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200-187
Imag~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. Well History File Identifier 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) [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERYL~WiNDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY Scah'ning Preparation ] x 30 = ,.-~D BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED F~LE: [] Other III IIIIIIIIIII II III DATE: S/ + z~~= TOTAL PAGES :~~,~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: __~ YES NO BY:BEV~,~,~:':t Y ROBIN) ....... VINCENT SHERYL MARIA WINDY DATE:d-/'t-~,~'/"Is/ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCRE~ERE FOUND: ~ES RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: Is~ Q u ali ty C h e c ke d 12/10/02Rev3NOTScanned.wpd • STATE OF ALASKA RECEIVED • A. ..KA OIL AND GAS CONSERVATION CO....0ISSION REPORT OF SUNDRY WELL OPERATIONS MAY 0 9 2014. 1. Operations Performed: A G C ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing IN Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change 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 200-187 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22867-60-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025518&380110 MPE-24AL1 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 12850' feet Plugs:(measured) None feet true vertical 4158' feet Junk:(measured) None feet Effective depth: measured 12850' feet Packer: (measured) 9135' feet true vertical 4158' feet Packer: (true vertical) 4204' feet Casing Length Size MD ND Burst Collapse Structural Conductor 113' 20" 113' 113' 1490 470 Surface 10041' 9-5/8" 36'-10077' 36'-4264' 5750 3090 Intermediate Production 9357' 7" 28'-9385' 28'-4271' 7240 5410 Liner 3399' 4-1/2" 9376'- 12775' 4268'-4159' 8430 7500 Perforation Depth: Measured Depth: Slotted Liner:9447'- 12731' feet True Vertical Depth: Slotted Liner:4283'-4161' 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: ❑Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 Daily Report of Well Operations 16. Well Status after work: 0 Oil 0 Gas 0 WDSPL 0 Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: J.E.B.Bolen,564-5110 N/A Email:J.E.B.Bolen@bp.com Printed Name: Joe Lastu Title: Drilling Technologist Signature: ne: 564-4091 Date: 5/611)1) 4 Form 10-404 Revised 10/2012 Submit Original Only V L 5-/z e / #1.9* RBEMS MAY 14 2(11 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 X4-0102J-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) 4/10/2014 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. -NOTIFY MPE PAD OPERATOR. -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 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 DECOM,P, PJSM.R/U CIRCULATING EQUIPMENT. r 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 VNTH BP WTL,BP SUPERINTENDENT,DOYON SUPERINTENDENT AND RIG CREW. 18:00 - 18:00 2.00 WHSUR' P DECOMP R/D HARD LINE AND STEAM IN CELLAR DUE TO ICE PLUG. -RN 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 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) 20:30 - 00:00 3.50 WHSUR P DECOMP PJSM.WELL KILL. -REVIEW DOYON WELL KILL S.O.P. -DISCUSSED INDIVIDUAL ROLES AND RESPONSIBILITIES WITH CREW. WSL AND TOOL PUSHER PRESENT FOR OPERATION. REVIEWED PRESSURE CROSSCHECK I 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 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. 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) 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 1 Hrs Task Code 1 NPT NPT Depth I 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 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. 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) '10:30 - 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 -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. -PULLTWC. -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 Task Code NPT NPT Depth Phase 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. L/D 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 WINDWALLTO SPOOLING UNIT. -CONTINUOUS HOLE FILL AT 20 BPH. 1-COMMUNICATION BETWEEN DRILLER AND SPOOLER OPERATOR AT ALL TIMES. -CENTRILIFT REPRESENTATIVE REMOVE AND RECORD ALL CLAMPS RECOVERED. POH FROM 9,180'MD TO SURFACE. L/D 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. 03:00 - 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 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 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. I-BLEED PRESSURE,7.0 BBLS BLED OFF. 17:30 - 19:30 2.00 DHB P INTERV PJSM.SET 7"HES RTT§. -POH AND STAND BACK 5 STANDS OF 4" 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. I-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 PJSM.NIPPLE UP 13-5/8"BOPE. -P/U RUNNING TOOL. -SET TEST PLUG. 1-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 I 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 IPJSM.POOH UD 2-7/8"TUBING TO PIPE SHED. -CHANGE OUT EQUIPMENT FOR 2-7/8" TUBING. -POOH FROM 4,886'MD TO 93'MD. -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. • 02:00 OUTER ANNULUS PRESSURE=0 PSI. 4/15/2014 100:00 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 I 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 Firs 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,R/U 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 MAINTAIN 100 PSI 03:00 - 06:00 3.00 RUNCOM P RUNCMP TEST TUBING AND SET PACKWR -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/WTLAPPROVAL 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 RN CIRCULATING LINES FOR FREEZE PROTECT -BEGIN PREP RIG FOR MOVE 15:30 - 18:30 3.00 WHSUR P RUNCMP PJSM,RN LITTLE RED AND TEST LINES -PUMP 85 BBLS DIESEL FREEZE PROTECT TO IA,TAKE RETURNS OUT TUBING -1.5 BPM=740 PSI 18:30 - 19:30 1.00 WHSUR P RUNCMP ALLOW DIESEL TO U-TUBE IN WELL 19:30 - 21:00 1.50 WHSUR P 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 -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 KB elev.=57.1'(N-27E) Wellhead Gen 5a system.11"csg 4 1/2"CIW BPV Profile MPE-24a/ 'tV,I 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 W 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 Degree W/DCK-2 Shear Valve 2,499' 3,300'-9400' Hole angle through perfs=90° sf I-Wire with clamp every Collar WI '"' 3 4.5"SLB PXP NDPG-C Multidrop 4 � a .044 Discharge Gauge(3.864"ID) 9,044' IW `" j i t J 4.5"HES L-80"XD"Dura sliding sleeve 1 `,, i Hyd 521 BxP(I-Wire) (3.813"ID) 9,057' ';ii__ l Ic 4.5"SLB NDPG-C Single Drop Intake g 069' y t --� Gauge(Vamtop PxP) (3.864 ID) f r 7 5/8"x 4.5"HES TNT L-80 Packer. 9,135 I, I 4.5"HES X Nipple(3.813"ID) 9,211' 4.5"12.6#13 CR-85 VamTop TubingII (drift id=3.958"cap=.0152bpf) MN WLEG w/TC-II and 5.00 OD. 9,267' 7"26 ppf,L-80,Btrcproduction casingRA tag at 9256' x (drift ID=6.151",cap=0.0383 bpf) "OA"window from 9385'-9397' (cap w/tbg=.02758) Above "OB"window from 9545'-9557' Baker 7"Hook ._ .� _ a Below 9397' NI 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') — 111 4.5"12.6#,L-80 IBT tubing. 7"26ppf,L-80 mod BTC shoe 9772 9428' 12860' Baker Float shoe at' 15 bbls(200')of class G cement above retainer 9-5/8"Howco EZSV 10009' g - < 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) . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 25, 2006 RE: MWD Formation Evaluation Logs: MPE-24A L1, AK-MW-10008 MPE-24A Ll: Digital Log Images 50-029-22867 -60 1 CD Rom PLEASE ACKi"lOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnica1 Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ("'} J. " ~ 'ate: C'~ fj '1006 ::.J J - Signed: (ì ~¿t\. ,___ '-""',,- SCANNE.D AUG 3 1 20G5 r9lJO ~ I~'?- ~ 14° ¡J'-I F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATION$uG 1 62004 ~ ~ 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage. Alaska 99519-6612 7. KB Elevation (ft): KBE = 53.70' ØI Repair Well 0 Plug Perforations 0 Stimulate ØI Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: ØI Development 0 Exploratory 0 Stratigraphic 0 Service n 200-187 6. API Number: 50-029-22867-60-00 9. Well Name and Number: MPE-24AL 1 8. Property Designation: 10. Field / Pool(s): ADL 380110 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 12850 feet true vertical 4158 feet Plugs (measured) None Effective depth: measured 12850 feet Junk (measured) None true vertical 4158 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 113' 20" 113' 113' 1490 470 Surface 10041' 9-5/8" 10077' 4264' 5750 3090 Intermediate Production 9357' 7" 9385' 4271' 7240 5410 Liner 3399' 4-1/2" 9376' - 12775' 4268' - 4159' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Slotted Liner 9447' - 12731' Slotted Liner 4283' - 4161' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8" 6.5#, L-80 9180' None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~BFl AUG 1 7 !;Wifí~~. Oil-Bbl Re resentative Dail Gas-Met Water-Bbl Tubin Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run ØI Daily Report of Well Operations ØI Well Schematic Diagram 17. 