - 06:00 3.00 RIGD P POST Page 2 of 2 Start: 7/23/2004 Rig Release: 7/26/2004 Rig Number: Spud Date: 1/14/2001 End: 7/26/2004 Description of Operations ..--.... -- ---- --- RIH wi ESP on 2 7/8" tbg. M/U connections to 2300 ft-Ibs using Best-O-Life 2000 pipe dope. Pump 10 bbls thru pump & meg cable every 2000'. Make reel to reel splice in ESP cable. Meg same. Con't to RIH wi ESP completion. Ran total of 286 its. M/U landing jt in hanger. Install penetrator in hanger. Make field connection on ESP cable. Plug in & meg connection. Land hanger & RILDS. Install TWC. N/D BOPE. Finish N/D BOPE. N/U X-mas tree. Test tree & meg ESP cable. P/U lubricator, pull TWC. Install BPV, UD lubricator. Clean pits & cellar area. Secure well. RELEASE RIG @ 0300 hrs. RDMO to MPF-50. Printed: 7/27/2004 10:44:20 AM Permit to Drill 2001860 MD 12860 v TVD DATA SUBMITTAL COMPLIANCE REPORT 4/112003 Well Name/No. MILNE PT UNIT SB E-24A Operator BP EXPLORATION (ALASKA) INC 4204 ,," Completion Dat 2/13/2001 / Completion Statu 1-OIL Current Status 1-OIL APl No. $0-029-22867-01-00 UIC N REQUIRED INFORMATION Mud Log N__.~o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt ./ Name ED ~~ LIS Verification ED C ,~ See Notes (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval Start Stop OH I Dataset CH Received Numb~er Comments 12/28/2OOl -r0'g09~..- 1 Directional Survey FINAL 9520 12807 Open ch Directional Survey FINAL ch FINAL ch Directional Survey MWD Directional Survey M ~ ,~ FINAL MWD DirectionalSurvey ~ vl ~ FINAL MWD Directional Survey ~-,.- I ~ MWD Directional.Survey L - t /~,q~./j / FINAL Directional Survey /~ ~ t /'10V~ / FINAL ch ch ch ch 9520 12860 Open 311/2001 Directional Survey Digital Data 311/2001 Directional Survey Paper Copy 3/1/2001 Directional Survey Digital Data 311/2001 Directional Survey Paper Copy 3/1/2001 Directional Survey Digital Data 3/1/2001 Directional Survey Paper Copy 3/1/2001 Directional Survey Digital Data 31112001 1/17/2002 /,,,~04 Directional Survey Paper Copy Digital Well Log Data__~ v'(~ NOTE: No paper log copies were received MD AND 'I'VD Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 41112003 Permit to Drill 2001860 Well Name/No. MILNE PT UNIT SB E-24A Operator BP EXPLORATION (ALASKA) INC MD 12860 TVD 4204 Well Cored? Y/~ Chips Received? ~Y ! N Analysis ~ Re. ceive, d? Completion Dat 2113!2001 Completion Statu 1-OIL ./~urrent Status 1-OIL ~N Daily History Received? Formation Tops ~__~/N APl No. $0-029-22867-0'1-00 UlC N Comments: Compliance Reviewed By: Date: To: WEI,L LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPE-24A, AK-MM-10008 January 10, 2002 MPE-24A; Digital Log Images: 50-029-22687-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMrrTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Arm: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Date: ,,¢,N 1 ? 2002 1 To-" WE!J~ LOG TRANSMITrAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 21,2001 RE: MWD Formation Evaluation Logs MPE-24A, AK-MM- 10008 1 LIS formatted Disc with verification listing. API#: 50-029-22867-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED DEC 2 8 2001 ,~,~i,~ ~ ~ , ,., K~ STATE OF ALASKA " ALAS ,JIL AND GAS CONSERVATION COM,~._SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ' [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-186 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-50-029-22867-01 4. Location of well at surface .......... - ' , .';~¥,,,.,,:'.,.:~[~_:;~, 9. Unit or Lease Name 3613' NSL, 1936' WEL, SEC. 25, T13N, R10E, UM ,..~. .... Milne Point Unit At top of productive interval ~ .Z,/.~J .~'/" 3890' SNL, 2426' WEL, SEC. 36, T13N, R10E, ua (OB Sandst"-~,i:~,iii~i':!.,.--.-'~ 10. Well Number At total depth i .......... .~:;~ ...... .". MPE-24A 1848' SNL, 2526' WEL, SEC. 06, T12N, R11E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit / Schrader Bluff KBE = 53.70' ADL 380110 12. Date Spudded1/14/2001 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'l/16/2001 2/13/2001 115' water depth' if °ffsh°reN/A MS L 110' N°' °f c°mpleti°nsOne :17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 12860 4204 FTI 12860 4204 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD 23. CASING, LINER AND CEMENTING RECORD CASING SE'h'ING DEPTH HOLE ' SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED "20" ' ..... ,9!.1#' "' ', ',' H-40 .... Su'rface, 113' 24" 260 8x Arctic Set, (Ap, prox.) .... 9-5/8" 40# L-80 36' 10077' 12-1/4" 28J~3"sx PF"E', 562 sx Class 'G' 7"' ' '26#' ' ' L-80 ..... 28' 9545' ' 12-~/4~'335 s~AS III, 245 sx"Class'G' ' ..... 4-1/2""' 12.6# L-SO 9428' 12860' 6-~/8" Ur{cemented Siotted Liner , 24. Perforations ppen to. P.roductipn (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~merva~, s~ze and number} SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 9195' MD TVD MD TVD 9532' - 12816' 4312' - 4204' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9700' Set Whipstock Freeze Protect with 65 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 18, 2001 Electric Submersible Pump ~ , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs'MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/20/2001 6 TEST PERIOD 2189 338 390I 155 ~i0w T~bing ~asing Pressure CALCULATED OIL-BBL G~,s-McF' ' WA~ER-BBL OIL GhAWTY-API (CORR) Press. 24-HouR RATE ...28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAR I ZOO1 _.. ~,,1~ (3il ~ Gas Cons. Commission Form 10-407 Rev. 07-01-80 ORIGINAL Anchorage Submit In Duplicate ( ( Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 30. True Vertical Depth Geologic Markers Measured Depth 29. Name Marker 4136' 8882' NA 4161 8978 NB 4185' 9065' NC 4212' 9164' NE 4245' 9286' NF 4269' 4318' 9380' 9552' OA OB Summary of Daily Drilling Reports, Surveys submitted by Vendor List of Attachments: 31 01 Terrie Hubble, 564-4628 06rA/· Date Prepared By NameINumber: the best of my knowledge Technical Assistant Title hereby certify that the foregoing is true and correct to Signed TerrieHubble ~)J\~ ~~ MPE-24A 200-186 Well Number Permit No. I 32. Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. water disposal. water supply for injection, observation, ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Indicate whether from ground level (GL) or other elevation (DF, KB, etc. ITEM 21 Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool ITEM 23: ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. RECEiVED MAR 2 1 ZOO I' " ~ \\~ j-~\ L t ~ \ .,... U :1' , I: ' t"\ o If no cores taken, indicate 'none' ITEM 28: Alaska Oil & Gas Cons. Commission Anchorage 1 0-407 Rev. 07-01-80 Form I' CUC:I V l-- IJ BP E×PLOP TION Pag Operations Summa Repo Ala~k~ Oil ~ Legal Well Name: MPE-24 Anchorage Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Sta~: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 1/1/2001 18:00 - 00:00 6,00 MOB PRE Rig Down at MPJ-20A - Prepare to move to MPE-24A 1/2/2001 00:00 - 00:00 24.00 MOB PRE Rig Down, Move Rig from Milne Point J-pad to E-pad - Move Sub with derrick up 1/3/2001 00:00 - 00:00 24.00 MOB PRE Spot and level sub on well. Spot mud pits, pipe shed and motor complexes. Spot cuEings tank and build berm around it. Move ~mp, pa~s house, shop and generator from J pad to E pad.. Sta~ thrawing out and hooking up water, air and hydraulic lines. 1/4/2001 00:00 - 04:00 4.00 MOB 3RE Change out su~ion valves in pits. Thaw out water lines and repair steam line. Install skate railing on pipe chute. 04:00 - 07:00 3.00, MOB PRE Remove ice from rig floor. Mop and clean rig. 07:00 - 12:00 5.00 WHSUR DECOMP Check for pressure and n/d tree. Pull tubing hanger and tubing head. Pull 7' packoff and casing hanger with pup. Ac~pt rig at 0700 hrs, 12:00 - 18:00 6.00 BOPSUF INT1 Install 11"x 11" drilling spool with double valves. N/u bops. 18:00 - 21:00 3.00 WHSUR PROD1 Fabricate flowline, choke line and fill up line. 21:00 - 22:00 1.00 BOPSUF PROD1 PJSM. M/U test jt and install test plug. 22:00 - 23:00 1.00 BOPSUF BARR PROD1 Change out ring gasket on choke line. 23:00 - 00:00 1.00 BOPSUF PROD1 Test bops. All rams/valves 250/3500 psi for 5/10 minutes. Test annular 250/2000 psi for 5 and 10 minutes. Chuck Scheve with AOGCC waived witnessing test. 1/5/2001 00:00 - 06:30 6.50 BOPSUR PROD1 Finish testing bops. Chuck Scheeve waived witnessing test. 06:30 - 10:00 3.50 S~HIP' PROD1 Trip in hole picking up and driEing 3-1/2" drill pipe to 2200'. 10:00 - 11:30 1.50 S~HIP PROD1 Displa~ freeze protect diesel from annulus and drill pipe with seawater. Circulate until seawater back to surfak. 11:30 - 19:30 8.00 S~HIP PROD1 Continue tripping in hole picking up and drifting 3-1/2" drill pipe. Tagged bridge plug at 6942'. 19:30 - 20:00 0.50 S~HIP PROD1 Circulate capaci~ of drill pipe. 20:00 - 22:30 2.50 S~HIP PROD1 Pooh and stand back drill pipe. 22:30 - 23:00 0.50 S~HIP PROD1 Se~i~ top drive. 23:00 - 00:00 1.00 S~HIP PROD1 Trip in hole picking up 3-1/2 drill pipe, 1/6/2001 00:00 - 09:00 9.00 S~HIP PROD1 Finish tripping in hole picking up and drifting 3-1/2" drill pipe 09:00 - 09:30 0,50 S~HIP PROD1 Circulate capacity of drill pipe. 09:30 - 12:00 2.50 S~HIP PROD1 Pooh standing drill pipe back in derrick. 137 stands drill pipe in derrick 12:00 - 13:00 1,00 S~HIP PROD1 Clean rig floor. 13:00 - 16:00 3.00 S~HIP PROD1 P/u, strap and m/u bha. Test MWD. 16:00 - 17:00 1,00 S~HIP PROD1 Clean up seawater spill and had a meeting with hands discussing how to prevent this in the futura. 17:00 - 17:30 0.50 S~HIP PROD1 Se~i~ top drive. 17:30 - 21:30 4.00 S~HIP PROD1 Continue tih to top of plug. Fill drill pipe and lost all pressure on top drive. 21:30 - 00:00 2.50 S~HIP TDRV PROD1 Waiting on pa~s to repair top drive. Lost ele~rical motor on lube pump. 1/7/2001 00:00 - 07:00 7,00 S~HIP TDRV PROD1 Replace electrical motor on lube pump on the top drive 07:00 - 08:30 1.50 S~HIP PROD1 Drill bridge plug 08:30 - 09:30 1.00 S~HIP PROD1 Circu ate bottoms up-no gas. 09:30 - 12:00 2.50 S~HIP PROD1 Continue tih to 9515. Sta~ed taking weight. 12:00 - 15:00 3.00 S~HIP PROD1 Wash and drill through ~ment stringem 9525'-9789'. 15:00 - 17:00 2.00 S~HIP PROD1 Pump sweep and displa~ well with seawater. 17:00 - 17:30 0.50 S~HIP PROD1 Pooh to 9055' 17:30 - 22:00 4,50 S~HIP PROD1 Make a mad pass tie-in log from 9055'-9789'. 