15. Well Class after proposed work: 0 Exploratory ØI Development 0 Service 16. Well Status after proposed work: ØI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL st 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: Printed Name Sondra Stewman Title Technical Assistant DateO<i$'-\ Y. Prepared By Name/Number: Sondra Stewman, 564-4750 Submit Original Only ,--, "', elev. = 57.1' (N-27E) GL elev. = 24.3' (N-27E) ~ 2-7/8"" Cameron ~: Gen Sa system. 11" O$g spool, 7-1/16"x 11" 5M FMC Ibg. spool wl7"mandrel hgr & packoff 7"x 27/8"1bg hgr.installed. 20" 91.1 ppf, H-40 @] 9-518" Howco ES emt stage collar. ~ KOP@4oo' Wellbore Angle: 70" to 76° 3,300' - 9400' Hole angle through perts = 90" 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 (driftID=6.151",cap=0.0383bpf) (cap w/lbg = .02758) RA tag at 9256' Above I 9375' Below I 9397' 4-112" 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' 1 33 bbls of class G cement below retainer 9-518" 40ppf, L-80 mod. shoe. 110077' I Top of cement= 13343' 51 bbls of class G cement 8.5" hole drilled to 14366'. Kuparuk sand wet. DATE REV. BY 04/04198 JBF 02102101 M. Linder 02/15101 MOO 07/24104 Lee Hume COMMENTS Drilling & Tem" P&A Nabors 27-E MILNE POINT UNIT WELL MPE.24a API NO: 50-029-22867-00 MPE-24a\LI Camco 2-7/8" x1" KBMM Gas lift mandrel 133' Camco 2-7/8" x1" KBMM Gas lift mandrel I 2513' Cameo 2-7/8" x1" KBMM Gas lift mandrel I 8959' HES XN-Nipple (2.205" id) I 9101' Tandem Pump, 26 stg. FC1800 134 BIg. FCI800 , 16 BIg. GPMTAR I GPMTAR 1:1 I 9117' I Tandem Intake - Gao Separator Model - GRSFTXAR Tandem Seal Seclion, Model- GSB3 DB UTIl T IL H6 PFS AFLAS 1 HSN I 9146' I I 9151' I Motor, 190 KMH 2415 volt 1 48 amp, I 9165' PumpMate w/6 fin cenlralizer I 9175' "OA" window from 9385'-9397' "OB" 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 . 112860' I Horizontal multi-lateral sidetrack into Schrader 22 E ESP ~tion ESP Changeout Nabors 4ES BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/23/2004 7/24/2004 7/25/2004 ~ ~ Page 1 of 2 BPEXPLORA TION Operations Summary Report MPE-24 MPE-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours 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 Task Code NPT Phase 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 DECOMP P 4.50 PULL 2.50 PULL DECOMP DECOMP P P 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 RUNCor P 3.00 RUNCor P CLEAN CLEAN RUNCMP RUNCMP 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....looks like from the annular preventor. PJSM. PT flange & kill line 350/3500 psi, OK. PJSM. Pull 2 way check. UD lubricator & extension. PJSM. MlU landing jt. BOLDs. Pull hanger to floor. 55-60K up wt, drag to 75K max. PJSM. Circulate & fill hole, (60) bbls to fill. Continue circulating seeing oil in retums. 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 1 112" 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'. MlU circulating head, fill hole. Reverse circulate & Clean out well bore to 9560'. Con't to reverse circulate & clean out wellbore 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 31/2" DP. POOH & stand back 2 7/8" tbg. PJSM. Prep to run 27/8" 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: Date 7/25/2004 7/26/2004 ~ ~ Page 2 of 2 BP EXPLORATION Operations Summary Report MPE-24 MPE-24 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 12:30 - 17:30 From - To Hours Task Code NPT RUNCMP 17:30 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:00 03:00 - 06:00 Phase 5.00 RUNCorfp 2.00 RUNCorfp 1,00 RUNCorff' 0,50 RUNCorfp 2.00 RUNCorfp 0.50 RUNCorfp 0.50 BOPSUF P 0.50 BOPSUF P 1,00 WHSUR P 1.50 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 3.00 RIGD POST P 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 2001870 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. MILNE PT UNIT SB E-24ALI Operator BP EXPLORATION (ALASKA) INC MD 12850 ,,' TVD 4158 v''/ Completion Dat 2/13/2001 -'/ Completion Statu 1-OIL Current Status 1-OIL UIC N -_ REQUIRED INFORMATION Mud Log N._Qo Sample No Directional Survey N_go APl No. 50-029-22867-60-00 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt ! ED D Ver LIS Verification Well Co,~p.~/Sample.~ Information: (data taken from Logs Portion of Master Well Data Maint) Interval Log Log 'Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments 1 9361 12795 Open 12/28/2001 10502 Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y N~ Chips Received? Analysis Receive. d? Daily History Received? (~ I N Formation Tops (~)f N Comments: Compliance Reviewed By: To: WELL LOG TRANSMITTAL 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 L 1, AK-MM- 10008 1 LIS formatted Disc with verification listing. API#: 50-029-22867-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: J'ma Galvin ' 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-I 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~,...$1ON 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. 200-187 3. Address =8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-50-029-22867-60 4. Location of well at surface ~---r--: .............. 9. Unit or Lease Name ~ ~, ~-~',;." ;"',,r,- ' 3613' NSL, 1936' WEL, SEC. 25, T13N, R10E, UM ; ":.,,..,~.;i'~''' !. Milne Point Unit At top of productive interval 3726' SNL, 2401' WEE, SEC. 36, T13N, R10E, UM (OA Target) At total depth ~ W?;,~[:~:,- ~ 10. Well Number __,~_~;~' i/_.) MPE-24AL1 1860' SNL, 2465' WEL, SEC. 06, T12N, R11E, UM ~' .__~ ..................... ," 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 53.70' ADL 380110 12. Date Spudded1/22/2001 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'1/20/2001 2/13/2001 115' water depth' if °ffsh°reN/A MSL 110' "°' °f c°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set121. Thickness of Permafrost 12850 4158 ETI 12850 4158 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, ABI 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 113' 24" 260 sx ATtic Set (Approx.) 9-5/8" 40# L-80 36' 10077' 12-1/4" 2823 sx PF 'E', 562 sx Class 'G' 7" 26# L-80 28' 9385' 12-1/4' 335 sx AS II1~ 245 sx Class 'G' 4-1/2" 12.6# L-80 9376' 12775' 6-1/8" Uncemented Slotted Liner 24. Perforations pp. en tq Production (M,D+.TVD of Top and 25. TUS~NG RECORD Bottom and ~merva~, size and numDer) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5~, L-80 9195' MD TVD MD TVD ' 9447'- 12731' 4283'-4161' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 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-BSL GAS'MCF WATER-BEE CHOKE SIZE I GAS'OIL RATIO 2/20/2001 6 TEST PERIOD 2189 338 390I 155 Flow Tubing Casing Pressure CALCULATED OIL-aBE GAS-MCF WATER-aBE OIL GRAWTY-API (CORE) !Press. 24-HOUR RATE 28. CORE DATA Brief description of iithology, Porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAR 2, i ZOO1 Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. NA 8882' 4136' NB 8978 4161' NC 9065' 4185' NE 9164' 4212' NF 9286' 4245' OA 9380' 4269' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys submitted by Vendor 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~ ~ .Ti!le TechnicaI,As,sistant , . , Date MPE-24AL1 200-187 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one intewal (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. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate'none'. R~CE~V~D 2001 Form 10-407 Rev. 07-01-80 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION Page 1 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: 2/112001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 111/2001 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 113/2001 00:00 - 00:00 24.00: MOB PRE Spot and level sub on well. Spot mud pits, pipe shed and motor complexes. Spot cuttings tank and build berm around it. Move camp, 3arts house, shop and generator from J pad to E pad.. Start thrawing out and hooking up water, air and hydraulic lines. 114/2001 00:00 - 04:00 4.00 MOB PRE Change out suction 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 ica 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. Accept rig at 0700 hrs. 12:00 - 18:00 6.00 BOPSUI: INT1 :Install 11" x 11" drilling spool with double valves. Nlu bops. 18:00 - 21:00 3.00 WHSUR PROD1 Fabricate flowline, choke line and fill up line. 21:00 - 22:00 1.00 BOPSUI~ PROD1 PJSM. MIU test jt and install test plug. 22:00 - 23:00 1.00 BOPSUI~ 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 5110 minutes. Test annular 250~ 2000 psi for 5 and 10 minutes. Chuck Scheve with ^OGCC waived witnessing test. 115/2001 00:00 - 06:30 6.50 BOPSUI~ PROD1 Finish testing bops. Chuck Scheeve waived witnessing test. 06:30 - 10:00 3.50 s'rWHIP PROD1 Trip in hole picking up and drifting 3-112" drill pipe to 2200'. 10:00 - 11:30 1.50 STWHIP PROD1 Displaca freeze protect diesel from annulus and drill pipe with seawater. Circulate until seawater back to surface. 11:30 - 19:30 8.00 STWHIP 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 STWHIP PROD1 Circulate capacity of drill pipe. 20:00 - 22:30 2.50 STWHIP PROD1 Pooh and stand back drill pipe. 22:30 - 23:00 0.50 STWHIP PROD1 Servica top drive. 23:00 - 00:00 1.00 STWHIP PROD1 Trip in hole picking up 3-1/2 drill pipe. 116/2001 00:00 - 09:00 9.00 STWHIP PROD1 Finish tripping in hole picking up and drifting 3-1/2" drill pipe 09:00 - 09:30 0.50 STWHIP PROD1 Circulate capacity of drill pipe. 09:30 - 12:00 2.50 STWHIP PROD1 Pooh standing drill pipe back in derrick. 137 stands drill pipe in derrick 12:00 - 13:00 1.00 STWHIP PROD1 Clean rig floor. 13:00 - 16:00 3.00 STWHIP PROD1 P/u, strap and m/u bha. Test MWD. 16:00 - 17:00 1.00 STWHIP PROD1 Clean up seawater spill and had a meeting with hands discussing how to prevent this in the future. 17:00 - 17:30 0.50 STWHIP PROD1 Servica top drive. 17:30 - 21:30 4.00 STWHIP PROD1 Continue tih to top of plug. Fill drill pipe and lost all pressure on top drive. 21:30 - 00:00 2.50 STWHIP TDRV PROD1 Waiting on parts to repair top drive. Lost electrical motor on lube pump. 1/7/2001 00:00 - 07:00 7.00 STWHIP TDRV PROD1 Replaca electrical motor on lube pump on the top drive 07:00 - 08:30 1.50 STWHIP PROD1 Drill bridge plug 08:30 - 09:30 1.00 STWHIP PROD1 Circulate bottoms up-no gas. 09:30 - 12:00 2.50 STWHIP PROD1 Continue tih to 9515. Started taking weight. 12:00 - 15:00 3.00 STVVHIP PROD1 Wash and drill through cement stringers 9525'-9789°. 15:00 - 17:00 2.00 STVVHIP PROD1 Pump sweep and displaca well with seawater. 17:00 - 17:30 0.50 STWHIP PROD1 Pooh to 9055' 17:30 - 22:00 4.50 STWHIP PROD1 Make a mad pass tie-in log from 9055'-9789'. 22:00 - 00:00 2.00 STWHIP WTHR PROD1 Phase III weather conditions. WOW. 1/812001 00:00 - 00:00 24.00 STWHIP WTHR PROD1 Phase III conditions. WOW. Change suction valves in pit #7, install snubbing post, and weather proof rig while waiting on weather. At 1800 hre Milne Pt went back to Phase II, but Prudhoe Bay and Kuparuk were Printed: 2r26/2001 3:08:06 PM BP EXPLORATION Page 2 of 7 Operations Summa Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/1412001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 2/112001 Group: RIG Rig Name: N^BORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 1/812001 00'.00 - 00:00 24.00 S'rWHIP WTHR PROD1 still Phase III. Remove snow so rig is accessible for water and diesel trucks. Prepare to Pooh. 11912001 00:00 - 04:30 4.50 STVVHIP WTHR PROD1 Pooh recording pu, so, and rotating wt every 10 stands. 04:30 - 05:30 1.00 STWHIP PROD1 L/D 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 ~vith 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. ClP ~. 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~ 1111/2001 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 WEXlT Make up for bha for dummy/tie-in run for setting whipstock and MWD. Test MVVD. 04:30 - 08:00 3.50 STWHIP WEXlT 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 WEXlT Mad pass from 9701-9200 to confirm depths of sands and RA tag. RA tag was 13' deeper. 12:00 - 13:00 1.00 STVVHIP WEXlT Pooh 15 stands to 8300'. Air line to crown-a-matic froze. 13:00 - 17:30 4.50 STWHIP DRAW WEXlT Repair air line to crown-a-matic 17:30 - 23:00 5.50 STWHIP WEXlT Finish trip out, drill pipe strap was same as pipe tally 7" float collar ~ 9700 23:00 - 00:00 1.00 STWHIP WEXlT Test csg to 3500~ for 30 min. 1112/2001 00:00 - 07:30 7.50 STWHIP WEXlT Finish tih with whipstock. Tag float collar at 9700'. 07:30 - 08:00 0.50 STWHIP WEXlT 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 WEXlT ~ Pump sweep and displace well with 9.1 Baradril mud. 09:00 - 18:00 9.00 STWHIP WEXlT '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 WEXlT Pump sweep 19:30 - 22:00 2.50 STWHIP WEXlT Trip out, mill full gauge. 6.151 22:00 - 00:00 2.00: STWHIP WEXlT Lay down BI-IA 1113/2001 00:00 - 03:00 3.00 STWHIP WEXlT Finsh laying down bha and clear rig floor. Printed: 2/26/2001 3:08:06PM BP EXPLORATION Page 3 of 7 Operations Summary 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: 211/2001 Contractor Name: N^BORS Rig Release: 2/112001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Date From-To Hours Task Code Phase Description of Operations 1113/2001 03:00 - 03:30 0.50 STWHIP WEXlT Rig up and flush out bop stack. 03:30 - 04:30 1.00 BOPSUI: PROD1 Pull wear ring and install test plug. 04:30 - 11:00 6.50 BOPSUF PROD1 Test bops. Annular 250~ 2000 psi 5 mini 10 min. All rams and valves 250/3500 psi 5 mini 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 cuffing drlg line 23:30 - 00:00 0.50 DRILL PROD1 Orient tools and run tru window 1114/2001 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 415000~ 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 wi 415000~ wt. 70 rpm, 2300~ with 230 gals, change out mud while drilling 1115/2001 00:00 - 01:30 1.50 DRILL PROD1 Drilling directional from11,153- 11,200 wi 415000~ 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 11,200-12354wl 415000~ wt. 70 rpm, 2300~ with 230 gals, sliding hrs 6, rot. hrs 8 1116/2001 00:00 - 07:30 7.50 DRILL PROD1 Drilling directional from 12354-12860 TD well wi 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 slo rt/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 BI-IA taking p/u and s/o rt/weights every 10 sds. 1117/2001 00:00 - 01:30 1.50' DRILL PROD1 Finish laying out BI-IA 01:30 - 06:00 4.50 DRILL PROD1 Pick up Bha, 6 118 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, puffing 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. 111812001 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 BI-IA 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 jt. 12.6~ L80 IBT - Install one Printed: 2/'26/2001 3:08:06 PM BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 1/1412001 Event Name: RE ENTER Start: 1/14/2001 End: 2/1/2001 :Contractor Name: NABORS Rig Release: 2/112001. Group: RIG Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Task Sub Code Phase Description of Operations 1111812001 09:00 - 14:00 5.00 CASE PROD1 floating 4 518 X 5 314 Centralizers per JT., total 3,432 ft. - Torque 4000 fi/lb 14:00 - 15:00 1.00 CASE PROD1 PJSM, Rig up false rotary table - Change out handling tool to 2 718 15:00 - 20:30 5.50 CASE . PROD1 Pick up 107 jts of 2 718 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 1/2" drill pipe - Takeg plu and s/o weights every 10 sds. - +1- 5000' at 00:00 hrs 1119/2001 100:00 - 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 1/2" slotted liner - take plu & slo 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 7116" 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 STVVHIP WEXlT Picking up BI-IA f/~ 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 STWHIP WEXlT Picking up BI-IA #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 WEXlT Tripping in hole with seal ass. 08:30 - 10:30 2.00 STWHIP WEXlT Logging with MWD tool from 9074-9437 tag bottom tie back sleeve ~ 9437 top OA sand 9385 10:30 - 13:00 2.50 STVVHIP WEXlT PJSM, Cut 90 ft. ddg line 13:00 - 19:30 6.50 STWHIP WEXlT Tripping out with seal ass. and lay down seal ass. 19:30 - 20:00 0.50 STWHIP WEXlT PJSM, Pull wear ring and run test plug to test bops 20:00 - 00:00 4.00 STWHIP WEXlT Testing BOPS and manifold 250-2000# BOP test was wavied by Jerry Jones 112112001 00:00 - 03:30 3.50 STVVHIP WEXlT PJSM, Testing BOPS and manifold 250-2000# BOP test was wavied by Jerry Jones 03:30 - 04:30 1.00 STWHIP WEXlT PJSM, Remove and move and replace kelly hose and test to 4000# 04:30 - 05:30 1.00 STVVHIP WEXlT PJSM, Blow down choke manifold and top drive, mud lines 05:30 - 06:00 0.50 STVVHIP WEXlT PJSM, pull test plug and run wear ring 06:00 - 07:00 1.00 STWHIP FLOR WEXlT Repair Hyd. pump 07:00 - 09:30 2.50 STWHIP WEXlT PJSM, Pick up whipstock and orient Baker window master whipstock and BI-IA # 7 starting mill, lower stdng mill, upper string mill, 1 HWDP, float sub, mwd , bumper sub, 9 dc., 18 HWDP 09:30 - 15:30 6.00 STWHIP WEXlT PJSM, Trip in hole with whipstock, fill every 25 sds. 15:30 - 16:00 0.50 s'rWHIP WEXlT Orient whip stock to 2 degees right of high side-set whipstock anchor wi Printed: 2/26/2001 3:08:~6 PM BP EXPLORATION Page 5 of 7 Operations Summa Report Legal Well Name: MPE-24 Common Well Name: MPE-24A Spud Date: 111412001 Event Name: RE ENTER Start: 1114/2001 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 1/2112001 15:30 - 16:00 0.50 STVVHIP iWF_.~T 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 WEXlT'XJ Milling window with 230 gals., 1550 psi, 60 rpms, 3000 # torque, 2-3,000 wt. top off window-9385 bottom window-9397 m/il depth- 9414 23:30 - 00:00 0.50 STWHIP WEXIT Pump high vis sweeps and working mills tru window 1/22/2001 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 STWHIP WEXIT wash BOPS with bop washer 06:30 - 11:30 5.00 DRILL PROD1 Pick up new Bha f/~-RR Bit, 43/4 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 IRig repair- repair draw works 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 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 IdWD. 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 4656'. 19:00 - 21:00 2.00 DRILL LMWD PROD2 Attempt to get good signal from MWD. No success. 