22:00 - 00:00 2.00 S~HIP ~HR PROD1 Phase III weather ~nditions. WOW. 1/8/2001 00:00 - 00:00 24.00 S~HIP ~HR PROD1 Phase III conditions. WOW. Change su~ion valves in pit ~7, install snubbing post, and weather proof rig while waiting on weather, At 1800 hrs Milne Pt went back to Phase II, but Prudhoe Bay and Kuparuk were Printed: 2/2612001 3:08:06 PM BP EXPLORATION 2 of 7 Operations Summary Report MAR 1 2001 Legal Well Name: MPE-24 ,Alaska 0il & Gas Cons. Commission Common Well Name: MPE-24A Sp~j~lDr~: 111412001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 1/8/2001 00:00 - 00:00 24.00 S'I'WHIP VVTHR PROD1 still Phase III. Remove snow so rig is accessible for water and diesel trucks. Prepare to Pooh. 1/9/2001 00:00 - 04:30 4.50 STWHIP WTHR PROD1 Pooh recording pu, so, and rotating wt every 10 stands. 04:30 - 05:30 1.00 STWHIP PROD1 LID bha. 05:30 - 06:30 1.00 STWHIP PROD1 Pull wear ring. 06:30 - 08:30 2.00 BOPSUF PROD1 Change top rams to 7" 08:30 - 11:00 2.50 STWHIP PROD1 Change top drive from 3-1/2" to 4-1/2" for fill up tool. 11:00 - 14:00 3.00 BOPSUF PROD1 Set test plug and test door to 1000 psi. 14:00 - 17:00 3.00 CASE PROD1 Change bails, mu fill up tool and ru casing equipment. 17:00 - 20:30 3.50 CASE PROD1 PJSM. Run 7" 26# L-80 BTC Mod casing. 20:30 - 21:00 0.50 CASE PROD1 Change out tongs 21:00 - 00:00 3.00 CASE PROD1 Run 7" 26# L-80 BTC Mod casing, total 85 jts. 1/10/2001 00:00 - 07:00 7.00 CASE PROD1 Finish running 234 jts 7" 26~ L-80 BTC mod casing. Casing shoe at 9772'. 07:00 - 09:00 2.00 CASE PROD1 Make up Dowell cement and circulate casing volume at 10 bpm with 800 psi. 09:00 - 09:30 0.50 CASE PROD1 PJSM with all personel. 09:30 - 10:30 1.00 CASE LINE PROD1 Demco valve stem on cement line was seized up and would open. Replaced valve. 10:30 - 14:30 4.00 CASE 'PROD1 Test lines 3500 psi. Pump 20 bls water and 50 bbls Chemical wash. Mix and pump 264 bbls(335 sxs) ASIII at 10.7 ppg. Tail with 51 bbls (245 sxs) Class"G" at 15.8 ppg. Wash lines, drop top plug and displace with rig pumps. Bumped plug with 95% pump efficiency to 2700 psi. Floats held. CIP @ 1300. Full returns with 10 bbls of 10.7ppg cement back to surface. 14:30 - 17:00 2.50 CASE PROD1 lay out land jt., flush cement lines, change elev. clear floor 17:00 - 17:30 0.50 CASE PROD1 Flush BOP stack 17:30 - 22:00 4.50 CASE PROD1 Run pack off, wouldn't test, pull pack off, flush head, run new pack off, test to 5000# for 15 min. 22:00 - 00:00 2.00 CASE PROD1 PJSM, Change rams to 3.5, test door seals to 1000# 1/11/2001 00:00 - 01:00 1.00 CASE PROD1 Pull test plug and install wear ring. 01:00 - 02:00 1.00 CASE PROD1 Change top drive from 4-1/2 to 3-1/2. 02:00 - 04:30 2.50 STWHIP WEXIT Make up for bha for dummy/tie-in run for setting whipstock and MWD. Test MWD. 04:30 - 08:00 3.50 STWHIP WEXIT Continue tih. Tagged float collar at 9700'. 13' deeper than float collar @ 9687'. Double checked all casing tallies-ok. 08:00 - 12:00 4.00 STWHIP WEXIT Mad pass from 9701-9200 to confirm depths of sands and RA tag. RA i tag was 13' deeper. 12:00 - 13:00 1.00 STWHIP WEXIT Pooh 15 stands to 8300'. Air line to crown-a-matic froze. 13:00 - 17:30 4.50 STWHIP DRAW WEXIT Repair air line to crown-a-matic 17:30 - 23:00 5.50 STWHIP WEXIT Finish trip out, drill pipe strap was same as pipe tally 7" float collar @ 9700 23:00 - 00:00 1.00 STWHIP WEXIT Test csg to 3500# for 30 min. 1/12/2001 00:00 - 07:30 7.50 STWHIP WEXIT Finish tih with whipstock. Tag float collar at 9700'. 07:30 - 08:00 0.50 STWHIP WEXIT Establish up and down weights. Orient and set whipstock at 7 degrees right of high side. Window will be from 9545'-9557'. 08:00 - 09:00 1.00 STWHIP WEX~fl'~. Pump sweep and displace well with 9.1 Baradril mud. 09:00 - 18:00 9.00 STWHIP WEXIT "~ Milling window from 9545-9557, starting mill depth 9572, 85 rpm, 4-5,000 wt., 225 gals min 2000# pump pressure 18:00 - 19:30 1.50 STWHIP WEXIT Pump sweep 19:30 - 22:00 2.50 STWHIP WEXIT Trip out, mill full gauge. 6.151 22:00 - 00:00 2.00 STWHIP WEXIT Lay down BHA 1/13/2001 00:00 - 03:00 3.00 STWHIP WEXIT Finsh laying down bha and clear rig floor. Printed: 2/26/2001 3:08:06 PM BP EXPLORATION Page 3 of 7 Operations Summa Report MAR g 1 2[1[11 A~ask~ Oi~~" Cc".., r,^,~ ..... r. nmmissiO~ Legal Well Name: MPE-24 Anchorage Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG 'Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 1/13/2001 03:00 - 03:30 0.50 STWHIP WEXlT Rig up and flush out bop stack. 03:30 - 04:30 1.00 BOPSUF; PROD1 Pull wear ring and install test plug. 04:30 - 11:00 6.50 BOPSUF PROD1 Test bops. Annular 250/2000 psi 5 min/10 min. All rams and valves 250/3500 psi 5 min/10 min. Test was witnessed by John Crisp with AOGCC. 11:00 - 12:00 1.00 BOPSUF PROD1 Blow down test lines. Pull test plug and install wear ring. 12:00 - 15:00 3.00 DRILL PROD1 ' Make up directional bha and test MWD, 15:00- 19:00 4,00 DRILL PROD1 Tih with bha to 9488 19:00 - 20:30 1.50 DRILL PROD1 Slip and cut drilling line 85 ft. 20:30 - 23:00 2.50 DRILL POWR PROD1 Rig repair, Elec. breaker in sub, lost all power to floor 23:00 - 23:30 0.50 DRILL PROD1 Finish cutting drlg line 23:30 - 00:00 0.50 DRILL PROD1 Orient tools and run tru window 1/14/2001 00:00 - 00:30 0.50 DRILL PROD1 Drilling directional from 9557-9602 00:30 - 01:00 0,50 DRILL PROD1 FIT test to 11.0~ with 9.1 mud and 430 psi. 01:00 - 14:30 13.50 DRILL PROD1 Drilling directional from 9,602- 10,467 wi 4/5000# wt. 70 rpm, 2300~ with 230 gals 14:30- 15:30 1.00 DRILL PROD1 circ. 15:30 - 00:00 8.50 DRILL PROD1 Drilling directional from 10,467-11,153 w/4/5000~ wt. 70 rpm, 2300# with 230 gals, change out mud while drilling 1/15/2001 00:00 - 01:30 1.50 DRILL PROD1 Drilling directional from11,153- 11,200 wi 4/5000# wt. 70 rpm, 2300# with 230 gals 01:30 - 04:00 2.50 DRILL PROD1 Short trip to window@9,545 no problems, pumped out 04:00 - 05:00 1.00 DRILL PROD1 Service rig and blow down top drive 05:00 - 06:00 1.00 DRILL PROD1 Trip in hole, wash 60 ft to bottom 06:00 - 00:00 18.00 DRILL PROD1 Drilling directional from 11,200-12354w/ 4/5000# wt. 70 rpm, 2300~ with 230 gals, sliding hrs 6, rot. hrs 8 1/16/2001 00:00 - 07:30 7.50 DRILL PROD1 Drilling directional from 12354-12860 TD well w/4/5000~ wt. 70 rpm, 2300# with 230 gals, sliding hrs 1, rot. hrs 5 07:30 - 10:00 2.50 DRILL PROD1 Circ, high vis sweeps 10:00 - 15:00 5.00 DRILL PROD1 Tripping up to window @ 9545. pumping out, no problems taking p/u and s/o fi/weights every 5 sds. 15:00 - 17:30 2.50 DRILL PROD1 Circ bottoms up and hooked up wildcat driller, monitor well 17:30 - 00:00 6.50 DRILL PROD1 Trip out, lay down BHA taking p/u and s/o fi/weights every 10 sds. 1/17/2001 00:00 - 01:30 1.50 DRILL PROD1 Finish laying out BHA 01:30 - 06:00 4.50 DRILL PROD1 Pick up Bha, 6 1/8 porcupine hole opener and two full gauge stab and one under gauge stab, trip in to window@ 9545 ;06:00 - 08:30 2.50 DRILL COND PROD1 Circ, putting shaker screens on new circ rate., shakers wouldn't handle rate. 08:30 - 18:30 10.00 DRILL . PROD1 Reaming with hole opener from 9557-12860 300 ft per hr. 100 rpms and 300 gals min. 18:30 - 21:00 2.50 DRILL PROD1 Circ 3 bottoms up and change out to new mud 21:00 - 00:00 3.00 DRILL PROD1 Tripping out for liner, pumping out of open hole, no problems getting pu and so wts every 5 sds. 1/18/2001 00:00 - 06:00 6.00 DRILL PROD1 Tripping out for liner, pumping out of open hole without rotating, no . problems, Take p/u and s/o wts every 5 sds. moniter well @ window - Pump slug - Pooh - Lay down BHA 06:00 - 08:00 2.00 CASE PROD1 Clear rig foor, -PJSM, Rig up Nabor casing tools 08:00 - 08:30 0.50 CASE DRAW PROD1 Install wildcat auto-matic driller on drawworks 08:30 - 09:00 0.50 CASE PROD1 Safety meeting with drill crew and service personnel on running 4 1/2" slotted liner 09:00 - 14:00 5.00 CASE PROD1 Picking up 84 jts of 4.5, 12.6#, L-80 slotted liner + 2 jts of 4.5, 12.6~ L80 IBT solid csg & one solid shoe it. 12.6# L80 IBT - Install one Printed: 212612001 3:08:06 PM (' RECEIVED BP EXPLORATION MAR I 7.001 Page 4 of 7 Operations Summary ReportAlaska Oil & Gas Cons. Commission Anchorage Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001. Group: RIG Rig Name: NABORS 22E Rig Number: 22E Date From-To Hours Task Sub Code Phase Description of Operations 1/18/2001 09:00 - 14:00 5.00! CASE PROD1 floating 4 5/8 X 5 3/4 Centralizers per JT., total 3,432 ft. - Torque 4000 ft/Ib 14:00 - 15:00 1.00 CASE PROD1 PJSM, Rig up false rotary table - Change out handling tool to 2 7/8 15:00 - 20:30 5.50 CASE PROD1 Pick up 107 its of 2 7/8 7.7# K-Fox inter string and spaceing out. Pick up Baker 7 x 5" HMC liner hanger. 20:30 - 22:00 1.50 CASE PROD1 Clear floor of csg. tools 22:00 - 22:30 0.50 CASE PROD1 circ. 2 718 volume 22:30 - 00:00 1.50 CASE PROD1 Trip in with 4 1/2" slotted liner on 3 112" drill pipe - Takeg p/u and sic weights every 10 sds. - +/- 5000' at 00:00 hrs 1/19/2001 00:00 - 03:00 3.00 CASE PROD1 Continue TIH with 4 1/2" slotted liner on 3 1/2" drill pipe to window at 9,545 03:00 - 04:00 1.00 CASE PROD1 Break circulation, Circulate liner vol. 3 bpm 800 psi 04:00 - 07:30 3.50 CASE PROD1 Trip in open hole with 4 112" slotted liner - take plu & sic wts every 5 stands - liner differential sticking when in slips from +/- 10,000' to Bottom - slingshot drill pipe to break free, Taking all wt. + top drive to break free - No problem after getting pipe moving. Land liner on bottom at 12,860' - top liner 9,428' 07:30 - 08:00 0.50 CASE PROD1 Break circulation & circulate drill pipe volume. 3 bpm 1000 psi 08:00 - 08:30 0.50 CASE PROD1 Drop 1 7/16" steel ball and circulate to ball seat at 12,830' 08:30 - 09:00 0.50 CASE PROD1 Pressure up to 2000 psi and set Baker Hmc liner hanger at 9436' - Pressure up to 3000 psi and release from Baker HR running tool. Started losing pressure after running tool released. Could not shear out ball seat due to circulation. Circulate at 5 bpm 4000 psi 09:00 - 16:30 7.50 CASE PROD1 Tripping out with inter string 16:30 - 22:30 6.00 CASE PROD1 PJSM, Rig up and laying down inter-string Rig down csg tools and clear floor 22:30 - 00:00 1.50 STWHIP WEXIT Picking up BHA #6 baker seal ass., float sub, MWD,hang off collar, bumper sub, 9 steel DC, 18 HWDP to verify setting depth for whip stock 1/20/2001 00:00 - 03:00 3.00 S3'WHIP WEXIT Picking up BHA #6 baker seal ass., float sub, MWD,hang off collar, bumper sub, 9 steel DC, 18 HWDP to verify setting depth for whip stock 03:00 - 08:30 5.50 STWHIP WEXIT Tripping in hole with seal ass. 08:30 - 10:30 2.00 STWHIP WEXIT Logging with MWD tool from 9074-9437 tag bottom tie back sleeve @ 9437 top CA sand 9385 10:30 - 13:00 2.50 STWHIP WEXIT PJSM, Cut 90 ft. drlg line 13:00 - 19:30 6.50 STWHIP WEXIT Tripping out with seal ass. and lay down seal ass. 19:30 - 20:00 0.50 STWHIP WEXIT PJSM, Pull wear ring and run test plug to test bops 20:00 - 00:00 4.00 STWHIP WEXIT Testing BOPS and manifold 250-2000# BOP test was wavied by Jerry Jones 1/21/2001 00:00 - 03:30 3.50 STWHIP WEXIT PJSM, Testing BOPS and manifold 250-2000~ BOP test was wavied by Jerry Jones 03:30 - 04:30 1.00 STWHIP WEXIT PJSM, Remove and move and replace kelly hose and test to 4000# 04:30 - 05:30 1.00 STWHIP WEXIT PJSM, Blow down choke manifold and top drive, mud lines 05:30 - 06:00 0.50 STWHIP WEXIT PJSM, pull test plug and run wear ring 06:00- 07:00 1.00 STWHIP FLOR WEXIT Repair Hyd. pump 07:00 - 09:30 2.50 STWHIP WEXIT PJSM, Pick up whipstock and orient Baker window master whipstock and BHA # 7 starting mill, lower string mill, upper string mill, 1 HWDP, float sub, mwd bumper sub, 9 dc., 18 HWDP 09:30 - 15:30 6.00 STWHIP WEXIT PJSM, Trip in hole with whipstock, fill every 25 sds. 15:30 - 16:00 0.50 STWHIP: WEXIT Orient whip stock to 2 degees right of high side-set whipstock anchor w/ Printed: 2/26/2001 3:08:06 PM BP EXPLORATIONRECEIVE e o Operations Summa Report MAR 2 1 2001 Legal Well Name: MPE-24 Common Well Name: MPE-24A Alaska q~l~t~'l~: Event Name: RE ENTER Start: 1/14/2001 En~nch°rage 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 1/21/2001 15:30 - 16:00 0.50 STWHIP WEXIT 20,000 down wt.-pull test with 5,000~ shear off with 35,000 top of whipstock set @ 9385 16:00 - 23:30 7.50 STWHIP WEXIT . Milling window with 230 gals., 1550 psi, 60 rpms, 3000 # torque, ~2-3,000 wt. top off window-9385 bottom window-9397 mill depth- 9414 23:30 - 00:00 0.501 STWHIP WEXIT Pump high vis sweeps and working mills tru window 1122/2001 00:00 - 01:30 1.50 STWHIP WEXIT Pump high vis sweeps and working mills tru window 01:30 - 06:00 4.50 STWHIP WEXIT Tripping out, mills full gauge 06:00 - 06:30 0.50 S'I'WHIP WEXIT wash BOPS with bop washer 06:30 - 11:30 5.00 DRILL PROD1 Pick up new Bha #8-RR Bit, 4314 sperry motor 1.5 deg. bent houseing and ABI, LWD, MWD, hang off sub, 3 non-mag dc, jars- tripping in 11:30- 13:30 2.00 DRILL DRAW PROD1 Rig repair- repair drawworks 13:30 - 16:30 3.00 DRILL PROD1 Trip in hole to window @ 9397 16:30 - 17:00 0.50 DRILL PROD1 Orient tools, poor reading from MWD tool 17:00 - 20:30 3.50 DRILL PROD1 Drill Directional from 9397-9601 Rt 1hr - Sliding 1 hr- bit wt.3-4000 pump pressure 2200# gals 256 RPMS 70 20:30 - 21:30 1.00 DRILL PROD1 re-log from 9480-9601 due to poor reading from MWD 21:30 - 22:00 0.50 DRILL PROD1 Drill Directional from 9601-9643 Rt .25 hr- Sliding 0- bit wt.3-4,000 pump pressure 2200~ gals 256 RPMS 70 22:00 - 23:00 1.00 DRILL PROD1 checking MWD tool and mud pits tool not reading right put deformer in mud, tool started reading 23:00 - 00:00 1.00 DRILL PROD1 Drill Directional from 9643-9722 Rt 1 hr- Sliding .25 hr- bit wt. 3-4000 pump pressure 2200~ gals 256 RPMS 70 1/23/2001 00:00 - 07:00 7.00 DRILL i PROD2 Directional drill f/9722' to 10185'. Ast-1.25 hrs, Art-2.75 hrs. 256 gpm, 2150/2350 psi, 2k wob, 4k tq. Getting poor signals from MWD. 07:00 - 08:00 1.00 DRILL LMWD PROD2 Pump out of hole to 9400' 08:00- 13:30 5.50 DRILL LMWD PROD2 Monitor well, slug pipe, continue POOH 13:30 - 16:30 3.00 DRILL LMWD PROD2 Download MWD. Change out motor, MWD and pulser. Load MWD. 16:30 - 19:00 2.50 DRILL LMWD PROD2 TIH to 2547'. Test MWD, weak signal. Continue TIH to 4858'. 19:00-21:00 2.00 DRILL LMWD PROD2 Attempt to get good signal from MWD. Nosuccess. Troubleshoot all MWD surface equipment, add more defoamer to mud, adjust pulsation dampners, alter pump speeds/psi, switch SCR assignments, pressure test pumps. Pressure test of pumps to 3000 psi, bled to 2500 psi in 1 minute, could not find leak. 21:00 - 22:00 1.00 DRILL LMWD PROD2 TIH to 7164'. Open and inspect all valves, valve seats and seals on pump #1 while TIH. 22:00 - 23:00 1.00 DRILL LMWD PROD2 Attempt to get good signal from MWD, r~o success. No signal from MWD. 23:00 - 00:00 1.00 DRILL LMWD PROD2 POOH to check MWD. 1/24/2001 00:00 - 02:30 2.50 DRILL LMWD PROD2 Continue POOH to change out MWD 02:30 - 06:30 4.00 DRILL LMWD PROD2 Download MWD, change out pulser, test MWD - good test 06:30 - 07:30 1.00 DRILL LMWD PROD2 TIH w/BHA plus 10 stands 07:30 - 08:00 0.50 DRILL LMWD PROD2 Test MWD - good test 08:00 - 12:00 4.00 DRILL LMWD PROD2 TIH, wash last 45' to bottom 12:00 - 00:00 12.00 DRILL PROD2 Drill f/10185' to 11200'. Art-6.25 hrs. Ast-1.5 hrs. 235gpm, 2050/2150 psi, 2-4 wob, 3-4k tq.Maintaining MW at 9.1 ppg. 1/25/2001 00:00 - 02:30 2.50 DRILL PROD2 Drilling f/11200' to 11345' in OA sand. Art- 1.25 hrs, Ast- .25 hrs. 235 gpm, 210012200 psi, 2-4 wob, 3-4k tq. 02:30 - 05:00 2.50 DRILL PROD2 Pump out of hole to shoe, no problems. 05:00 - 06:00 1.00 DRILL PROD2 Service top drive and crown. 06:00 - 14:00 8.00 DRILL ClRC PROD2 Repair shale shakers - change out bad motor. Printed: 2/26/2001 3:08:06 PM BP EXPLORATIONRECEiVE[ ge6°f7 Operations Summa Report MAR 1 2001 Legal Well Name: MPE-24 Common Well Name: MPE-24A Alaska ~lJt~__ [yat~ Ci~,~/2001 Event Name: RE ENTER Start: 1/14/2001 En~n' ' -cn0rage 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 112512001 14:00 - 15:001.00 DRILL PROD2 TIH, max 5k drag. 15:00 - 00:00 9.00 DRILL PROD2 Drilling fl 11345' to 12165' in OA sand. Art- 5.0 hfs, Asr- 1.25 hrs. 232 gpm, 2200/2300 psi, 2-4 wob, 3-4k tq. Maintaining 9.1-9.3 mud wt. 1/26/2001 00:00 - 10:30 10.50 DRILL PROD2 Drill to 12165' to 12850' total depth. Art- 6.25hrs, Ast- 2.25 hrs. Drilling w/235gpm, 2200/2350psi, 2-4wob, 3-4k tq. 10:30 - 13:00 2.50 DRILL PROD2 Circulate hole clean and displace to new 9.1 Baradrill mud w/2% lubetex. Circulate 3 bottoms up at 235 gpm, 2200 psi. 13:00 - 17:30 4.50 DRILL PROD2 Pump out of hole at 235 gpm to window, no problems. Taking PU and SO wts every 5 stds. 17:30 - 18:00 0.50 DRILL PROD2 Monitor well, pump slug. 18:00 - 22:00 4.00 DRILL PROD2 Pooh taking PU and SO wts every 10 stds. 22:00 - 00:00 2.00 DRILL . PROD2 Download MWD and lay down BHA. 1/27/2001 00:00 - 01:00 1.00 DRILL PROD2 Finish LD drilling BHA ~01:00 - 02:00 1.00 DRILL PROD2 PJSM, PU 6 1/8" porcupine holeopener BHA w/2 full gauge stabs 02:00 - 05:30 3.50 DRILL PROD2 TIH to 9385', fill pipe every 25 stands 05:30 - 16:30 11.00 DRILL PROD2 Ream with porcupine hole opener from 9485' to 12850'. No hole 3roblems, no bridges. 100rpm, 295gpm, 2200psi 16:30 - 19:30 3.00 DRILL PROD2 Circ sweep around and 3 hole volumes, shakers clean. Spot 130 bbl new 9.1 ppg Baradrill mud w/3% lubetex in open hole. 19:30 - 22:00 2.50 DRILL PROD2 POOH to 9312', no problems. 22:00 - 22:30 0.50 DRILL PROD2 Spot 2 drums EP Mudlube in 30 bbl pill in cased hole f/9312' to 8000' 22:30 - 00:00 1.50 DRILL PROD2 POOH 1/28/2001 00:00 - 03:00 3.00 DRILL PROD2 Continue Pooh with hole opener bha 03:00 - 03:30 0.50 DRILL PROD2 LD hole opener bha 03:30 - 04:00 0.50 DRILL PROD2 Clear rig floor, PJSM 04:00 - 05:30 1.50 DRILL PROD2 MU whipstock retrieving tool bha w/MWD, load MWD. 05:30 - 09:30 4.00 DRILL PROD2 Test MWD, TIH to 9044' filling every 25 stands 09:30 - 11:30 2.00 DRILL PROD2 PJSM, slip and cut 117' drillline 11:30 - 12:00 0.50' DRILL PROD2 Continue tih to 9338', orient to highside, latchup whipstock @ 9389'. PU to 45k, let jars hit and pull whipstock free 12:00 - 12:30 0.50 DRILL PROD2 Monitor well, pump slug 12:30 - 19:30 7.00 DRILL PROD2 Pooh, lay down whipstock, MWD and bha 19:30 - 21:00 1.50 CASE COMP . Change bails, RU casing tools 21:00 - 21:30 0.50 CASE COMP Safety meeting with drill crew and service personnel on running slotted liner 21:30 - 00:00 2.50 CASE COMP Run 4 1/2", 12.6#, L80, BTC slotted liner. 45 jts ran at midnight. 1/29/2001 00:00 - 02:00 2.00 CASE COMP Continue Running 4 1/2" 12.6~ L-80 IBT slotted liner - Ran 84 jts slotted, 2 jts solid for 3367.24' - Torque 3800 ft/Ib 02:00 - 03:00 1.00 CASE COMP Change handling tools to 2 7/8" - Rig up False rotary table 03:00 - 06:00 3.00 CASE COMP Make up Baker slick stick, Pick up 106 jts 2 7/8" 7.7# K-Fox inter-string - torque 1800 ft/Ibs - Space out & Pick up Baker 7" casing Hook liner hanger 06:00 - 07:00 1.00 CASE COMP Change handling tools to 3 1/2" drill pipe 07:00 - 07:30 0.50 CASE COMP Circulate 2 7/8" K-Fox tubing capacity 4 bpm 600 psi 07:30 - 09:30 2.00 CASE COMP TIH with 4 1/2" slotted liner on 3 1/2" 13.3~ 'G' drill pipe to 9,385' 09:30 - 10:00 0.50 CASE COMP Circulate capacity of drill pipe & tubing 4 bpm 1000 psi 10:00 - 10:30 0.50 CASE ;COMP work bent shoe jt through window at 9,385': Set down on top of'OB' liner top at 9,435' two times - With string in tension, rotate string one turn to right - Slack off and exited 7" casing 10:30 - 11:30 1.00 CASE COMP Continue TIH with 4 1/2" liner to setting depth at 12,775' - No problem with differential sticking - with top of liner at window p/u wt. 150k, s/o wt. 90k - Ran to setting depth with drill pipe, did not use HWT. Printed: 2/26/2001 3:08:06 PM BP EXPLORATION Page 7 of 7 Operations Summa Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/1/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 1/29/2001 11:30 - 12:00 0.50 CASE COMP Screw into last stand and fish for bottom of window with Baker 7" Hook liner hanger, Work though window two time, no latch, With sting in compression, Rotate string 1/2 turn to right and lack off- latch bottom of window on third time of rotating 1/2 turn. - lack off all string wt. on bottom of window 12:00 - 12:30 0.50 CASE COMP Circulate capacity of drill string at 4 bpm 1100 psi 12:30 - 13:30 1.00 CASE COMP Drop 1 7/16" steel ball and Circulate down to ball seat at 12,755' 13:30 - 14:00 0.50, CASE COMP With ball on seat, Pressure up to 3000 psi & release HR running tool from liner, Lost 10k wt. - Pressure up to 4200 psi and shear out ball seat. - Pump slug 14:00 - 17:00 3.00 CASE COMP POOH, rack back 9300' of 3 1/2" 17:00 - 20:00 3.00 CASE COMP PJSM, POOH laying down 3 1/2" drillpipe 20:00 - 00:00 4.00 CASE COMP LD hanger running tool, POOH laying down 2 7/8" inner string 1/30/2001 00:00 - 01:30 1.50 CASE COMP Continue laying down 2 7/8" and liner running tool. 01:30 - 02:00 0.50 RUNCOI~ COMP RD 2 7/8" tool, RU 3 1/2" tools 02:00 - 02:30 0.50 RUNCOI~ COMP TIH w/HWDP & DC 02:30 - 03:30 1.00 RUNCOI~ 'COMP Service rig 03:30 - 04:00 0.50 RUNCOI~ COMP POOH laying down HWDP & DC 04:00 - 09:00 5.00 RUNCOI~! COMP Test BOP's. Rams and valves to 250psi, then 3500psi. Annular to 250 3si, then 2000psi. 09:00 - 14:30 5.50 RUNCOI~! COMP PU Baker 7" Retrivable Bridge Plug and TIH on 3 1/2" drillpipe to 9300' 14:30 - 15:00 0.50 RUNCOI~! COMP Drop ball, pump down and set RBP w/3400 psi. RBP at 9300' 15:00 - 16:00 1.00 RUNCOI~ COMP Test casing and RBP to 1000 psi - good test 16:00 - 16:30 0.50 RUNCOI~ COMP Drop dart and pump down to open circ sub 16:30 - 18:30 2.00 RUNCOI~ COMP Pump HiVis sweep, caustic pill and displace to seawater 18:30 - 20:00 1.50 RUNCOI~ COMP Displace to 9.1 KCL water 20:00 - 00:00 4.00 RUNCOI~ COMP POOH laying down drillpipe 1/31/2001 00:00 - 02:30 2.50 RUNCOI~ COMP POOH laying down 3 1/2" drillpipe, LD RBP running tool. 02:30 - 05:00 2.50 RUNCOI~ COMP ND BOP, flowline and choke hose. Remove DSA and drilling spool. Install valves on tubing spool. 