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, no 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 wi 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 fl 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. 1/2512001 00:00 - 02:30 2.50 DRILL PROD2 Drilling fl 11200' to 11345' in OA sand. Art- 1.25 hrs, Ast- .25 hrs. 235 gpm, 2100/2200 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 EXPLORATION Page 6 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: 1114/2001 End: 2/1/2001 Contractor Name: NABORS Rig Release: 21112001 Group: RIG Rig Name: NABORS 22E Rig Number: 22E Sub Phase Description of Operations Date From-To Hours Task Code 112512001 14:00-15:00 1.00 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 hrs, Ast- 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 wi 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 BI-IA 01:00 - 02:00 1.00 DRILL PROD2 PJSM, PU 6 118" porcupine holeopener BHA wi 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 problems, 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 fl 9312' to 6000' 22:30 - 00:00 1.50 DRILL PROD2 POOH 1/2812001 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 i Confinue 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. 1/2912001 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 its solid for 3367.24' - Torque 3800 fi/lb 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 fi/lbs - 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 9,365' 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 plu 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 1/2912001 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 112 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 7116" 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, reck 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 3 112" tools 02:00 - 02:30 0.50 RUNCOI~ COMP TIH wi 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 psi, then 2000psi. 09:00 - 14:30 5.50 RUNCOI~! COMP PU Baker 7" Retrivable Bridge Plug and TIH on 3 112" drillpipe to 9300' 14:30 - 15:00 0.50 RUNCOI~! COMP Drop ball, pump down and set RBP wi 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~I 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 wate~r 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~I COMP ND BOP, flowline and choke hose. Remove DS^ 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~ COMP MU retrievable bridge plug retrieving tool and TIH picking up 2 718" tubing to 9187' 19:30 - 21:00 1.50 RUNCOI~ ~ 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 RUNCOI~ ~ COMP Pull master bushing and clean drip pan and steam tables prior to ND BOP 22:30 - 00:00 1.50 RUNCOI~ ~ COMP ND BOP, flowline and choke hose 2/112001 00:00 - 02:00 2.00 RUNCOI~I 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 RUNCOI~! COMP Pull TWC and pump 80 bbls diesel down annulus to freeze protect annulus and tubing. 04:30 - 06:00 1.50' RUNCO~ COMP Let annulus and tubing u-tube and equalize. O psi. Secure well. Release rig at 0600 hrs. ,, 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 3 112 jaws and guides in top drive 02:30 - 06:00 3.50 RIGU COMP Pick up 60 jts of 5 in pipe in mouse hole and stand in derrick to use as belly board for 2 718 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 NId tree and nipple up adaptor flange 08:00 - 10:30 2.50 BOPSUF BARR COMP Repair bridge crane 10:30 - 19:30 9.00 BOPSUF COMP Nipple up BOPS and change upper and lower rams to 2 718 19:30 - 22:00 2.50 BOPSUF COMP Pick up test it. and Tiw valve and dart valve 22:00 - 22:30 0.50 BOPSUF 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 BOPSUF BARR COMP Change out top rams 02:00 - 10:00 8.00 BOPSUF COMP Testing BOPS 250#--2000~ test waiver By John Spalding 10:00 - 11:00 1.00 BOPSUF; i 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 2 718 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 2/11/2001 00:00 - 02:00 2.00 PULL COMP Laying down 25 jts. 2 7/8 tubing 02:00 - 21:00 19.00 RUNCOI~ ~'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 RUNCOI~ COMP PJSM and rig up spooling unit and rig floor 23:00 - 00:00 1.00 RUNCOI~ ~ COMP PJSM, picking up ESP motor 2/1212001 =00:00 - 04:00 4.00 RUNCOI~ ~ COMP Picking up ESP motor 04:00 - 19:30 15.50 RUNCOI~ ~ COMP Picking up 2 718 L-80 6.5~ tubing and GLMs and running ESP motor, flush tubing ~ 5000 ft. and 9100 w/500 pump pressure ~ 1.5 bbls per min., installing clamps ever 60 ft. total its run 286, total clamps used Lacalle 148, pump protectors 8, fiat protectors 3, ESP motor set ~ 9194.55, X-nipple {~ 9111.29, GLM~I~ 8969.15, GLM #2 ~} 2522.68, GLM #3 ~ 138.38 19:30 - 21:30 2.00 RUNCO~ COMP Splice ESP cable to penetrator and test phase to phase 3.6 ohms phase to ground 2000 meg. hy. press bottom 1992 psi bottom hole temp. 78 21:30 - 22:30 1.00 RUNCOr COMP Land tubing, lay down land jt. test 2 way check to 1000 # 22:30 - 00:00 1.50 BOPSUF COMP Nipple down BOPS 2/1312001 00:00 - 02:00 2.00 BOPSUF COMP Nipple down bops 02:00 - 04:00 2.00 WHSUR COMP Nipple up tree and test to 5000~ 04:00 - 05:00 1.00 WHSURI 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 13-Feb-O 1 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPE-24AL1 MWD Dear Dear Sir/Madam' /~' 7 Enclosed are two survey hard Copies and I disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,369.02' MD 9,385.00' MD 12,850.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager RECEIVED Attachment(s) Nas~ O. il & Gas Cons. Milne Point Unit Alaska Drilling & Wells Milne Point MPE, Slot MPE24 MPE-24A L ~ MWD Surveyed: 26 January, 2001 S UR VEY REPORT 28 February, 2001 ' Your Ref: AP1500292286760 Surface Coordinates: 6016150.87 N, 569209.37 E (70' 27' ~6.0198" N, Kelly Bushing: 53.70ft above Mean Sea Level 149° 26' 06.8436" Vll) nRILLING SI~FIVlC~S Survey Ref: svy9813 A Hal#burton Company Sperry-Sun Drilling Services Survey Report for MPE-24AL1 MWD Your Reft AP1500292286760 Surveyed: 26 January, 200f Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 9369.02 75.240 187.000 4212.84 4266.54 9385.00 74.980 187.230 4216.94 4270.64 9466.98 85.310 189.880 4230.96 4284.66 9508.71 89.940 191.190 4232.69 4286.39 9559.78 92.150 191.070 4231.76 4285.46 9605.61 92.460 190.050 4229.91 4283.61 9655.84 92.340 189.070 4227.81 4281.51 9696.86 92.270 190.070 4226.16 4279.86 9748.47 91.850 189.640 4224.30 4278.00 9788.09 92.710 188.330 4222.73 4276.43 9839.57 92.280 188.290 4220.49 4274.19 9884.91 92.030 190.420 4218.78 4272.48 9933.40 92.400 190.180 4216.91 4270.61 9979.08 93.210 190.080 4214.67 4268.37 10027.83 92.520 190.400 4212.23 4265.93 10070.77 92.710 190.450 4210.28 4263.98 10115.94 92.530 190.570 4208.21 4261.91 10163.20 91.470 191.330 4206.56 4260.26 10205.95 91.480 188.300 4205.46 4259.16 10255.93 90.120 189.990 4204.76 4258.46 10306.94 89.820 187.600 4204.79 4258.49 10343.08 89.880 187.320 4204.88 4258.58 10400.55 93.330 190.860 4203.27 4256.97 10440.08 91.970 191.220 4201.45 4255.15 10492.33 91.840 190.380 4199.71 4253.41 10532.23 91.420 191.290 4198.57 4252.27 10589.75 92.210 189.570 4196.75 4250.45 10620.86 92.220 188.040 4195.55 4249.25 10675.67 92.150 189.610 4193.46 4247.16 10714.59 92.150 189.210 4192.00 4245.70 Global Coordinates Northings Eastings (ft) (ft) 7329.65 S 461.82W 6008817.24 N 568815.65 E 7344.98 S 463.74W 6008801.90 N 568813.88 E 7424.73 S 475.76W 6008722.04 N 568802.59 E 7465.71S 483.39W 6008680.99 N 568795.35 E 7515.81S 493.24W 6008630.81N 568785.96 E 7560.82 S 501.63W 6008585.71N 568777.99 E 7610.31S 509.97W 6008536.15 N 568770.12 E 7650.73 S 516.78W 6008495.67 N. 568763.68 E 7701.54S 525.61W 6008444.78 N 568755.32 E 7740.64S 531.79W 6008405.62 N 568749.50 E 7791.53 S 539.23W 6008354.66 N 568742.54 E 7836.24S 546.59W 6008309.89N 568735.59 E 7883.91S 555.25W 6008262.14 N 568727.37 E 7928.82 S 563.28W 6008217.16 N 568719.77 E 7976.74S 571.93W 6008169.16 N 568711.56 E · 8018.92 S 579.70W 6008126.91N '568704.19 E 8063.29 S 587.93W 6008082.47 N 568696.37 E 8109.66S 596.90W 6008036.02N 568687.83 E 8151.77 S 604.18W 6007993.84N 568680.93 E 8201.10 S 612.13W 6007944.44 N 568673.45 E 8251.51S 619.92W 6007893.96 N - 568666.12 E 8287.34S 624.62W 6007858.08 N 568661.76 E 8344.05 S 633.69W 6007801.29 N 568653.22 E 8382.81S 641.25W 6007762.47 N 568646.02 E 8434.10 S 651.03W 6007711.08 N 568636.71E 6473.28 S 658.53W 6007671.64N 568629.57 E 8529.81S 668.g4W 6007615.21N 568619.69E 8560.53S 673.70W 6007564.45 N 568615.22 E 8614.65 S 682.10W 6007530.25 N 568607.32 E 8653.02S 688.46W 6007491.83 N 568601.32 E Dogleg Rate (°llOOft) Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 7321.61 Tie on point 2.14 7337.05 KOP 13.00 7417.70 11.53 7459.35 4.33 7510.33 2.32 t .96 2.44 1.16 3.95 0.84 4.73 0.91 1.79 1.56 0.46 0.48 2.76 7.09 4.34 4.72 0.79 8.60 3.56 1.63 2.51 3.29 4.91 2.87 1.03 7556.08 76O6.25 7647.23 7698.78 7738.36 7789.79 7835.09 7883.5O 7929.10 7977.75 8020.61 8065.70 8112.87 8155.58 8205.54 8256.55 8292.68 8350.11 8389.54 8441.70 8481.54 8538.98 8570.06 8624.83 8663.71 . .. DrillQuest 2.00.06 __ 28 February, 2001 - 11:50 Page 2 of 5 Sperry-Sun Drilling Services Survey Report for MPE.24AL1 MWD Your Ref: AP1500292286760 