05:00 - 06:00 1.00 RUNCOI~ COMP NU tubing spool, test same to 5000 psi. 06:00 - 09:00 3.00 RUNCOI~I COMP NU DSA, BOP and flowline 09:00 - 09:30 0.50 RUNCOI~ COMP Run test plug and test spool and DSA to 250psi, then 3500psi 09:30 - 19:30 10.00 RUNCOI~I COMP MU retrievable bridge plug retrieving tool and TIH picking up 2 7~8" tubing to 9187' 19:30 - 21:00 1.50 RUNCOI~I COMP MU tubing hanger, install TWC, run and land same. Test TWC to 1000psi from both above and below TWC. Bottom of retrieving tool at 9214'. 21:00 - 22:30 1.50 RUNCO~I COMP Pull master bushing and clean drip pan and steam tables prior to ND BOP 22:30 - 00:00 1.50 RUNCO~ COMP ND BOP, flowline and choke hose 2/1/2001 00:00 - 02:00 2.00 RUNCO~ COMP Nipple up tree and test same 5000 psi-ok. 02:00 - 03:00 1.00 RUNCO~ COMP Rig up to u-tube annulus and tubing for freeze protection. 03:00 - 04:30 1.50 RUNCO~ COMP Pull TWC and pump 80 bbls diesel down annulus to freeze protect annulus and tubing. 04:30 - 06:00 1.50 RUNCOr COMP Let annulus and tubing u-tube and equalize. O psi. Secure well. Release rig at 0600 hrs. ~ .... ? ', :; ..... ,, .. ....... ....: ..... ,, R~al~ ~ ~1"~"= ' ~I~=,~, . ';.V' ~,~" '"" ' MAR 2 1 ZOO1 Alaska Oil & Gas Cons. Commission Printed: 2/26/2001 3:08:06 PM BP EXPLORATION Page 1 of 1 Operations Summa Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/14/2001 Event Name: COMPLETION Start: 2/9/2001 End: 2/15/2001 Contractor Name: NABORS Rig Release: 2/13/2001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 2/9/2001 00:00 - 02:30 2.50 RIGU COMP Install 3 1/2 jaws and guides in top drive 02:30 - 06:00 3.50 RIGU COMP Pick up 60 its of 5 in pipe in mouse hole and stand in derrick to use as belly board for 2 7/8 tubing 06:00 - 07:00 1.00 BOPSUF COMP Rig up lubricator and pull back pressure valve and set two way check 07:00 - 08:00 1.00 BOPSUF COMP N/d tree and nipple up adaptor flange 08:00- 10:30 2.50 BOPSUF BARR COMP Repair bridge crane 10:30 - 19:30 9.00 BOPSUR COMP Nipple up BOPS and change upper and lower rams to 2 7/8 19:30 - 22:00 2.50 BOPSUR COMP Pick up test it. and Tiw valve and dart valve 22:00 - 22:30 0.50 BOPSUI~ COMP Attemp to test upper rams would not test leaking 22:30 - 00:00 1.50 BOPSUF; BARR COMP Open doors to upper rams and change out rams 2/10/2001 00:00 - 02:00 2.00 BOPSUI~ BARR COMP Change out top rams 02:00 - 10:00 8.00 BOPSUI; 'COMP Testing BOPS 250#-2000# test waiver By John Spalding 10:00 - 11:00 1.00 BOPSUI; COMP Pick up lubricator and pull two way check 11:00 - 14:30 3.50 CLEAN COMP Pick up landing jt. and made up to hanger, circ. out diesel recover 80 bbls of diesel 14:30 - 15:30 1.00 PULL COMP Pulled hanger and layed down same 15:30 - 18:00 2.50 PULL COMP Pick up 5 jts of 2 7/8 tubing and latch bridge plug and pull the same, lay down 1 jt. of tubing, circ. bottoms, losses to well bore 8-9 bbls per hr. 90,000 pickup 85,000 slack off 1,000 psi 30 spm 18:00 - 23:30 5.50 PULL COMP Monitor well and tripping out with 89 sds. of tubing and stand in derrick 23:30 - 00:00 0.50 PULL COMP Rigged up to lay down 25 jts of tubing 2/1112001 00:00 - 02:00 2.00 PULL COMP Laying down 25 jts. 2 7/8 tubing 02:00 - 21:00 19.00 RUNCO~ ri'RAN COMP Monitor well, Iosts to well slowed to 1.5 bbls per hr. wait on ESP pump and spooling unit, clean rig and working on rock washer 21:00 - 23:00 2.00 RUNCO~ COMP PJSM and rig up spooling unit and rig floor 23:00 - 00:00 1.00 RUNCO~ COMP PJSM, picking up ESP motor 2/12/2001 00:00 - 04:00 4.00 RUNCOr COMP Picking up ESP motor 04:00 - 19:30 15.50 RUNCOr COMP Picking up 2 7/8 L-80 6.5~ tubing and GLMs and running ESP motor, flush tubing @ 5000 f. and 9100 wi 500 pump pressure @ 1.5 bbls per min., installing clamps ever 60 ft. total jts run 286, total clamps used Lacalle 148, pump protectors 8, fiat protectors 3, ESP motor set (~ 9194.55, X-nipple @ 9111.29, GLM#1@ 8969.1.5, GLM #2 @ 2522.68, GLM #3 ~ 138.38 19:30 - 21:30 2.00 RUNCOI~ COMP Splice ESP cable to penetrator and test ~hase to phase 3.6 ohms r~ phase to ground 2000 meg. RECEIVE hy. press bottom 1992 psi bottom hole temp. 78 ,21:30- 22:30 1.00 RUNCOI~ COMP Land tubing, lay down land it. MAR ?~ IZOO1 test 2 way check to 1000 # 22:30 - 00:00 1.50 BOPSUI; COMP Nipple down BOPS 2/13/2001 00:00 - 02:00 2.00 BOPSUI; COMP Nipple down bops Alaska Oil & Gas Cons. Commission 02:00 - 04:00 2.00 WHSUR COMP Nipple up tree and test to 5000g Anchorage 04:00 - 05:00 1.00 WHSUR COMP R/U lubricator and pull TWC, set BPV 05:00 - 07:00 2.00 RIGD COMP Lay down 5" pipe from derrick freeze protect tubing and annulus with 65 bbls diesel 15 bbls in tubing, 50 bbls in annulus Printed: 2/26/2001 3:08:27 PM DEFiNiTiVE Milne Point Unit Alaska Drilling & Wells Milne Point MPE, Slot MPE24 MPE-24A Surveyed: 26 January, 200f SURVEY REPORT 28 February, 2001 Your Ref: AP1500292286701 Surface Coordinates: 6016150.87 N, 569209.37 E (70° 27' 16.0198" N, Kelly Bushing: 53.70ft above Mean Sea Level 149° 26'06.8436"W) DRILLINB EERVICEE A Halllburlon Company Survey Reft svy9810 Sperry-Sun Drilling Services Survey Report for MPE.24A Your Ref: APl 500292286701 Surveyed: 26 January, 200f DEFINITIVE Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9464.56 73.730 188.400 4238.39 4292.09 9545.00 72.200 190.970 4261.96 4315.66 9603.77 80.210 193.320 4275.97 4329.67 9653.83 89.260 195.710 4280.56 4334.26 9695.70 95.370 195.480 4278.86 4332.56 9746.44 95.730 195.400 4273.96 4327.66 9787.12 92.650 193.570 4270.99 4324.69 9841.59 92.770 192.460 4268.41 4322.11 9883.17 93.820 193.110 4266.02 4319.72 9931.81 92.710 192.820 4263.25 4316.95 9978.17 92.220 191.060 4261.26 4314.96 10032.91 93.880 192.970 4258.34 4312.04 10073.64 93.760 192.910 4255.63 4309.33 10123.47 92.770 193.990 4252.79 4306.49 10164.55 92.340 194.780 4250.96 4304.66 10216.04 91.720 194.650 4249.14 4302.84 10256.41 91.600 194.720 4247.97 4301.67 10305.62 91.050 193.040 4246.83 4300.53 10349.50 90.620 193.370 4246.19 4299.89 10392.89 90.430 192.770 4245.79 4299.49 10443.88 90.920 191.960 4245.19 4298.89 10477.40 92.040 193.110 4244.33 4298.03 10534.12 92.160 193.140 4242.25 4295.95 10581.82 91.600 192.060 4240.68 4294.38 10623.70 91.480 191.280 4239.56 4293.26 10672.72 89.570 192.230 4239.11 4292.81 10716.53 89.570 192.390 4239.44 4293.14 10769.75 90.490 193.290 4239.41 4293.11 10806.78 93.020 196.240 4238.27 4291.97 10855.91 92.900 195.760 4235.74 4289.44 7420.88 S 474.15W 6008725.91N 568804.17 E 7496.68 S 487.08W 7552.43 S 499.10W 7600.63 S 511.59W 7640.90S 522.83W 7689.58 S 536.27W 7728.86S 546.42W 7781.87 S 558.67W 7822.35 S 567.86W 7869.67 S 578.75W 7914.99 S 588.34W 7968.45 S 599.71W 8008.05 S 608.81W 8056.44S 620.38W 8096.19 S 630.58W 8145.96S 643.65W 8184.99S 653.88W 8232.75 S 665.68W 8275.47 S 675.70W 8317.73 S 685.52W 8367.54S 696.43W 8400.24 S 703.71W 8455.45 S 716.58W 8501.97 S 726.98W 8542.97S 735.45W 8590.96S 745.43W 8633.76 S 754.77W 8685.65 S 766.60W 8721.43 S 776.03W 8768.59S 789.55W 6008649.99 N 568791.94 E 6008594.13 N 568780.44 E 6008545.82 N 568768.41 E 6008505.44 N 568757.54 E 6008456.64 N 568744.55 E 6008417.27 N 568734.77 E -6008364.15 N 568723.01E 6008323.58 N 568714.20 E 6008276.16 N 568703.74 E 6008230.76N 568694.58 E 6008177.20 N 568683.70 E 6008137.51N 568674.97 E 6008089.02 N 568663.85 E 6008049.17 N 568654.02 E 6007999.28 N 568641.41E 6007960.15 N 568631.55 E 6007912.29 N 568620.19 E 6007869.48 N 568610.56 E 6007827.13 N 568601.15 E 6007777.23 N 568590.69 E 6007744.45 N 568583.72 E 6007689.13 N 568571.37 E 6007642.51N 568561.40 E 6007601.44 N 568553.31E 6007553.36 N 568543.77 E 6007510.47 N 568534.83 E 6007458.48 N 568523.49 E 6007422.61N 568514.39 E 6007375.32 N 568501.30 E Alaska Drilling & Wells Milne Point MPE Dogleg Vertical Rate Section Comment (°ll00ft) 7349.58 3.60 7426.40 14.17 7483.42 18.69 7533.18 14.60 7574.93 0.73 7625.36 8.80 7665.90 2.05 7720.30 2.97 7761.81 2.36 7810.37 3.94 7856.68 4.62 7911.34 0.33 7951.98 2.94 8001.72 2.19 8042.73 1.23 8094.15 0.34 8134.47 3.59 8183.65 1.24 8227.52 1.45 8270.90 1.86 8321.89 4.79 8355.40 0.22 8412.07 2.55 8459.75 1.88 8501.61 4.35 8550.62 0.37 8594.43 2.42 8647.65 10.49 8684.62 1.01 8733.59 Tie on point AK-6 BP_IFR-AK KOP 28 February, 2001 - 11:52 Page 2 of 5 .. DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE-24A Your Ref: AP1500292286701 Surveyed: 26 January, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10899.28 92.710 195.450 4233.61 4287.31 10942.55 92.770 195.410 4231.55 4285.25 10988.63 92.590 194.580 4229.39 4283.09 11038.03 91.110 194.690 4227.80 4281.50 11080.72 90.860 195.700 4227.06 4280.76 11130.37 91.290 194.230 4226.13 4279.83 11172.48 91.850 193.220 4224.98 4278.68 11221.86 92.520 193.320 4223.09 4276.79 11264.85 93.080 193.210 4220.99 4274.69 11316.78 92.960 192.870 4218.26 4271.96 11355.36 93.630 192.070 4216.04 4269.74 11407.59 95.550 191.850 4211.86 4265.56 11448.19 94.880 191.660 4208.17 4261.87 11496.02 94.000 191.410 4204.47 4258.17 11536.78 93.690 189.680 4201.74 4255.44 11586.13 94.070 188.950 4198.40 4252.10 11624.66 92.770 189.760 4196.10 4249.80 11675.10 91.720 188.440 4194.12 4247.82 11721.95 91.290 188.600 4192.89 4246.59 11769.38 90.370 187.680 4192.20 4245.90 11815.67 91.230 187.010 4191.56 4245.26 11866.61 92.340 189.110 4189.97 4243.67 11910.25 93.630 188.840 4187.70 4241.40 11964.13 92.840 187.280 4184.66 4238.36 11994.18 91.850 188.060 4183.43 4237.13 12046.87 93.320 187.130 4181.05 4234.75 12095.08 92.710 187.060 4178.52 4232.22 12141.92 93.080 186.960 4176.15 4229.85 12189.10 92.470 186.460 4173.87 4227.57 12239.46 94.190 186.920 4170.94 4224.64 8810.32S 801.21W 8851.98 S 812.70W 8896.44S 824.61W 8944.21S 837.09W 8985.40 S 848.28W 9033.36 S 861.09W 9074.25 S 871.08W 9122.28 S 882.41W 9164.07S 892.26W 9214.59S 903.96W 9252.20 S 912.28W 9303.13 S 923.07W 9342.71S 931.30W 9389.43 S 940.84W 9429.41S 948.28W 9478.00 S 956.25W 9515.95 S 962.50W 9565.71S 970.47W 9612.03 S 977.41W 9658.98 S 984.13W 9704.88 S 990.04W 9755.29 S 997.18W 9798.34S 1003.98W 9851.60 S 1011.52W 9881.35 S 1015.53W 9933.53 S 1022.49W 9981.30 S 1028.43W 10027.73 S 1034.14W 10074.53 S 1039.65W 10124.46S 1045.51W 6007333.49 N 568490.04 E 6007291.72 N 568478.93 E 6007247.15 N 568467.43 E 6007199.27 N 568455.40 E 6007157.98 N 568444.60 E 6007109.90 N 568432.22 E 6007068.92 N 568422.62 E 6007020.79 N 568411.74 E 6006978.91N 568402.27 E 6006928.28 N 568391.04 E 6006890.60 N 568383.07E 6006839.57 N 568372.76E 6006799.91N 568364.89 E 6006753.10 N 568355.79 E 6006713.06N 568348.72 E 6006664.40 N 568341.20 E 6006626.39 N 568335.30 E 6006576.55 N 568327.79 E 6006530.18 N 568321.29 E 6006483.17 N 568315.01E 6006437.21N 568309.52 E 6006386.74N 568302.85 E 6006343.63 N 568296.45 E 6006290.30 N 568289.40 E 6006260.51N 568285.67 E 6006208.28 N 568279.20 E 6006160.45 N 568273.70 E 6006113.97 N 568268.42 E 6006067.12 N 568263.35 E 6006017.13 N 568257.96 E Dogleg Rate (O/'lOOft) 0.84 0.17 1.84 3.00 2.44 3.08 2.74 1.37 1.33 0.69 2.70 3.70 1.71 1.91 4.30 1.66 3.97 3.34 0.98 2.74 2.36 4.66 3.02 3.24 4.19 3.30 1.27 0.82 1.67 3.54 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 8776.84 8820.00 8865.98 8915.32 8957.95 9O07.54 9049.62 9098.96 9141.89 9193.75 9232.26 9284.32 9324.75 9372.43 9413.08 9462.24 9500.65 9550.96 9597.69 9644.98 9691.09 9741.85 9785.35 9838.99 9868.91 9921.36 9969.30 10015.87 10062.77 10112.79 26 February, 2001 - 11:52 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE-24A Your Ref: AP150029228670f Surveyed: 26 January, 200f Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (rt) (ft) (ft) (ft) 12283.35 93.760 187.000 4167.90 4221.60 10167.92 s 1050.81 w 12333.83 93.200 186.330 4164.83 4218.53 10217.97 s 1056.66 w 12379.09 93.020 186.150 4162.38 4216.08 10262.90 s 1061.57 w 12432.14 94.010 186.840 4159.13 4212.83 10315.51 s 1067.56 w 12471.13 93.080 185.330 4156.72 4210.42 10354.20 s 1071.68 w 12518.45 91.230 186.240 4154.94 4208.64 10401.24 S 1076.45 W 12565.07 90.250 185.780 4154.33 4208.03 10447.60 S 1081.33 W 12613.15 91.600 187.530 4153.56 4207.26 10495.35 S 1086.90 VV 12657.99 91.170 186.940 4152.47 4206.17 10539.82 S 1092.55 W 12706.22 90.920 186.510 4151.59 4205.29 10587.71 S 1098.20 W 12749.31 90.800 186.470 4150.95 4204.65 10630.52 S 1103.07W . 12791.09 90.250 185.460 4150.56 4204.26 10672.07 S 1107.41W 12860.00 90.250 185.460 4150.26 4203.96 10740.67 S 1113.96W Global Coordinates Northings Easfings (ft) (ft) 6005973.62 N 568253.05 E 6005923.53 N 568247.67 E 6005878.56 N 568243.18 E 6005825.89 N 568237.68 E 6005787.16 N 568233.91E 6005740.08 N 568229.58 E 6005693.67 N 568225.13 E 6005645.88 N 568220.00 E 6005601.36 N 568214.77 E 6005553.42 N 568209.57 E 6005510.56 N 568205.10 E 6005468.97 N 568201.14 E 6005400.32 N 568195.22 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.463° (04-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 192.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12860.00ff., The Bottom Hole Displacement is 10798.28ft., in the Direction of 185.921° (True). Dogleg Rate (°llOOft) 1.00 1.73 0.56 2.27 4.54 4.36 2.32 4.60 1.63 1.03 0.29 2.75 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 10156.38 10206.51 10251.44 10304.11 10342.79 10389.76 10436.08 10483.91 10528.56 10576.54 1O619.40 10660.91 10729.32 Projected survey 28 February, 2001 - 11:52 Page 4 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE-24A Your Ref: AP1 50029228670f Surveyed: 26 January, 200t Milne Point Unit Alaska Drilling & Wells Milne Point MPE Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9464.56 4292.09 7420.88 S 474.15 W Tie on point 9545.00 4315.66 7496.68 S 487.08 W KOP 12860.00 4203.96 10740.67 S 1113.96 W Projected survey Survey tool program for MPE.24A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 9464.56 4292.09 9464.56 4292.09 12860.00 4203.96 Survey Tool Description MWD Magnetic (MPE-24) AK-6 BP_IFR-AK (MPE-24A) 28 February, 2001 - 11:52 Page 5 of 5 DrillQuest 2.00.06 Miine Point Unit Alaska Drilling & Wells Milne Point MPE, Slot MPE24 MPE-24A MWD Surveyed: 26 January, 2001 S UR VEY REPORT 28 February, 2001 Your Ref: AP1500292286701 Surface Coordinates: 6016150.87 N, 569209.37 E (70° 27' f6.0198" N, 149° 26' 06.8436" W) Kelly Bushing: 53.70fl above Mean Sea Level QRILLINI~ SERVICES Survey Ref: svy9811 Halliburton Company Sperry, Sun Drilling Services Survey Report for MPE-24A MWD Your Ref: AP150029228670'1 Surveyed: 26 January, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) VertiCal Depth (ft) 9464.56 73.730 188.400 4238.39 4292.09 9545.00 72.200 190.970 4261.96 4315.66 9603.77 80.210 193.320 4275.97 4329.67 9653.83 89.260 195.240 4280.55 4334.25 9695.70 95.370 195.050 4278.86 4332.56 9746.44 95.730 195.060 4273.96 4327.66 9787.12 92.650 193.080 4270.98 4324.68 9841.59 92.770 192.100 4268.41 4322.11 9883.17 93.820 192.740 4266.02 4319.72 9931.81 92.710 192.410 4263.25 4316.95 9978.17 92.220 190.810 4261.26 4314.96 10032.91 93.880 192.780 4258.34 4312.04 10073.64 93.760 192.560 4255.63 4309.33 10123.47 92.770 193.740 4252.79 4306.49 10164.55 92.340 194.420 4250.96 4304.66 10216.04 91.720 194.300 4249.14 4302.84 10256.41 91.600 194.400 4247.97 4301.67 10305.62 91.050 192.730 4246.83 4300.53 10349.50 90.620 193.120 4246.19 4299.89 10392.89 90.430 192.640 4245.79 4299.49 10443.88 90.920 191.790 4245.19 4298.89 10477.40 92.040 193.000 4244.32 4298.02 10534.12 92.160 192.990 4242.25 4295.95 10581.82 91.600 191.940 4240.68 4294.38 10623.70 91.480 191.940 4239.56 4293.26 10672.72 89.570 191.080 4239.11 4292.81 10716.53 89.570 192.170 4239.44 4293.14 10769.75 90.490 193.090 4239.41 4293.11 10806.78 93.020 195.780 4238.27 4291.97 10855.91 92.900 195.560 4235.74 4289.44 Local Coordinates. Global Coordinates Northings Eastings Northings Eastings (ft) (ft) - (ft) (ft) 7420.88 S 474.15W 6008725.91N 568804.17 E 7496.68 S 487.08W 6008649.99 N 568791.94 E 7552.43 S 499.10W 6008594.13 N 568780.44 E 7600.68 S 511.39W 6008545.77 N 568768.61E 7641.04S 522.31W 6008505.30 N 568758.06 E 7689.81S 535.43W 6008456.42 N 568745.39 E 7729.16 S 545.29W 6008416.98 N 568735.90 E 7782.26 S 557.15W 6008363.77 N 568724.53 E 7822.80 S 566.08W 6008323.15 N 568715.98 E 7870.19 S 576.65W 6008275.66 N 568705.85 E 7915.56S 585.97W 6008230.21N 568696.95 E 7969.07S 597.14W 6008176.60 N 568686.28 E 8008.72S 606.06W 6008136.87 N 568677.73 E 8057.16 S 617.38W 6008088.32 N 568666.86 E 8096.97S 627.36W 6008048.43 N 568657.25 E 8146.81S 640.12W 6007998.46 N 568644.95 E 8185.91S 650.12W 6007959.28 N 568635.31E 8233.73 S 661.66W 6007911.35 N 568624.22 E 8276.50S 671.48W 6007868.49 N 568614.80 E 8318.79 S 681.15W 6007826.11N 568605.52 E 8368.62 S 691.93W 6007776.18 N 568595.20 E 8401.35 S 699.13W 6007743.39 N 568588.31E 8456.58 S 711.87W 6007688.04 N 568576.08 E 8503.13 S 722.16W 6007641.40 N 568566.22 E 8544.09 S 730.82W 6007600.36 N 568557.94 E 8592.12 S 740.60W 6007552.24 N 568548.61E 8635.03 S 749.43W 6007509.25 N 568540.18 E 8686.96S 761.07W 6007457.22 N 568529.03 E 8722.80 S 770.29W 6007421.29 N 568520.14 E 8770.04S 783.55W 6007373.93 N 568507.32 E Dogleg Rate (°/'lOOff) Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 7349.58 Tie on point 3.60 7426.40 KOP 14.17 7483.42 18.48 7533.19 14.60 7574.95 0.7t 8.99 1.81 2.96 2.38 3.61 4.70 0.61 3.09 1.96 1.23 0.39 3.57 1.32 1.19 1.92 4.92 0.21 2.49 0.29 4.27 2.49 2.44 9.97 0.51 7625.4O 7665.95 7720.36 7761.87 7810.43 7856.74 7911.39 7952.03 8001.78 8042.80 8O94.23 8134.55 8183.74 8227.61 8271.00 8321.98 8355.49 8412.17 8459.84 8501.71 8550.72 8594.52 8647.74 8684.72 8733.71 28 February, 2001 - 11:51 Page 2 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE-24A MWD Your Ref: AP1 500292286701 Surveyed: 26 January, 2001 Milne Point Unit Measured Depth Incl. Azim. Sub-Sea Depth (ft) 10899.28 92.710 195.250 4233.61 10942.55 92.770 195.290 4231.55 10988.63 92.590 194.480 4229.39 11038.03 91.110 194.580 4227.80 11080.72 90.860 195.700 4227.06 11130.37 91.290 194.670 4226.13 11172.48 91.850 192.540 4224.98 11221.86 92.520 193.020 4223.09 11264.85 93.080 192.920 4220.99 11316.78 92.960 192.810 4218.26 11355.36 93.630 192.150 4216.04 11407.59 95.550 191.880 4211.86 11448.19 94.880 191.650 4208.17 11496.02 94.000 191.280 4204.47 11536.78 93.690 189.720 4201.73 11586.13 94.070 189.150 4198.40 11624.66 92.770 189.700 4196.10 11675.10 91.720 188.460 4194.12 11721.95 91.290 188.640 4192.89 11769.38 90.370 187.670 4192.20 11815.67 91.230 186.940 4191.56 11866.61 92.340 189.060 4189.97 11910.25 93.630 188.810 4187.70 11964.13 92.840 187.280 4184.66 11994.18 91.850 188.050 4183.43 12046.87 93.320 187.090 4181.05 12095.08 92.710 187.070 4178.52 12141.92 93.080 187.060 4176.15 12189.10 92.470 186.270 4173.87 12239.46 94.190 186.830 4170.94 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Easfings (ft) (ft) (ft) (ft) (ft) 4287.31 8811.80 S 795.05W 6007332.07N 568496.20 E 4285.25 8853.49 S 806.43W 6007290.27 N 568485.21E 4283.09 . 8897.98 S 818.26W 6007245.67 N 568473.80 E 4281.50 8945.77 S 830.65W 6007197.77 N 568461.86 E 4280.76 8986.97S 841.79W 6007156.46 N 568451.09 E 4279.83 9034.88 S 854.80W 6007108.44N 568438.53 E 4278.68 9075.79S 864.70W 6007067.44N 568429.01E 4276.79 9123.91S 875.61W 6007019.22 N 568418.55 E 4274.69 9165.76S 885.25W 6006977.29 N 568409.30 E 4271.96 9216.31S 896.80W 6006926.63 N 568398.22 E 4269.74 9253.92 S 905.12W 6006888.94 N 568390.25 E 4265.56 9304.84S 915.96W 6006837.93 N 568379.88 E 4261.87 9344.42 S 924.20W 6006798.27 N 568372.01E 4258.17 9391.15 S 933.68W 6006751.45 N 568362.96 E 4255.43 9431.14 S 941.09W 6006711.40 N 568355.93 E 4252.10 9479.71S 949.16W 6006662.75 N 568348.31E 4249.80 9517.65 S 955.46W 6006624.75 N 568342.36 E 4247.82 9567.42 S 963.41W 6006574.91N 568334.87 E 4246.59 9613.73 S 970.38W 6006528.54N 568328.34 E 4245.90 9660.68 S 977.10W 6008481.53 N 568322.05 E 4245.26 9706.59 S 982.99W 6008435.57 N 568316.59 E 4243.67 9757.00S 990.07W 6006385.09 N 568309.97 E 4241.40 9800.05 S 996.84W 6006341.98 N 568303.60 E 4238.36 9853.32S 1004.37W 6006288.65 N 568296.57 E 4237.13 9883.07S 1008.38W 6006258.86 N 568292.84E 4234.75 9935.25 S 1015.31W 6006206.62 N 568286.39 E 4232.22 9983.02 S 1021.24W 6006158.79 N 568280.90 E 4229.85 10029.45 S 1027.00W 6006112.31 N 568275.58 E 4227.57 10076.25 S 1032.47W 6006065.46 N 568270.55 E 4224.84 10126.20 S 1038.20W 6006015.46N 568265.28 E Dogleg Rate (°llOOft) 0.84 0.17 1.80 3.00 2.69 2.25 5.23 1.67 1.32 0.31 2.44 3.71 1.74 1.99 3.89 1.39 3.66 3.22 0.99 2.82 2.44 4.70 3.01 3.19 4.17 3.33 1.27 0.79 2.11 3.59 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 8776.97 8820.13 8866.12 8915.46 8958.09 9007.67 9O49.76 9099.10 9142.03 9193.89 9232.41 9284.47 9324.89 9372.57 9413.22 9462.39 950O.8O 9551.11 9597.84 9645.13 9691.24 9742.00 9785.50 9839.13 9869.06 9921.50 