Surveyed: 26 January, 200f Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (rt) (ft) (ft) (fi) (rt) 10767.49 92.030 187.520 4190.07 4243.77 10798.36 92.160 187.100 4188.94 4242.64 10856.86 90.550 186.990 4187.56 4241.26 10884.95 91.720 190.030 4187.00 4240.70 10951.08 92.960 189.850 4184.30 4238.00 10991.44 91.780 189.530 4182.63 4236.33 11041.64 93.140 188.420 4180.48 4234.18 11081.54 93.690 189.270 4178.10 4231.80 11132.02 95.370 189.960 4174.12 4227.82 11171.91 95.450 191.680 4170.35 4224.05 11220.64 93.080 190.590 4166.73 4220.43 11265.40 94.370 190.450 4163.82 4217.52 11315.77 94.570 189.470 4159.90 4213.60 11355.06 94.750 189.530 4156.70 4210.40 11406.60 95,670 190.160 4152.02 4205.72 11436.33 92.640 191.940 4149.87 4203.57 11500.18 91.850 189.690 4147.37 4201.07 11536.69 91.600 190.210 4146.27 4199.97 11587.67 93.020 192.650 4144.22 4197.92 11626.59 91.230 191.940 4142.77 4196.47 11679.35 90.740 192.770 4141.86 4195.56 11721.37 91.110 193.160 4141.19 4194.89 11772.05 91.480 192.710 4140.04 4193.74 11800.15 91.480 193.170 4139.32 4193.02 11874.17 91.170 191.870 4137.60 4191.30 11908.21 91.360 191.730 4136.85 4190.55 11960.65 91.540 192.160 4135.53 4189.23 11996.31 91.850 191.830 4134.47 4188:17 12093.97 92.030 190.350 4131.16 4184.86 12142.85 92.090 191.190 4129.41 4183.11 8705.32 S 696.15W 8735.92S 700.07W 8793.96S 707.25W 8821.73 S 711.40W 8886.82 S 722.81W 8926.56 $ 729.60 W 8976.10 S 737.42 W 9015.46 S 743.54 W 9065.07 S 751.95 W 9104.08 $ 759.40 W 9151.75 S 768.79W 9195.67 S 776.94W 9245.12 S '785.63W 9283.75 S 792.09W 9334.32 $ 800.87W 9363.42S 806.55W 9426.08S 818.52W 9462.02S 824.82W 9511.95S 834.92W 9549.95S 843.20W 9601.48 S 854.49W 9642.42S 863.91W 9691.80 S 875.25W 9719.18 S 881.54W 9791.42S 897.59W 9824.73 S 904.54W 9876.02S 915.39W 9910.88 S 922.80W 10006.66S 941.58W 10054.65 S 950.70W 6007439.46N 568594.11E 6007408.82 N 568590.47 E 6007350.72 N 568583.84 E 6007322.91 N 568579.94 E 6007257.72N 568569.14 E 6007217.91N 568562.72 E 6007168.31N 568555.36 E 6007128.89 N 568549.60 E 6007079.21N 568541.66 E 6007040.13 N 568534.57 E 6006992.37 N 568525.63 E 6006948.38 N 568517.88 E 6006898.85 N 568509.66 E 6006860.17 N 568503.55 E 6006809.52 N .568495.25 E 6006780.37 N 568489.83 E 6006717.59 N 568478.44 E 6006681.59 N 568472.47 E 6006631.58 N 568462.84E 6006593.50 N 568454.92 E 6006541.87 N 568444.11 E 6006500.84 N 568435.06 E 6006451.36 N 568424.18 E 6006423.92 N 568418.14 E 6006351.54 N 568402.77 E 6006318.16 N 568396.13 E 6006266.78 N 568385.75 E 6006231.84N 568378.67 E 6006135.89 N 568360.79 E 6006087.82 N 568352.10 E Dogleg Rate (°/'lOOft) 3.20 1.42 2.76 11.59 1.89 3.03 3.5O 2.53 3.60 4.30 5.35 2.90 1.98 0.48 2.16 11.81 3.73 1.58 5.53 4.95 1.83 1.28 1.15 1.64 1.81 0.69 0.89 1.27 1.53 1.72 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 8716.57 8747.42 8805.89 8833.97 8900.01 8940.32 8990.47 9030.29 9080.59 9120.26 9168.78 9213.41 9263.60 9302.75 9354.05 9383.66 9447.38 9483.85 9534.70 9573.49 9626.10 9667.96 9718.44 9746.44 9820.21 9854.17 9906.48 9942.04 10039.51 10088.30 28 February, 2001 - 11:50 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE-24AL1 MI~VD Your Reft AP1 500292286760 Surveyed: 26 January, 200f Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 12188.76 92.090 189.200 4127.73 4181.43 10099.80 S 958.82 W 12236.62 92.280 188.440 4125.91 4179.61 10147.06 S 966.16 W 12283.55 92.640 189.030 4123.89 4177.59 10193.40 S 973.28 VV . 12332.95 92.460 188.970 4121.70 4175.40 10242.15 S 981.00 W 12378.08 92.710 188.000 4119.66 4173.36 10286.74 S 987.65 W ' 12428.56 92.400 187.940 4117.41 4171.11 10336.68 S 994.64 W 12468.78 92.400 188.200 4115.73 4169.43 10376.47 S 1000.28 W 12520.68 92.530 188.600 4113.49 4167.19 10427.76 S 1007.86 W 12565.50 91.840 188.300 4111.78 4165.48 10472.06 S 1014.44 W 12615.12 91.780 186.380 4110.22 4163.92 10521.25 S 1020.78 W 12657.95 91.850 186.220 4108.86 4162.56 10563.80 S 1025.47 W 12706.79 91.480 184.660 4107.44 4161.14 10612.40 S 1030.10 W 12748.43 91.540 185.660 4106.34 4160.04 10653.85 S 1033.85 W 12782.09 91.230 184.020 4105.53 4159.23 10687.38 S 1036.68 W 12850.00 91.230 184.020 4104.07 4157.77 10755.11 S 1041.44 W Global Coordinates Dogleg Northings Easfings Rate (ft) (ft) (°/100ft) 6006042.60 N 568344.40 E 6005995.27 N 568337.51E 6005948.87 N 568330.82 E 6005900.05 N 568323.55 E 6005855.40 N 568317.31E 6005805.40 N 568310.79 E 6005765.56 N 568305.52 E 6005714.20 N 568298.42 E 6005669.84 N 568292.25 E 6005620.59 N 568286.37 E 6005578.00 N 568282.07 E 6005529.36 N 568277.89 E 6005487.87 N 568274.53 E 6005454.32 N 568272.00 E 6005386.55 N 568267.87 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 188.099° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12850.00ft., The Bottom Hole Displacement is 10805.42ft., in the Direction of 185.531° (True). 4.33 1.64 1.47 0.38 2.22 0.63 0.65 0.81 1.68 3.87 0.41 3.28 2.41 4.96 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 10134.15 10181.97 10228.86 10278.20 10323.28 10373.71 10413.90 10465.75 10510.53 10560.12 10602.91 10651.68 . 10693.25 10726.84 10794.56 Projected Survey 28 February, 2001 - 11:51 Page 4 of 5 DriflQuest 2.00.06 Sperry. Sun Drilling Services Survey Report for MPE-24AL I MHID Your Ref: APl 500292286760 Surveyed: 26 January, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPE Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) Comment 9369.02 4266.54 7329.65 S 461.82 W Tie on point 9385.00 4270.64 7344.98 S 463.74 W KOP 12850.00 4157.77 10755.11 S 1041.44 W Projected Survey Survey tool program for MPE-24AL1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12850.00 4157.77 Survey Tool Description MWD Magnetic (MPE-24) 26 February, 2001 - 11:51 Page 5 of 5 DrillQuesf 2.00.06 13-Feb-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well MPE-24AL1 Dear Dear Sir/Madam: ~? Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,369.02' MD 9,385.00' MD 12,850.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, vv,,, ..... ,. ,~, .... ~ (.~,~ Survey Manager Attachment(s) RECEIVED 1 2001 Oil& Ga~ Oons; CommissiOn .~chora~e Milne Point Unit Alaska Drilling & Wells Milne Point MPE, Slot MPE24 MPE-24AL1 Surveyed: 26 January, 200t DEFiNiTiVE S UR VEY REPORT 28 February, 2001 Your Ref: AP1500292286760 Surface Coordinates: 6016150.87 N, 569209.37 E (70° 27' 16.0198' N, Kelly Bushing: 53.70ft above Mean Sea Level t49° 26' 06.8436" W) ORII--LIN~; E;ERVI I::B=; Survey Reft svy9812 A Holllbur~on Comp-ny Milne Point Unit Measured Depth (ft) Incl. Azim. Sperry-Sun Drilling Services Survey Report for MPE-24AL1 Your Ref: AP1500292286760 DEFiNiTiVE Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 9369.02 75.240 187.000 4212.84 4266.54 9385.00 74.980 187.230 4216.94 4270.64 9466.98 85.310 189.880 4230.96 4284.66 9508.71 89.940 191.480 4232.69 4286.39 9559.78 92.150 191.250 4231.76 4285.46 9605.61 92.460 9655.84 92.340 9696.86 92.270 9748.47 91.850 9788.09 92.710 9839.57 92.280 9884.91 92.030 9933.40 92.400 9979.08 93.210 10027.83 92.520 7329.65 S 461.82W 7344.98 S 463.74W 7424.73 S 475.76W 7465.69 S 483.49W 7515.74S 493.55W 190.220 4229.91 4283.61 7560.74S 502.08W 189.180 4227.81 4281.51 7610.20 S 510.54W 190.140 4226.16 4279.86 7650.61S 517.41W 189.970 4224.30 4278.00 7701.39 S 526.42W 188.560 4222.73 4276.43 7740.46 S 532.79W 188.340 4220.49 4274.19 7791.34S 540.35W 190.480 4218.78 4272.48 7836.03 S 547.76W 190.530 4216.91 4270.61 7883.67 S 556.59W 190.610 4214.67 4268.37 7928.52 S 564.96W 190.730 4212.23 4265.93 7976.37 S 573.98W 10070.77 92.710 191.120 4210.28 4263.98 10115.94 92.530 191.210 4208.21 4261.91 10163.20 91.470 191.320 4206.56 4260.26 10205.95 91.480 188.470 4205.46 4259.16 10255.93 90.120 190.230 4204.76 4258.46 Alaska Drilling & Wells Milne Point MPE 10306.94 89.820 187.730 4204.79 4258.49 10343.08 89.880 187.440 4204.88 4258.58 10400.55 93.330 191.000 4203.27 4256.97 10440.08 91.970 191.460 4201.45 4255.15 10492.33 91.840 190.650 4199.71 4253.41 10532.23 91.420 191.510 4198.58 4252.28 10589.75 92.210 189.760 4196.75 4250.45 10620.86 92.220 188.200 4195.55 4249.25 10675.67 92.150 189.750 4193.46 4247.16 10714.59 92.150 189.440 4192.00 4245.70 Global Coordinates Northings Easfings (ft) (ft) 6008817.24 N 568815.65 E Dogleg Rate (°/lOOff) 6008801.90 N 568813.88 E 2.14 6008722.04N 568802.59 E 13.00 6008681.01 N 568795.25 E 11.74 6008630.86 N 568785.65 E 4.35 6008585.80 N 568777.54 E 6008536.25 N 568769.55 E 6008495.79 N 568763.04 E 6008444.92 N 568754.51E 6008405.79 N 568748.50 E 6008354.85 N 568741.42 E 6008310.09 N 568734.42 E 6008262.37 N 568726.03 E 6008217.44 N 568718.08 E 6008169.51N' 568709.51E 8018.49 S 582.11W 6008127.32 N . 