9969.44 10016.02 10062.91 10112.92 26 February, 2001i - 1~:51 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE-24A MWD Your Ref: AP1500292286701 Surveyed: 26 January, 200f Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 12283.35 93.760 187.020 4167.90 4221.60 10169.66 S 1043.48 W 6005971.95 N 568260.40 E 12333.83 93.200 186.450 4164.83 4218.53 10219.70 S 1049.39 W 6005921.86 N 568254.96 E 12379.09 93.020 186.130 4162.38 4216.08 10264.62 S 1054.34 VV 6005876.90 N 568250.42 E 12432.14 94.010 186.860 4159.13 4212.83 10317.23 S 1060.33 W 6005824.23 N 568244.92 E 12471.13 93.080 185.190 4156.71 4210.41 10355.93 S 1064.41 W 6005785.50 N 568241.20 E 12518.45 91.230 186.380 4154.94 4208.64 10402.97 S 1069.18 W 6005738.41 N 568236.87 E 12565.07 90.250 185.390 4154.33 4208.03 10449.34 S 1073.96 W 6005692.00 N 568232.52 E 12613.15 91.600 187.450 4153.56 4207.26 10497.11 S 1079.33 W 6005644.18 N 568227.59 E 12657.99 91.170 186.610 4152.47 4206.17 10541.60 S 1084.82 W 6005599.65 N - 568222.52 E 12706.22 90.920 186.150 4151.59 4205.29 10589.53 S 1090.18 W 6005551.67 N 568217.60 E 12749.31 90.800 185.920 4150.95 4204.65 10632.37 S 1094.71W 6005508.79 N 568213.47 E 12791.09 90.250 184.760 4150.56 4204.26 10673.97 S 1098.60W 6005467.16 N 568209.97 E 12860.00 90.250 184.760 4150.26 4203.96 10742.64S 1104.32W 6005398.44 N 568204.89 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.463° (04-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 192.400° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12860.00ft., The Bottom Hole Displacement is 10799.25ft., in the Direction of 185.869° (True). Dogleg Rate (°llOOft) 1.07 1.58 0.81 2.32 4.90 4.65 2.99 5.12 2.10 1.09 0.60 3.07 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 10156.5O 10206.64 10251.58 10304.25 10342.92 10389.89 1O436.20 10484.01- 10528.64 10576.6O 10619.42 10660.88 10729.17 Projected Survey DrillQuest 2.00.06 28 February, 2001 - 11:51 . Page 4 of 5 Sperry-Sun Drilling Services Survey Report for MPE-24A MWD Your Ref: AP1500292286701 Surveyed: 26 January, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPE Comments Measured Station Coordinates Depth TVD Northings Eastings (~) (~) (~) (~) Comment 9464.56 4292.09 7420.88 S 474.15 W Tie on point 9545.00 4315.66 7496.68 S 487.08 W KOP 12860.00 4203.96 10742.64 S 1104.32 W Projected Survey Survey tool program for MPE-24A MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12860.00 4203.96 Survey Tool Description MWD Magnetic (MPE-24) 28 February, 200f - ff:5f Page 5 of 5 DrillQuest 2.00.06 ALASKA OIL AND GAS CONSERVATION CO~L~IlSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Schultz Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit MPE-24A BP Exploration (Alaska) Inc. Permit No: 200-186 Sur Loc: 3613'NSL, 1936'WEL, Sec. 25, TI3N, RIOE, UM Btmhole Loc. 1728'SNL, 2178'EWL, Sec. 06, TI2N, RllE, UM Dear Mr. Schultz: Enclosed is the approved application for permit to redrill the above referenced well. ' The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 'Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice .(approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 6'59-3607. Sincerely, J. M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this 2,8'fv~.--- day of November, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o cncl. Depamnent of Environmental. Conservation w/o end. ' ~, STATE OF ALASKA ff . ALASK,I. ;L AND GAS CONSERVATION COMIt"' ,SION PERMIT TO DRILL 20 AAC 25.005 I I'l Exploratory [] Stratigraphic Test [] Development Oil la' Type of work B Drill [] Redrill I b. Type of well Re-Entry [] Deepen Service [] Development Gas Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 29.12' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 c~z.5-~.,-/~gvAl~J_ 380110 7 It n- "' bJJ 4. Location of well at surface . Un' ,., ~roperty Name ,11. Type Bond (See 2O AAC 25.025) 3613' NSL, 1936' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3887' SNL, 2426' WEL, SEC. 36, T13N, R10E, UM (OB Target) MPE-24A Number 2S100302630-277 At total depth 9. Approximate spud date 1728' SNL, 2178' EWL, SEC. 06, T12N, R11E, UM 11/30/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 1728' MDI No Close Approach 2560 12753' MD / 4175' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9552' MD Maximum Hole Angle 93 ° Maximum surface 1067 psig, At total depth (TVD) 4000' / 1527 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin.q Weiqht Grade Couplinq Len.qth MD TVD MD TVD {include staqe data) N/A 7" 26# L-80 BTC-M 9720' 30' 30' 9750' 4375' 315 sx AS IIIr 265 sx Class 'G' 6'1/8" 4-1/2" 12.6# L-80 IBT-M 3301' 9452' 4320' 12753' 4175' Llncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 14366 feet Plugs (measured) Abandonment Plug 14366'- 13343'; EZSV set at 10009'; Abandonment Plug 10009' - 9800'; Bridge Plug set at 6910' true vertical 6563 feet Effective depth: measured 9800 feet Junk (measured) true vertical 4402 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 113' 113' Surface 10041' 9-5/8" 2823 sx PF 'E', 562 sx Class 'G' 10077' 4500' Intermediate Production Liner !~i'.'m.~ i~,.' ....... "'~' .'" ....... ~ ..... : ......... i ..... ....... , ......... ~.. ~ ,:,~:~,:: .... · . i ;!000 Perforation depth: measured None true vertical None ~1~$~'.:~ '"~,;~ ~.; ....... ,";, · . ~i; .,*,: ~,.~...~:.~.,-..~,,,:;. ,,~ :~,~.;~) :.-., ,-~ ........ ~.,~{~,~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Larry Wolfson, 564-5969 Prepared By Narne/Nurnbec Terrie Hubble, 564-4628 , (. 1. I hereby certify that the for~g~g~g is tr,u~ ~:),rrect to the best of my knowledge ~ / / Signed Steve Shultz ,.~ .~..~,,' ~.~ ~--' Title Senior Drilling Engineer Date /~//~ Permit NumberIAPl Number Approval Date See cover letter ~--/~:), ~- 50-029-22867-01 //-'~?~--~0 for other requirements Conditions of Approval: Sampt~ Required [] Yes [] No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures I~ Yes ~ No Directional Survey Required !~ Yes [] No Required Working Pressure for DOPE ~,~2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: by order of Approved By ORIGINAL, ,, , SIGNED,_..,==, BY Commissioner the commission Date Form 10-401 Rev. 12-01-85 URIGINAL Submit In Triplicate 1. Well Plan Summary Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit IWell Name: I MPE-24A & MPE-24A L1 I I Type of Well {producer or injector): I Producer (Sidetrack Multilateral) Surface Location: E-24A OB Target End: E-24A L10A Target Start: E-24A L10A Target End: 3613' FSL (1666' FNL), 1936' FEL (3342' FWL), Sec. 25, T13N, R10E X = 569209.37 Y = 6016150.87 X = 568791 Y = 6008646 Z = 4263' TVDss 3551' FSL (1728' FNL), 2579' FEL (2178' FWL), Sec. 06, T12N, R11 E X = 568140 Y = 6005520 Z = 4118' TVDss 1555' FSL (3723' FNL), 2401' FEL (2877' FWL), Sec. 36, T13N, R10E X = 568814 Y = 6008810 Z = 4215' TVDss 3551' FSL (1728' FNL), 2579' FEL (2178' FWL), Sec. 06, T12N, R11E X = 568140 Y = 6005520 Z = 4061' TVDss AFE Number: Estimated Start Date: OA MD 12744' OB MD 12753' I3372°5 I IN°v' 30'n 20001 OA TVDrkb (TD) 4118' OB TVDrkb (TD) 4175' I Ri~l: I Nabors 22E I Operatin9 days to complete: 1 25.2 OA Max. Inc. 93° OB Max. Inc. 93° I 129.12' I IWell Design (conventional, slim hole, etc.): I Sidetrack multi-lateral with extended horizontal I laterals. Electric Submersible Pump completion. Scope: MPE-24 was drilled in 1998 by Nabors Rig 27E to a depth of 14,366'. LWD logs revealed the Kuparuk Sands were water wet. The open hole section was abandoned and the well has been in operations shut-down since 04/04/98~see Section 2.2 for current mechanical condition. Drillout bridge plug at 6,910' and cleanout to PBTD. Run and cement 7" casing to 9750' to isolate casing patch. Set whipstock and mill window into top OB sand. Drill a 3200' horizontal well in OB sand. Run 4 ~' slotted liner with hanger. Set retrievable whipstock at top of OA interval at +/- 9380' MD. Mill window in 7" and 9 %" casing. Drill a 3350' horizontal well in OA. Retrieve whipstock. Run 4 Y2" slotted liner with Baker "Hook Hanger" system into upper lateral. Freeze protect well. The well will be completed with a 3 1~,, tubin~ ESP completion by Nabors 4ES. Version #2, 11113/2000 i (' Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit Current Well Information 2.1 General Well Name: MPE-24A APl Number: MPE-24A L1 APl Number: Well Type: Current Status: BHP: BHT: 2.2 Current Mechanical Surface: Abandonment Plug EZSV set at Abandonment Plug Bridge Plug 2.3 Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: 2.4 Materials Needed Production Casing: 2 x Production Liners: L-80 Completion: MPE-24A 50-029-22867-01 50-029-22867-60 Development - Schrader Bluff Sidetrack Multilateral Producer Operations Shut-Down 1800 psi @ 4000' TVDss Schrader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4020' TVDss Estimated (SOR) Condition Cellar Box above MSL = 24.3' KB / MSL = 57.1' 20", 92 Ib/ft, H-40 Welded set at 113' RKB 9 5/8", 40 Ib/ft, L-80, BTC-M set at 10,077' RKB 14,366'-13343' 10,009' 10,009'-9800' 6,910' Expected reserves 2.0 MMbbl Production rate: 1500 stb/d Production rate: 1000 stb/d 9750' I off 4O off I lot 2 off 6650' 170 off 4 %" x 5 ~" x 8" 7,, x 41/2,, 4½" I assembly 9280' 2 %" ESP 2 %" Gauge 2 %" Landing Nipple 2x2%" I off I lot 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7"x 8 1/8" Rigid SB Casing Centralizers 7" casing pups 5', 10', 20' 7" Baker Whipstock and Anchor 4 W', 12.6#, L-80, IBT-Mod Slotted Liner Rigid Straight Blade Centralizers and stop rings Baker liner top hanger with inner string Baker guide shoe, pack off bushing Baker Level 3 "Hook Hanger" Multilateral Equip. 2 %" 6.3 lb/fi, L-80, 8 round EUE tubing Centrilift Electric Submersible Pump Centrilift Pressure Gauge X Nipple Gas Lift Mandrels BIW ESP & Heat Trace Penetrators 2 %" tubing pup joints Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit 3. Drilling Hazards and Contingencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Fre~luenc~/ Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carr~ out this drill when open hole sections are exposed. 3.1.1. The 6 ~" horizontals will be drilled with the BOP installed. MPE-24A is being drilled in an undrained fault block and reservoir pressure is expected to be virgin 8.65 lb/gal equivalent. The planned mud weight is 9.1 lb/gal, which provides a 0.45 lb/gal overbalance (98 psi). 3.2. Kick tolerance 3.2.1. The kick tolerance for the 6 %" horizontal open hole section is infinite assuming an influx at the 12753' MD in the Schrader OB formation. This is a worst case scenario based on an 8.7 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12.0 lb/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. 3.2.2. The 7" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 8,000' MD. 3..3. Lost Circulation 3.3.1. Lost cimulation has not been encountered while drilling this interval on previous E-Pad wells. 3.3.2. Clean hole ECD in the 6 %" horizontal holes is estimated to be 11.7 lb/gal. Maintain minimum ECD thru use of proper hole cleaning procedures, PWD monitoring, and control drilling. 3.3.3. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Unexpected High Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no off take or injection support. Reservoir pressure is expected to be 1880 psi (8.65 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3.5. Stuck Pipe 3.5.1. The E-24A directional plan has aggressive horizontal intervals (3200' and 3350') in the OA/OB reservoirs. These hole intervals have massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. Schrader Bluff Tract 14 2000 Pro~ram MPE-24A Drillin~l Permit 3.5.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5.3. There is a risk of differentially sticking the 4 1/2" slotted liners. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.7 lb/gal OA/OB sand reservoir pressure (87 psi differential pressure @ 4175' TVD). The liner should be kept moving as much as possible while r,u~ni~g~i~ th~open...hoJ,.e. i!=' :ii i! ...... 3.6. Pad Data Sheet 3.6.1. Please Read the E-Pad Data Sheet thoroughly. 3.7. Hydrates 3.7.1. Serious gas cut mud from Hydrates on E-Pad was seen between 2100'-2200' TVDss in four of the 1994 - 1995 wells, requiring an 11.5 ppg mud weight. These wells were all located in the East South East area of the pad (we will be drilling South South West). Be alert between 2000' TVDss and 2400 TVDsj[~t.~~ 3.7.2. Shallow gas was encountered on E-7 and E-8 just under the base of the Permafrost (2296' TVDss and 2480' TVDss respectively). 3.7.3. Gas and oil cut mud was also encountered on E-3 at 3880' TVDss and 3974' TVDss. 3.7.4. Mud returns should be monitored to determine if hydrates are encountered on this well. 3.7.5. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) d) 0.6% Drill & Slide - have in mud system prior to drilling hydrates Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300-400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflect actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit 3.8. Breathing 3.8.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3.9. Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.10. Geosteering 3.10.1. Two rig site geologists are required onsite for accurate geosteering through the thin OA/OB sands 3.10.2. It is critical that we achieve a high percentage of 6 34" hole in reservoir zone drilling in the OAJOB sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. 3.11. Hydrogen Sulfide 3.11.1. MPE Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well E- Well Type H2S Status Date taken 2 Gas Inj Shut In Feb 2000 3i Gas ~nj Injector Feb 2000 4 KUP Prod <2.00 Feb 2000 5i WAG Injector Feb 2000 6 KUP Prod Shut In Apr 2000 7 WAG Shut In Feb 2000 8 KUP Prod 2.28 Feb 2000 9 KUP Prod 3.30 Feb 2000 10 Long Term Shut In Feb 2000 11 KUP Prod 2.78 Feb 2000 13 Long Term <2.00 Feb 2000 14 KUP Prod <2.00 Apr 2000 15 SBF Prod <2.00 Feb 2000 16i WAG Injector Feb 2000 17i WAG Injector Apr 2000 18 KUP Prod <2.00 Feb 2000 19 Long Term Shut In Feb 2000 20 SBF Prod <2.00 Feb 2000 21 Long Term Shut In Feb 2000 22 KUP Prod 8 Feb 2000 23i WAG Injector Feb 2000 24 Long Term Shut In Feb 2000 30 Long Term Shut In Feb 2000 33 Long Term Shut In Feb 2000 Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit 4. Drillin Pro ram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPE-24A Close Approach Wells: There are no close approach wells Well Name Current Production Precautions Status Priority N/A N/A N/A N/A 4.2. Well Control Expected BHP 527 psi @ 4000' TVD (estimated) Max Exp Surface Pressure 1067 psi (0.115 psi/ft ~las cjradient) BOPE Rating 5000 psi WP (entire stack & valves) Planned BOPE Test Pres. 2000/250 psi Rams and Valves 2000/250 psi Annular 4.3. Mud Program 6 W' Production Hole Mud Properties: OB/OA Density (ppg) I Funnel visI YP HTHP 9.1 40 - 55 22 - 27 < 10 KCL - CaCO3 Baradril N Mud ~ pH I APl Filtrate I LG Solids I 8.0 - 8.5 4 - 6 < 12 ppb NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore psi EMW (ppg) Base Permafrost .... SV1 .... Top Ugnu .... Top Ugnu M .... NA .... NB .... NC .... NE .... NF - - - Top OA 9380 4215 1897 8.65 Base OA 9475 4240 1908 8.65 Top OB 9552 4263 1918 8.65 Base OB 9620 4284 1928 8.65 Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit 4.5. Casing/Tubing Program Hole Size Csg / Wt/Ft Grade Conn Length Top Bottom Tb~l O.D. MD / TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' 113' / 113' 12 ¼" 9 %" 40# L-80 BTC-M 10047' 30' / 30' 10077' / 4445' N/A 7" 26# L-80 BTC-M 9720' 30' / 30' 9750' / 4375' 6 %" OB 4 ½" 12.6# L-80 I BT-Mod 3301' 9452' / 4320' 12753' / 4175' 6 %" OA 4 ½" 12.6# L-80 IBT-Mod 7373' 9380' / 4272' 12744' / 4118' Tubing 2 %" ESP 6.3# L-80 EUE-Mod 9250' 30' / 30' 9280' / 4290' 4.6. Cement Calculations Casing Size 1 7" 26 Ib/ft L-80 BTC-M BasisI No excess - all cement in cased hole Total Cement Volume: Wash Spacer Lead Tail Temp 50 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg 75 bbl of Viscosified Spacer (Mudpush XL Design) weighted to 10.50 ppg 315 sx 249 bbl 10.7 lb/gal Class G Arctic Set III Light 265 s_x 55__bb_l~lass G BHST = 80° F from SOR, BHCT 85° F estimated by Dowell 4.6.1. Casing Spaceout a) Space 7" casing out with pups and long/short joints as required to place the top of a long full joint at the actual top of the OA and OB sands to allow for the windows to be milled just below the top of the sands and in the middle of a full joint of casing. Run full casing joints across the OA and OB sands. Any casing pup joints required for space out should be placed below the base of the sands. b) A radioactive tag should be placed in the casing string at least 100' above the OA sands. c) Emergency 7" casing slips can be used instead of the 7" mandrel hanger if required to achieve the required space out. 4.6.2. 7" String Centralizer Placement a) Do not run centralizers on the 2 joints of 7" casing spaced across the upper OA sand. b) With the exception stated above, 8 1/8" x 7" straight blade rigid centralizers should be run floating in the middle of each joint of casing from the 7" casing shoe up to 8000' MD. 4.6.3. 4 ½" Slotted Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint with no stop collar (i.e. free floating across the whole length of the joint) for the whole string. 4.7. Survey and Logging Program Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit I 6 ~/," Hole Sections: I MWD I GR/Res ! PWD i DDS I ABI I ABGR - (ABGR will be run if available) Cased Hole:I None 4.8. Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzles Max. Hours Number and Section K-Revs I (OB lat.) 6 %" 9552'- 12753' Security FM2643 PDC 3x16 ~ ~ 2 (OA lat.) 6 %" 9380'- 12744' Security FM2643 PDC 3x16 ~ ~ 4.9. Motors and Required Doglegs Drilling Motor Size and Motor Required Flow Rate RPMs Required Doglegs BHA No. (see 5.2.1) I & 2 4 ~" Sperrydrill 4/5, 6.3 stg FTC Performance, 250 gpm 100 Maximum build = 12°/100' 1.5° or 1.15° adj with 5.8" sleeve (max.) . Schrader Bluff Tract 14 2000 Proc~lram M PE-24A Drillin~l Permit 5. MPE-24A Nabors 22E Operations Summary 5.1. Pre-Rig Operations 1. Grade and level pad 5.2. Procedure 5. \6. 7. 9. 10. 11. 12. 13. 14. 17.16. 15. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. MIRU Nabors 22E, NU & test BOP on Gen 5 wellhead. PU 3-1/2" drill pipe MU rotary BHA, MWD and 8-3/8" mill tooth bit. RIH and drill out bridge plug at 6910'. Cleanout to cement plug at + 9800'. MAD pass from PBTD to top of OA sand (+9380'). Run and cement 7" casing inside 9-5/8" casing to isolate casing patch. Bring cement to surface to eliminate the need for freeze protecting annulus. Make up rotary BHA, MWD and mill. RIH to float collar; confirm depths. MU Baker Window Master window milling BHA with bottom trip anchor and MWD. RIH. Orient and set whipstock. Mill window thru 7" and 9-5/8" casing. MU BHA with 6-1/8" PDC bit, 4-3/4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3-1/2" drill pipe. Drill 6-1/8" OB lateral from 9552' to 12753'; geosteering and short tripping as required. Maintain BARADRILn mud properties. Make a hole opener run at TD. Displace OB lateral with clean BARADRILn mud. Run 4 ½" slotted liner with 2 7/8" inner string and hang off in 7" casing. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. RIH. Orient and set whipstock. Mill window thru 7" and 9-5/8" casing. MU BHA with 6-1/8" PDC bit, 4-3/4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3-1/2" drill pipe. RIH. Displace hole to clean BARADRILn mud. Drill 6-1/8" OA lateral from 9380' to 12,744' geosteering and short tripping as required. Maintain BARADRILn mud properties. Make a hole opener run at TD. Displace OA lateral with clean BARADRILn mud. MU whipstock retrieving tool and pull whipstock. Run 4 ½" slotted liner with 2 7/8" inner string, Baker Hook Hanger and hang off in 7" casing. POOH laying down 3 ½" drill pipe. Run in hole with 2 7/8" tubing to top of OA liner. Displace 7" casing to 9.1 lb/gal completion fluid. Land tubing hanger. Set tubing plug and BPV. ND BOP. Install and test tree. Pull tubing plug and BPV. Freeze protect the tubing and annulus. Install BPV and secure the well. RD/MO. ., ,~,., ........ ',~...,:.,..~ ~.; ...... i:, '-:~.*, =~ ....... ~.,,.:,.,.- Schrader Bluff Tract 14 2000 Proc~lram MPE-24A Drillin~l Permit 6. MPE-225 Nabors 4ES Operations Summary 1. MI/RU Nabors 4ES. 2. Circulate out freeze protection with 9.1 ppg brine. 3. Remove tree and install BOP. 4. Pull and stand back the 2 7/8" tubing. 5. Make up the ESP completion and run in on the 2 7/8" tubing. Freeze protect the well. 6. Set tubing plug and BPV. Remove the BOP. Install and test the tree. 7. RD/MO. 8. Hook up flowlines and instrumentation. 10 T,.= 2~/t6'tree. MPU E-24Orig. DF. elev.=57.1'(N27E) Wellhead: Gen. 5A system. 11" csg. Orig. GL. elev.= 24.3' spool. 7 1116' X 11" SM FMC tbg. spool wi 7' mandrel hgr. and packoff. ! DF to 9 5/8" csg. hnr. = 36.3' (N 27E) 7' x 2 7/8" tbg. hgr. installed. J Diesel to 2060' 20' 9~.