568701.77 8062.76S 590.84W 6008082.97 N 568693.45 8109.08 S 600.07W 6008036.57N 568684.65 8151.17 S 607.41W 6007994.41N 568677.70 8200.48 S 615.53W 6007945.02N 568670.04 8250.86 S 623.49W 6007894.57 N 568662.55 8286.69 S 628.26W 6007858.71N 568658.11 8343.37 S 637.46W 6007801.93 N 568649.44 8382.10 S 645.15W 6007763.13 N 568642.11 8433.36S 655.17W 6007711.79 N 568632.57 E E - E E E 8472.50 S 662.83W 6007672.58 N 568625.27 8529.00 S 673.44W 6007615.99 N 568615.18 8559.70 S 678.29W 6007585.24 N 568610.62 8613.80 S 686.84W 6007531.06 N 568602.58 8652.15 S 693.32W 6007492.65 N 568596.45 2.35 2.08 2.34 0.88 4.17 0.94 4.75 0.77 1.78 1.44 1.01 0.45 2.25 6.66 4.45 4.94 0.82 8.62 3.63 1.57 2.40 3.34 5.01 2.83 0.80 Vertical Section Comment 7321.61 7337.05 7417.70 7459.34 7510.32 7556.06 7606.23 7647.20 7698.74 7738,32 7789.75 7835.05 7883.46 7929.04 7977.68 8020.52 8065.58 8112.74 8155.45 8205.41 8256.41 8292.55 8349.97 8389.39 8441.55 8481.38 8538.81 8569.89 8624.65 8663.53 Tie on point AK-6 BP_IFR-AK KOP .__ 28 February, 2001 - 11:51 Page 2 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPE,24AL f Your Ref: AP1 500292286760 Surveyed: 26 January, 200f 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) 10767.49 92.030 187.720 4190.07 4243.77 10798.36 92.160 187.310 4188.94 4242.64 10856.86 90.550 187.230 4187.56 4241.26 10884.95 91.720 190.220 4187.00 4240.70 10951.08 92.960 190.110 4184.30 4238.00 10991.44 91.780 189.750 4182.63 4236.33 11041.64 93.140 188.660 4180.48 4234.18 11081.54 93.690 189.480 4178.10 4231.80 11132.02 95.370 190.160 4174.12 4227.82 11171.91 95.450 191.870 4170.35 4224.05 11220.64 93.080 190.840 4166.73 4220.43 11265.40 94.370 190.660 4163.82 4217.52 11315.77 94.570 189.600 4159.90 4213.60 11355.06 94.750 189.740 4156.70 4210.40 11406.60 95.670 190.340 4152.02 4205.72 11436.33 92.640 192.080 4149.87 4203.57 11500.18 91.850 189.850 4147.37 4201.07 11536.69 91.600 190.400 4146.27 4199.97 11587.67 93.020 192.760 4144.22 4197.92 11626.59 91.230 192.190 4142.77 4196.47 11679.35 90.740 192.880 4141.87 4195.57 11721.37 · 91.110 192.990 4141.19 4194.89 11772.05 91.480 192.750 4140.04 4193.74 11800.15 91.480 193.140 4139.32 4193.02 11874.17 91.170 191.810 4137.60 4191.30 11908.21 91.360 191.840 4136.85 4190.55 11960.65 91.540 191.280 4135.53 4189.23 11996.31 91.850 191.990 4134.47 4188.17 12093.97 92.030 190.250 4131.16 4184.86 12142.85 92.090 190.830 4129.41 4183.11 8704.42 S 701.21W 6007440.31N 568589.05 E 8735.00 S 705.24W 6007409.69 N 568585.30 E 8793.02S 712.64W 6007351.61N 568578.44E 8820.77 S 716.90W 6007323.82 N 568574.44 E 8885.81S 728.56W 6007258.68 N 568563.38 E 8925.53 S 735.52W 6007218.89 N 568556.79 E 8975.03S 743.54W 6007169.32 N 568549.23 E 9014.37S 749.82W 6007129.93 N 568843.32 E 9063.95 S 758.40W 6007080.27 N 568535.20 E 9102.93 S 765.99W 6007041.22 N 568527.97 E 9150.57 S 775.55W 6006993.49 N 568518.85 E 9194.45 S 783.88W 6006949.54N 568510.93 E 9243.88 S 792.72W 6006900.02 N 568502.55 E 9282.48 S 799.29W 6006861.36 N 568496.34 E 9333.03 S 808.24W 6006810.74 N 568487.86 E 9362.11S 814.01W 6006781.61N 568482.36 E 9424.74S 826.14W 6006718.86 N 568470.81E 9460.66S 832.56W 6006682.88 N 568464.73 E 9510.56 S 842.78W 6006632.89 N 568454.97 E 9548.53 S 851.18W 6006594.84N 568446.92 E 9600.03 S 862.63W 6006543.24 N 568435.95 E 9640.98 S 872.03W 6006502.21N 568426.93 E 9690.37 S 883.32W 6006452.71N 568416.10 E 9717.75 S 889.61W 6006425.28 N 568410.06 E 9790.00S 905.60W 6006352.88 N 568394.75 E 9823.31S 912.57W 6006319.51N 568388.09 E 9874.67S 923.08W 6006268.05 N 568378.06 E 9909.58 S 930.26W 6006233.08 N 568371.19 E 10005.35 S 949.09W 6006137.14 N 568353.26 E 10053.37 S 958.02W 6006089.03 N 568344.77 E Dogleg Rate (°/lOOft) Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 3.26 8716.39 1.39 8747.24 2.76 8805.71 11.43 8833.79 1.88 8899.82 3.06 8940.13 3.47 8990.27 2.47 9030.09 3.59 9080.39 4.27 9120.05 5.3O 9168.56 2.91 9213.18 2.14 9263.36 0.58 9302.51 2.13 9353.81 11.74 9383.41 3.7O 9447.13 1.65 9483.6O 5.4O 9534.44 4.83 9573.22 1.60 9625.81 0.92 9667.67 0.87 9718.17 1.39 9746.16 1.84 9819.94 0.57 9853.90 1.12 99O6.23 2.17 9941.80 1.79 10039.27 1.19 10088.07 28 February, 2001 - 11:51 Page 3 of 5 DrillQuest 2.00.06 Sperry. Sun Drilling Services Survey Report for MPE.24AL f Your Reft APl 500292286760 Surveyed: 26 January, 200f Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (rt) (ft) (ft) 12188.76 92.090 189.840 4127.73 4181.43 10098.51 S 966.25 W 12236.62 92.280 188.290 4125.91 4179.61 10145.73 S 973.79 W 12283.55 92.640 189.100 4123.89 4177.59 10192.08 S 980.88 W 12332.95 92.460 189.200 4121.70 4175.40 10240.80 S 988.73 W 12378.08 92.710 188.310 4119.66 4173.36 10285.36 S 995.59 W 12428.56 92.400 188.350 4117.41 4171.11 10335.26 S 1002.89W 12468.78 92.400 188.600 4115.73 4169.43 10375.00S 1008.82W 12520.68 92.530 189.180 4113.49 4167.19 10426.23 S 1016.83W 12565.50 91.840 188.800 4111.78 4165.48 10470.47 S 1023.83W 12615.12 91.780 187.040 4110.22 4163.92 10519.59 S 1030.66W 12657.95 91.850 186.580 4108.86 4162.56 10562.10 S 1035.74W 12706.79 91.480 185.080 4107.44 4161.14 10610.66S 1040.70W 12748.43 91.540 185.970 4106.34 4160.04 10652.09 S 1044.70W 12782.09 91.230 184.440 4105.53 4159.23 10685.60 S 1047.76W 12850.00 91.230 184.440 4104.07 4157.77 10753.29 S 1053.01W Global Coordinates Dogleg Northings Easflngs Rate (ft) (ft) (°/t00ft) 6006043.82 N 568336.96 E 6005996.53 N 568329.87 E 6005950.12 N 568323.21E 6005901.33 N 568315.81 E 6005856.71N 568309.37 E 6005806.74N 568302.52 E 6005766.94N 568296.97 E 6005715.64 N 568289.43 E 6005671.34N 568282.85 E 6005622.16 N 568276.47 E 6005579.61N 568271.79 E 6005531.00 N 568267.28 E 6005489.53 N 568263.66 E 6005455.99 N 568260.92 E 6005388.26 N 568256.29 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 188.099° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12850.00ft., The Bottom Hole Displacement is 10804.73ft., in the Direction of 185.593° (True). 2.15 3.26 1.89 0.42 2.05 0.62 0.62 1.14 1.76 3.55 1.09 3.16 2.14 4.64 0.00 Alaska Drilling & Wells Milne Point MPE Vertical Section Comment 10133.91 10181.73 10228.61 10277.96 10323.04 1O373.47 1O413.65 1O465.5O 1O510.28 10559.87 10602.67 1O651.45 10693.03 1O726.64 10794.40 Projected Survey 28 February, 2001 - 11:51 Page 4 of 5 DrillQuest 2.00.06 Sperry. Sun Drilling Services Survey Report for MPE.24AL f Your Ref: AP1500292286760 Surveyed: 26 January, 200f Milne Point Unit Alaska Drilling & Wells Milne Point MPE Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9369.02 4266.54 7329.65 S 461.82 W Tie on point 9385.00 4270.64 7344.98 S 463.74 W KOP 12850.00 4157.77 10753.29 S 1053.01 W Projected Survey Survey tool program for MPE-24AL f From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 9369.02 4266.54 9369.02 4266.54 12850.00 4157.77 Survey Tool Description MWD Magnetic (MPE-24) AK-6 BP_IFR-AK (MPE-24AL1) 28 February, 2001- 11:51 Page 5 of 5 DrillQuest 2.00.06 ALASKA OIL AND GAS CONSERVATIOn[ CO~ISSION Steve Schultz Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 995014192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re; Prudhoe Bay Unit MPE-24AL1 BP Exploration (Alaska) Inc. Permit No: 200-187 Sur Loc: 3613'NSL, 1936'WEL, Sec. 25, T13N, R10E, UM .Btmhole Loc. 1728'SNL, 2178'EWL, Sec. 06, T12N, RllE, UM Dear Mr. Schultz: Enclosed iSthe approved application for permit to drill the above referenced .well. The permit to drill 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. The permit is for a new wellbore segment of existing well MPE-24A, Permit No. 186, API '50- 029-22867-01' Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (B'OPE) 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 659-3607. Sincerely, . J. M. 'Heusser Commissioner .. BY O.RDER OF THE COMMISSION DATED this ~~---- day of November, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. * ALASK L AND GAS CONSERVATION COM SION PERMIT TO DRILL 20 AAC 25.005 , la. Type of work ~ Drill [] Redrill 1 lb. Type of well Re-Entry [] Deepen [] Service [][] DevelopmentEXpl°rat°ry Gas [][] StratigraphiCsingle Zone Test [][] MultipleDeVel°pmentzone Oil I ;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 ~z~'K/~n~L380110 4. Location of well at surface 7. Unit oFProperty Name 11. Type Bond (See 20 ^AC 25.025) 3613' NSL, 1936' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3723' SNL, 2401' WEL, SEC. 36, T13N, R10E, UM (OA Target) MPE-24AL1 Number 2S100302630-277 At total depth 9. Approximate spud date 1728' SNL, 2178' NWL, SEC. 06, T12N, R11E, UM ~;)jv~-0i~ 1.,Faofe~ 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 12744' MD / 4118' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9380' MD Maximum Hole Angle 93 ° Maximum surface 1067 psig, At total depth (TVD) 4000' / 1527 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casin(3 Wei(~ht Grade Couplinq Len,qth MD TVD MD TVD (include staqe data) 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 9720' 7" (Planned) 315 sx AS III, 265 sx Class 'G' 9750' 4375' Production Liner Perforation depth: measured None ~'"' '",~'~ '~ ".'Ir true vertical None .,.~ ~,~, ,~,,, ~'* .... ~ ~ r ,~[~ ^,achment [] [] [] ,,ve,er..tc [] or,,n, .ro,r,,m [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction ^nalysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Larry Wolfson, 564-5969 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreg(:~i~g~s true artd~f~ct~o the best of my knowledge Signed Steve Shultz ~ .... ~(/J~X~'-' Title Senior Ddlling Eng,neer Date ' ~"' ~' '~ ........... h ..... ~ ~ "'~ ~ ~ ~' i! a ~ ...