~ ppf, H~O I ~3' ~! "owco 9,5/8" 'ES'12~,~, md I seawater to top of BP Cementer stage collar I I I KOP ~ ~~ I Max. hole angle = 74 to 77 deg. I f/3650' to 9450' ~ 10.1 ppg ddg. fluid Hole angle through perfs. = not appl. I 15 bbl. (200') of Class 'G' 1 ,-'cement above the retainer. I Bt=. surface casing i --'-- - I L~cementing retainer, ) '~33 bbl. of Class G'cement i ~ below the retainer. Stimulation none performed Re! Io~.' Not applioable ~., '~ ~ ~'~'.' ~ ~.~.. #' [[ ~',...,~, Size 8PF Intewal (TVD) i "=~'~'~"':" ;,,, TOC = 13,343' · 51 bbl. (250 sks) Class G cement plug 8.5" hole drilled to 14,366'. Kup, Sands are wet. DATE REV, BY COMMENTS MILNE POINT UNIT 04/0~8 JBF Drilled & Temp. P&A by Nabors 27E WELL E-24 APl NO; 50-029-22867 BP EXPLORATION {Al{) TRI~E: FMC 2 9116" 5M WELLHEAD: FMC Gen 5A System 11", 5M csg.head w! 7" mandrel hanger & packoff 7 1116' x 11", 5M, tbg spool w/ 7' x 2 7!8" tubing hanger I 11 3' ! 20" 92 Ib/ft, .-40 Welded I I PROPOSED COMPLETION P E-24A & E-24A I..(". Orig KB elev (N27E) = 57.1' Cellar Box elev = 24.3' 2-718" X 1" Gas Lift Mandrel 2150' I 2133' I I 2 47'I ,, .~ ~....... ~.- .. ~ · ~..~..~ .. .,..,~,...;:, ,. ,,. ~, ,~ :;~ ....,.r .. ..... ~ .. :.:-.%.. ~ :,...,.:,~ :.,.,,._..~ .t . , ,~ '~',. ~.,,.~.',' ... ............ 7", 26#, L-80, BTC-M Casing Drift: 6.151" Casing ID: 6.276" 9 5/8" Casing Patch (30 ') 9 5/8" ES" Cementer / 2-7/8", 6.3 lb/fi, L-80, EUE-M Coupling OD: 3.5" Drift/ID' 2.347"/2.441" x 1" Gas Lift Mandrel F 9180' I 3pie 2.313" ID Electric Submersible Pump 9230' Pressure Gauge r 9280, Junction I 938°' ! Baker Hughes Hookwall Hanger IWindow in 7" & 9 5/8" casing@ Well Inclination ~ Window = 75° Baker Hughes Conventional Hanger Window in 7" & 9 5~8" casing~ Well Inclination ~ Window = 75° Bottom Trip Anchor and W~ OA Lateral TD I ' ',380'-12,744;-I Slotted Liner & Hanger OB Horizontal ~. ~.~ ~ 7" Casing Shoe @ +9750' 6-118" OB Lateral TD [ 9,552'-12 4-1/2" Slotted Liner & Hanger PBTD @ 9,800' (est) - 15 bbl "G" Howco 9 5/8" EZSV @ 10,009' 9 5/8", 40 ppg L-80 BTC-M Csg @ 10, DATE REV. BY COMMENTS 11113/2000 Larry Wolfson Level 2 Multi-Lateral, 2 7/8" ESP Completion BP Milne Point Unit WELL: E-24A ML APl NO: Exploration (Alaska) North Slope Alaska Alaska State Plane 4 MILNEPT MPE MPE-24 4200 -- I DrillQuesf 1:: o Z 0 Eastings Scale: linch = 1000ft -2000 -1000 I -7000 - -8000 - -9000 -- -10000 -- -11000 - r 8S.26 t~SO.O0~ 10620.2] $, !1~7.62 iF '702~.00 I I -2000 -1000 0 Scale: linch = 1B§l~ltence is True North Eastings -7000 -8000 -9000 '~ 1:: o Z -10000 O O II -11000 '~ I 2740.~0 9oso oo 1178o :'It 'PE-24L2 TD · I !1 11 $, 1167.62 iF I I~ I I I I 7200 7800 8400 9000 9600 10200 10800 Scale: linch = 600ff Vertical Section Section Azimuth: 186.274° (True North) Sperry-Sun Drilling Services Proposal Report for MPE-24A Wpf North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Easflngs (~t) (~t) (~t) (~) (~) 9552.00 72.131 191.089 4263.07 4320.17 7500.05 S 487.74 W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°ll00ft) 6008646.37 N 568790.87 E 9584.00 75.466 193.072 4271.99 4329.09 7530.09 S 494.17W 6008616.27 N 568784.72 E 9600.00 77.384 192.982 4275.75 4332.85 7545.24 S 497.68W 6008601.08 N 568781.35 E 9700.00 89.372 192.445 4287.26 4344.36 7641.96 S 519.49W 6008504.16 N 568760.44 E 9731.88 93.194 192.276 4286.55 4343.65 7673.09 S 526.31W 6008472.98 N 568753.91E 10000.00 93.194 192.276 4271.61 4328.71 7934.67 S 583.23W 10500.00 93.194 192.276 4243.75 4300.85 8422.48 S 689.38W 11000.00 93.194 192.276 4215.90 4273.00 8910.29 S 795.53W 11500.00 93.194 192.276 4188.05 4245.15 9398.09 S 901.68W 12000.00 93.194 192.276 4160.19 4217.29 9885.90 S 1007.83W 12500.00 93.194 192.276 4132.34 4189.44 10373.71S 1113.98W 12752.68 93.194 192.276 4118.26 4175.36 10620.23 S 1167.62W 6008210.87 N 568699.42 6007722.10 N 568597.80 6007233.33 N 568496.19 6006744.56 N 568394.58 6006255.78 N 568292.96 6005767.01N 568191.35 6005520.00 N 568140.00 12.000 12.000 12.000 12.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ff. Vertical Section is from Well and calculated along an Azimuth of 186.274° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12752.68ft., The Bottom Hole Displacement is 10684.23ft., in the Direction of 186.274° (True). Alaska State Plane 4 MILNEPT MPE Vertical Section (ft) 7508.43 7538.99 7554.44 7652.96 7684.64 E 0.000 7950.88 E 0.000 8447.37 E 0.000 8943.86 E 0.000 9440.34 E 0.000 9936.83 E 0.000 E 0.000 10433.32 10684.23 Comment ST Exit ~. 12.000°/100ft 30.000° TF: 9552.00ft ' MD, 4320.17ft TVD End Dir · 9731.88ft MD, 4343.65ft TVD Total Del~th: 12752.68fl MD 4175.36ft TVD Tar~let - MPE-24A OB TD Continued... f3 April, 2000- 9:00 - f- DrillQuest f.05.05 Sperry-Sun Drilling Services Proposal Report for MPE-24A ' Wpf North Slope Alaska Alaska State Plane 4 MILNEPT MPE Comments Measured Depth (ft) 9552.00 9731.88 12752.68 Station Coordinates TVD Nothings Eas6ngs (~) (~) (~) 4320.17 7500.05 S 487.74W 4343.65 7673.09 S 526.31W 4175.36 10620.23 S 1167.62W Comment ST Exit @ 12.000°/100ft, 30.000° TF: 9552.00ft MD, 4320.17ft TVD End Dir: 9731.88ft MD, 4343.65ft TVD Total Depth · 12752.68ft MD, 4175.36ft TVD Targets associated with this wellpath Target Name MPE-24A OB TD Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Easfings (ft) (ft) 4175.36 10620.23 $ 1167.62W 4118.26 6005520.00 N 568140.00 E 70°25'31.6771"N 149°26'41.0722"W Target Target Shape Type Point f3 April, 2000 - 9:01 - 2 - DrillQuest 1.05.05 VENDOR Al ASK~ST~T 10 DATE INVOK~E / CREDFr MEMO DESCRIPTION GROSS DISCOUNT 101200 CK101200C 100. O0 100. O0 PYNT (:OHNENTS' PERIIIT TO DRILL I'EE H/~NDL]:NG INST' S/H SONDRA X47~0 IE ATTACHED CHECK 15 114 PAYMENT FOR fTEME DESCRIBED ABOVE. ~ ~ OO_ OO 1 OO. OO =,:BP.EXPLORAT.!.O.N (ALASKA) .PAY ili::'''~: .DATE .:?ii::;ii!! .... .,. , · .':=:.~'t'::? ?' ::::? :~:..'~O~::.i.::.::!i!!~ORCUPI~ii!:D~:I'.¢~': ' ., ANCHORAGE AK 99,~O 1 I1" L ?~[lO?ll" I:0'1~ ~ PO:I, RqSI-' 00~1,1, WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~~J~f~ INIT CLASS ADMINISTRATION WELL NAME ~,7-~,~ PROGRAM: exp dev '--"~~,/ J'~/~-., GEOL AREA 1. Permit fee attached ........................ 2. Lease number appropriate.'3~. ~.e.¢.. '~:~...,;~/31',~. ~/O; ~.~./. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can-be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOLOGY A,~,/~ D,~TE I{. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horiZOns .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tahkage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~::~C::~ Dsig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S' gas probable ............ . ..... redrll v/ serv wellbore sag ann. disposal para req UNIT# ~/j ..~ ~__~ ON/OFF SHORE '~- 30. Permit can be issued wlo hydrogen sulfide measures ..... y ~'~ 31. Data presented on potential ove~mssure zones .... .... 32. Seismic analysis of shallow gas zones ............ ~t ~ / Y N 33. Seabed ~ndition sUwey (if off-shore) ......... './~-- Y N ~. Conta~ name/phone for weekly progress repo~s [~mto~ only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) Will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate, freshwate¢; or cause drilling waste... to surface;' (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N GEOLQ.GY: ENGINEERING:. ,.U_lC/Annular COMMISSION: Commentsllnstructions: 0 Z 0 Z -d -r ". c:~nsoffice\wordian~liana\checklist (rev. 11101fl00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve :the readability of the Well History file and to Simp!ify finding information, informati;3n of this '. nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Sun Nov 25 11:19:49 2001 Reel Header Service name ............. LISTPE Date ..................... 01/11/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/11/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM-10008 R. FRENCH J. PYRON MPE-24A 500292286701 B.P.Exploration (Alaska), Inc. Sperry Sun 25-NOV-01 25 13N 10E 3613 1936 .00 53.70 24.30 RECEIVED DEC 2 8 2001 Alaska Oil & Gas Cons. Comrmssior~ Anch~)rage IST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9545.0 7.000 9545.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 3 IS DIRECTIONAL ONLY. THIS RUN WAS USED TO SET THE WHIPSTOCK AND MILL AND IS NOT PRESENTED. 3. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. MPE-24A KICKS OFF FROM MPE-24 AT 9545' MD, 4316' TVD (TOP OF WHIPSTOCK). DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHNOOR OF BP EXPLORATION ALASKA, INC. DATED 9/7/01. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUN 4 REPRESENTS WELL MPE-24A WITH API % 50-029-22867-01. THIS WELL REACHED A TOTAL DEPTH OF 12860' MD, 4204' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9520.0 12807.0 RPX 9535.0 12814.0 RPS 9535.0 12814.0 RPM 9535.0 12814.0 RPD 9535.0 12814.0 FET 9535.0 12814.0 ROP 9573.0 12860.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 4 9520.0 12860.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9520 12860.5 11190.3 6682 ROP MWD FT/H 1.15 715.85 148.878 6576 GR MWD API 35.9 115.15 73.1272 6575 RPX MWD OHMM 0.15 1601.27 15.3457 6559 RPS MWD OHMM 0.26 1833.25 18.8392 6559 First Reading 9520 9573 9520 9535 9535 Last Reading 12860.5 12860.5 12807 12814 12814 RPM MWD OHMM 0.34 2000 RPD MWD OHMM 0.42 2000 FET MWD HR 0.23 5.95 24.7283 6559 26.9217 6559 0.806394 6559 9535 9535 9535 12814 12814 12814 First Reading For Entire File .......... 9520 Last Reading For Entire File ........... 12860.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9520.0 12807.0 RPX 9535.0 12814.0 RPS 9535.0 12814.0 RPM 9535.0 12814.0 RPD 9535.0 12814.0 FET 9535.0 12814.0 ROP 9573.0 12860.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 16-JAN-01 Insite 4.05.5 66.16 Memory 12860.0 MINIMUM ANGLE: MAXIMUM ANGLE: 72.2 95.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PBO1732HAGR4 PBO1732HAGR4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BARADRIL-N 9.20 52.0 8.2 26000 4.4 1.300 1.056 1.000 .900 73.0 91.4 73.0 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 Name Service Unit Min Max Mean DE?T FT 9520 12860.5 11190.3 RO? MWD040 FT/H 1.15 715.85 148.878 GR MWD040 API 35.9 115.15 73.1272 RPX MWD040 OHMM 0.15 1601.27 15.3457 RPS MWD040 OHMM 0.26 1833.25 18.8392 RPM MWD040 OHMM 0.34 2000 24.7283 RPD MWD040 OHMM 0.42 2000 26.9217 FET MWD040 HR 0.23 5.95 0.806394 First Last Nsam Reading Reading 6682 9520 12860.5 6576 9573 12860.5 6575 9520 12807 6559 9535 12814 6559 9535 12814 6559 9535 12814 6559 9535 12814 6559 9535 12814 First Reading For Entire File .......... 9520 Last Reading For Entire File ........... 12860.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/11/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/11/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