~.~.~, ,.,.~..~ ......... ,,. , ,~.~,.~..~.'...~!rt~.,f~..~..~... ~ .... ~1 ~ ~," t, i! '.' ~I I.,~ !~.....t....~,~ Permit Number ..,.-./APl Number Approval D_ate _ I See cover letter -~-~"-/'~:~/,~- 50-029-22867-60 I/",~1~-., ~I for other requirements Conditions of Approval: Serf{pies Required [] Yes [~ No Mud Log Requi~d [] Yes I~ No Hydrogen Sulfide Measures [] Yes I~.No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE ~[~.K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: ORIGINAL SIGNED BY by order of Approved By J.M. Heusser Commissioner the commission Date//'~ ~ ~'~.. Form 10-401 Rev. 12-01-85 ORIGINAL 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 Type of Well (producer or iniector): I Producer (Sidetrack Multilateral) Surface Location: E-24A OB Target Start: E-24A OB Target End: E-24A L10A Target Start: 3613' FSL (1666' FNL), 1936' FEL (3342' FWL), Sec. 25, T13N, R10E X = 569209.37 Y = 6016150.87 1392' FSL (3887' FNL), 2426' FEL (2852' FWL), Sec. 36, T13N, R10E X = 568791 Y = 6008646 Z = 4263' TVDss 3551' FSL (1728' FNL), 2579' FEL (2178' FWL), Sec. 06, T12N, R11E 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 E-24A L10A Target End: 3551' FSL (1728' FNL), 2579' FEL (2178' FWL), Sec. 06, T12N, R11E X = 568140 Y = 6005520 Z -- 4061' TVDss I AFE Number: 1 337205 I Ri~l: I Nabors22E I Estimated Start Date: I Nov. 30;n 2000 I Operatin9 days to complete: 1 25.2 OA MD 12744' OB MD 12753' OA TVDrkb (TD) 4118' OB TVDrkb (TD) 4175' OA Max. Inc. 93° OB Max. Inc. 93° I KBE I 29.12' 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 ½" 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 ½" slotted liner with Baker "Hook Hanger" system into upper lateral. Freeze protect well. The well will be completed with a 3 ½" tubin~l ESP completion by Nabors 4ES. Version ~Y2, 11113/2000 Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drilling Permit 2. Current Well Information 2.1 General 2.2 2.3 2.4 Well Name: MPE-24A MPE-24A APl Number: 50-029-22867-01 MPE-24A L1 APl Number:50-029-22867-60 Well Type: Development - Schrader Bluff Sidetrack Multilateral Producer Current Status: Operations Shut-Down BHP: 1800 psi @ 4000' TVDss Schrader Bluff 'OB' sand. Normal pressure gradient. BHT: 80°F @ 4020' TVDss Estimated (SOR) Current Mechanical Condition MPE-24: Doyon 27E: Conductor: Surface: Abandonment Plug EZSV set at Abandonment Plug Bridge Plug 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' Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Expected reserves 2.0 MMbbl Production rate: 1500 stb/d Production rate: 1000 stb/d Materials Needed Production Casing: 9750' 40~ 11~ 2~ 7" 264f 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 2 x Production Liners: 6650' 170 off 4 %" x 5 ~4" x 8" 7" x 4 ½" 4½" I assembly 4 ½", 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. L-80 Completion: 9280' 2%" ESP 2 %" Gauge 2 %" Landing Nipple 2x2%" 1off I lot 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 M PE-24A Drillin~l Permit 3. Drillin_ Hazards and 'Contingencies 3.1. Well Control "'''''''/ ~ ''~* ~.n~ *"' .... "'"'Oii ''''~' -~'~-~'"'-'"*'" .... ? :~'''''~'~''~;''''' ..... MANDATORY WELL CONTROL DRILLS: Drill Type Frequency 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 carry 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 circulation 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. 3.5.2. Schrader Bluff Tract 14 2000 Pro~lram M PE-24A Drillin~l Permit Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.6. 3.5.3. There is a risk of differentially sticking the 4 ½" 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 whi~.~;., ..r~r~jD...~,,!,_n the o~en hole. Pad Data Sheet 3.6.1. Please Read the E-Pad Data Sheet thoroughly. 3.7. Hydrates 3.7.1. 3.7.2. 3.7.3. 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 TVDss! Shallow gas was encountered on E-7 and E-8 just under the base of the Permafrost (2296' TVDss and 2480' TVDss respectively). Gas and oil cut mud was also encountered on E-3 at 3880' TVDss and 3974' TVDss. 3.7.4. 3.7.5. Mud returns should be monitored to determine if hydrates are encountered on this well. 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) c) d) e) 2 ppb Lecithin - have in mud system prior to drilling hydrates 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. 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) i) 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 Drilling 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 pementage of 6 ~" hole in reservoir zone drilling in the OA/OB 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 ~nj 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 Lon~ Term Shut In Feb 2000 1 . Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit Drillin_cl Program 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 I Max Exp Surface Pressure 1527 psi @ 4000' TVDI 1067 psi (estimated) (0.115 psi/ft gas ~lradient) BOPE Ratin~l 5000 psi WP lentire stack & valves) IPlanned BOPE Test Pres. 2000/250 psi Rams and Valves 2000/250 psi Annular 4.3. Mud Program 6 W' Production Hole Mud Properties: OBIOA Density (ppg) I Funnel visI YP HTHP 9.1 40 - 55 22 - 27 < 10 KCL- CaCO3 Baradril N Mud pHI APl Filtrate I LG Solids 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 Cuffings 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 Drilling 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" 12.64f L-80 IBT-Mod 3301' 9452' / 4320' 12753' / 4175' 6 ~" OA 4 ½" 12.6# L-80 I BT-Mod 7373' 9380' /4272' 12744' /4118' Tubin~l 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 Amtic Set III Light 265 sx 55 bbl 15.8 Ib/~al Class 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. Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit 4.7. Survey and Logging Program I 6 ~/~" Hole Sections: I MWD I GR/Res I PWD I DDS I ABI / 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.) 1 ( Schrader Bluff Tract 14 2000 Pro~lram MPE-24A Drillin~l Permit MPE-24A Nabors 22E Operations Summary 5.1. Pre-Rig Operations 1. Grade and level pad 5.2. Procedure 13. 14. 15. 16. 17. 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 Yz" 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 ~" 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. Schrader Bluff Tract 14 2000 Pro~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=16'tree. MPU E-24 O,g. OF. mv.=57.1'(,27E) Wellhead: Gen. 5A system. 11" csg. Orig. GL. elev.= 24.3' spool, 7 1/16' X 11" 5M FMC tbg. spool w/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" 91.1PPf, H-40 I 113, I , ) Howco 9 5/8" 'ES' I 2147' md I seawater to top of BP Cementer stage collar I I KOP O 300' I 9 5/8" bridge plug I I Max. hole angle = 74 to 77 deg. I. J I 6910' md I f/3650' to 9450'I 10.1 ppg drlg. fluid 15 bbl. (200') of Class 'G' Hole angle through perfs. = not appl. ~ I ~ cement above the retainer. Howco9 5/8" EZSV I 10,009' I 95/8",40ppf, L-80 Mod. 10,077' ~[,~cementing mtaine Btrs. surface casing I I ) ~33 bbl. of Class G'cement i below the retainer. Stimulation Summary none performed Perforation Summary, i I ~ ~ ~..,.. :.j' ~ ,~:' '. "~' Ref loft: Not applicable TOO = 13,343' 51 bbl. (250 sks) Olass G cement plug 8.5" hole drilled to 14,386'. Kup. Sands are wet. DATE REV. BY COMMENTS MILNE POINT UNIT 04/05/98 JBF Drilled & Temp. P&A by Nabors 27E WELL E-24 APl NO: 50-029-22867 BP EXPLORATION (AK) ! TREE: FMC 2 9/16" 5M PROPOSED COMPLETION WELLHEAD: FMC Gen 5A System~'"P E-24A & E-24A L~' OrigKBelev(N27E)=5?.l' 11", 5M csg.head w/ .... ~ .... Cellar Box elev = 24.3' 7" mandrel hanger & packoff ."'""' 7 1/16" x 11", 5M, tbg spool w/ 7" x 2 7~8" tubing hanger I ''~' I Welded ~ · / ·" [ 21 2-7/8" x 1 Gas Lift Mandrel ,. 2133' 9 5/8" Casing Patch (30 ') ; ' DriftJlD · 2.347"/2.441" I 2147' I 9 5/8" 1ES" CementerI I :'~:':'::. ': ii 0- ...... ,,'.~, .~,-, Centrilifl Electric Submersible Pump Casing Drift: 6.151" Casing ID: 6.276" ~; , Centrilift Pressure Gauge I ~so, Baker Hughes Hookwall Hanger ....................... Bakor Hughes ConYentional Hanger Well Inclination @ INindow = ?5° ~ottom Trip Anchor and Whip~tock /l~.~.~.~...... , 0-~/8" OB lateral TD I 7" Casing Shoe @ ±0750' ~ ~. 4-112" Slotted Uner & Hanger PBID @ 0,800' (est) - 115 bbl "G" ~mt How¢o 0 5/8" fiZ$¥ @ 10,000' 0 5/8", 40 ppg I_-80 BI¢-M Csg @ 10,077' · DATE REV. BY COMMENTS - Milne Point Unit - WELL: E-24A ML 1111312000 Larry Wolfson Level 2 Multi-Lateral, 2 718" ESP Completion APl NO: _ BP Exploration(Alaska) Sperry-Sun Drilling Services Proposal Report for MPE-24AI.t Wpf North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 9380.00 75.120 187.110 4214.78 4271.88 7336.93 S 462.72 w 9400.00 77.202 188.341 4219.56 4276.66 7356.17 S 465.33W 9412.00 78.453 189.069 4222.09 4279.19 7367.76 S 467.11W 9500.00 88.778 191.303 4231.86 4288.96 7453.71S 482.57W 9536.34 93.043 192.213 4231.29 4288.39 7489.28 S 489.97W 10000.00 93.043 192.213 4206.67 4263.77 7941.80 S 587.91W 10500.00 93.043 192.213 4180.13 4237.23 8429.80 S 693.53W 11000.00 93.043 192.213 4153.59 4210.69 8917.80 S 799.15W 11500.00 93.043 192.213 4127.05 4184.15 9405.79 S 904.77W 12000.00 93.043 192.213 4100.51 4157.61 9893.79 S 1010.39W 12500.00 93.043 192.213 4073.97 4131.07 10381.78 S 1116.01W 12744.31 93.043 192.213 4061.00 4118.10 10620.23 S 1167.62W Global Coordinates Northings Eastings (ft) (fl) 6008809.71 N 568814.37 E Dogleg Rate (°ll00ft) Alaska State Plane 4 MILNEPT MPE Vertical Section (ft) 7343.55 6008790.45 N 568811.94 E 12.000 7362.96 6008778.84 N 568810.27 E 12.000 7374.68 6008692.75 N 568795.61 E 12.000 7461.81 6008657.12 N 568788.54 E 12.000 7497.97 6008203.70 N 568694.80 E 0.000 7958.49 6007714.74 N 568593.72 E 0.000 8455.10 6007225.78 N 568492.64 E 0.000 8951.72 6006736.83 N 568391.56 E 0.000 9448.33 6006247.87 N 568290.47 E 0.000 9944.95 6005758.92 N 568189.39 6005520.00 N 568140.00 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). E 0.000 E 0.000 Based upon Minimum Curvature type calculations, at a Measured Depth of 12744.31ft., The Bottom Hole Displacement is 10684.23ff., in the Direction of 186.274° (True). 10441.57 1o684.23 Comment ST Exit ~ 12.000°1100ft, 30.000° TF: 9380.00ft MD, 4271.88ft TVD End Dir: 9536.34ff MD, 4288.39ft TVD Total De~th: 12744.31ft MD, 4118.10ft TVD Target - MPE-24 L2 TD Continued... 13 April, 2000- 9:02 - 1- DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for MPE-24AL) Wp1 North Slope Alaska Alaska State Plane 4 MILNEPT MPE Comments Measured Depth (ft) 9380.00 9536.34 12744.31 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4271.88 7336.93 S 462.72 W 4288.39 7489.28 S 489.97 W 4118.10 10620.23 S 1167.62 W Comment ST Exit @ 12.000°/100ft, 30.000° TF: 9380.00ft MD, 4271.88ft TVD End Dir: 9536.34ft MD, 4288.39ft TVD Total Depth: 12744.31ft MD, 4118.10ft TVD Targets associated with this wellpath Target Name MPE-24 L2 TD Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Easflngs (ft) (ft) (ft) 4118.10 10620.23 S 1167.62W 4061.00 6005520.00 N 568140.00 E 70°25'31.6771"N 149°26'41.0722"W Target Target Shape Type Point f3 April, 2000 - 9:02 - 2 - DrillQuest f. 05.05 (' H 17 ..¢; 4 0 8 ~ o/~ ?/oo oD ~ 764o~, VENDOR AI-ASKASTAT 10 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 101200 CKIO12OOD 100. O0 100. O0 PYMT (:OMMENTS: PERI IIT TO DRILL I'EE HANDL]:NG~ 'rNST: ~/H ~ONDRA X4?~iO AITACflED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 1 OO. OO 3, OO, OO .... ,,BP.EXPLORAT. IO...N (ALASKA')~.:!NG,. :': ;:,. :..'AN~:hOAA~?iAdS~i!~ 99519-6612 '~!:i'i:,::!i! i:.?!:,'~: i:" .. .pAy ,"&?Ri, Off," ~:Ot,~O:~Gqs~: OOGNN~q," WELL PERMIT CHECKLIST COMPANY WELL NAME ~-~?~/-. ! PROGRAM: exp dev ,/ redrll serv wellbore seg ~ ann. disposal para req FIELD & POOL ADMINISTRATION DATE ENGINEERING INIT CLASS ~'-~'~V 7~)/4.-, APPR DATE 1. Permit fee attached ...... 2. Lease number appropriatec~ ~ ~ ~-'-'-'P,~; ?~. 'i '.5~i/i 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 ........... GEOL AREA ~c:~,) UNIT# ~ .j ! ~ ~-~ ON/OFF SHORE 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~{~,..~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. GEOLOGY 30. ~ ' 31. 32. II APPR DATE 33. (A) will ~ntain waste in a suitable re~iving zone~ ....... Y N Y Y · . ~,, ,"'2 ~___ ~ ~ t. Is presence of H2S gas probable ................. '~ N~ t'~'~'> ~>~'~-.r~:k-~'" ~>~c,~, ~'~ '~-'e'"~-'~' ~ ~ '~'~~~ .. ' --18 . , Permit can be issued wlo hydrogen sulfide measures ..... ~ '~ ~ '~ 4= Data presented on potential overpressure zones ....... ~m ~~ ~ ~-~ Seismic analysis of shallow gas zones ............ ' .~ Y N ~ Seabed ~ndition suwey (if off-shore) ......... ~ ~ '- Y N Conta~ name/phone for weekly progress repo~s [~mto~ only] Y N With proper ~menting records, this plan Y N Y N Y N Y N Commentsllnstructions: , (B) will not contaminate, freshwater; 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. GEOLQGY: ENGINEERING:. UIC/~,,n. ular . COMMISSION: 1§ I§ c:\msoffice\wordian\diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particula.rly germane to the Well Permitting Process but is part Of the history' file. To improve :the readability of the Well History file and to Simplify finding information, informati~)n 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 $ Thu Nov 29 10:17:22 2001 Reel Header Service name ............. LISTPE Date ..................... 01/11/29 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 ..................... 01/11/29 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 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 7 AK-MM-10008 J. FOLEY C. DIXON MPE-24AL1 500292286760 B.P. Exploration (Alaska), Inc Sperry Sun 29-NOV-01 MWD RUN 9 AK-MM-10008 J. FOLEY C. DIXON 25 13N 10E 3613 1936 .00 53.70 24.30 RECEIVED DEC 2. 8 2001 & Gas Cons. Comrmss~o,, AlaskaOi~ " "' ' Anchorage 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9385.0 7.000 9385.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 6 IS DIRECTIONAL ONLY. THIS RUN WAS USED TO SET THE WHIPSTOCK AND MILL AND IS NOT PRESENTED. 3. MWD RUNS 7, 8, AND 9 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GE MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. MWD RUN 8 RESULTED IN A SHALLOW PULSE FAILURE AND IS NOT PRESENTED. 5. MPE-24AL1 KICKS OFF FROM MPE-24 AT 9385' MD, 4271' 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. 6. MWD RUNS 7 AND 9 REPRESENT WELL MPE-24AL1 WITH API % 50-029-22867-60. THIS WELL REACHED A TOTAL DEPTH OF 12850' MD, 4158' 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 ....... 01/11/29 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 9361.5 12795.5 RPD 9375.5 12802.5 RPM 9375.5 12802.5 RPS 9375.5 12802.5 RPX 9375.5 12802.5 ROP 9414.5 12849.5 FET 9415.0 12802.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 7 9361.5 10185.0 9 10185.5 12849.5 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 9361.5 12849.5 11105.5 6977 First Reading 9361.5 Last Reading 12849.5 ROP MWD FT/H 9.72 2028.2 GR MWD API 29.39 104.62 RPX MWD OHMM 0.32 788.78 RPS MWD OHMM 0.17 2000 RPM MWD OHMM 0.47 2000 R?D MWD OHMM 0.09 2000 FET MWD HR 0.2 30.41 170.958 72.1879 29.5468 37.6738 45.4088 48.5085 1.22092 6871 6869 6855 6855 6855 6855 6776 9414.5 9361.5 9375.5 9375.5 9375.5 9375.5 9415 12849.5 12795.5 12802.5 12802.5 12802.5 12802.5 12802.5 First Reading For Entire File .......... 9361.5 Last Reading For Entire File ........... 12849.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/29 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 ....... 01/11/29 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9361.5 10131.0 RPX 9375.5 10138.0 RPD 9375.5 10138.0 RPS 9375.5 10138.0 RPM 9375.5 10138.0 ROP 9414.5 10185.0 FET 9415.0 10138.0 $ LOG HEADER DATA DATE LOGGED: 23-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10185.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 85.3 93.2 TOOL NUMBER PBO1732HAGR4 PBO1732HAGR4 6.125 Water Based 9.10 53.0 8.1 30000 4.0 .120 .105 .100 .200 70.0 81.2 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET ~D070 HR 4 1 68 28 Name Service Unit DEPT FT ROP MWD070 FT/H GR MWD070 AP1 RPX MWD070 OHMM RPS MWD070 OHMM RPM MWD070 OHMM RPD MWD070 OHMM FET MWD070 HR Min Max 9361.5 10185 9.72 2028.2 29.39 104.62 0.32 788.78 0.17 1337.29 0.47 2000 0.09 2000 0.25 2.87 Mean Nsam 9773.25 1648 185.906 1542 72.3699 1540 18.2322 1526 20.4322 1526 42.1036 1526 48.9167 1526 0.796634 1447 First Reading 9361.5 9414.5 9361.5 9375.5 9375.5 9375.5 9375.5 9415 Last Reading 10185 10185 10131 10138 10138 10138 10138 10138 First Reading For Entire File .......... 9361.5 Last Reading For Entire File ........... 10185 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10131.5 12795.5 RPD 10138.5 12802.5 RPM 10138.5 12802.5 RPS 10138.5 12802.5 RPX 10138.5 12802.5 FET 10138.5 12802.5 ROP 10185.5 12849.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 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 26-JAN-01 Insite 4.05.5 66.16 Memory 12850.0 89.8 95.7 TOOL NUMBER PBO1732HAGR4 PBO1732HAGR4 6.125 Water Based 9.20 52.0 8.2 26000 4.4 .120 .094 .100 .200 70.0 91.4 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD090 FT/H 4 1 68 GR MWD090 API 4 1 68 RPX MWD090 OHMM 4 1 68 RPS MWD090 OHMM 4 1 68 RPM MWD090 OHMM 4 1 68 RPD MWD090 OHMM 4 1 68 FET MWD090 HR 4 1 68 0 4 8 12 16 20 24 28 Name Service Unit Min Max DEPT FT 10131.5 12849.5 ROP MWD090 FT/H 10 412.84 GR MWD090 API 50.21 103.09 RPX MWD090 OHMM 5.9 333.85 RPS MWD090 OHMM 7.12 2000 RPM MWD090 OHMM 9.17 2000 RPD MWD090 OHMM 9.97 2000 FET MWD090 HR 0.2 30.41 Mean 11490.5 166.633 72.1352 32.7868 42.6111 46.3552 48.3916 1,33612 First Last Nsam Reading Reading 5437 10131.5 12849.5 5329 10185.5 12849.5 5329 10131.5 12795.5 5329 10138.5 12802.5 5329 10138.5 12802.5 5329 10138.5 12802.5 5329 10138.5 12802.5 5329 10138.5 12802.5 First Reading For Entire File .......... 10131.5 Last Reading For Entire File ........... 12849.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/11/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/11/29 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
