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HomeMy WebLinkAbout201-134 Im~e Project Well History File Cove=, Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA [3 Color items: J~ Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL ~WINDY Scanning Preparation / x30= BY: BEVERLY ROBIN VINCENT SHERYL ~INDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BEVER OBIN ""V~)NC ENT Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES .^.,^ .. _ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED B?': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DA'I'E: Isl General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned,wpd ' STATE OF ALASKA •SKA OIL AND GAS CONSERVATION C•MISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS FEB 2 8 2013 1. Operations Performed: AO CC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other El Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 201 - 134 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 23031 - 60 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 & 315848 V MPG - 14L1 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): r Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 9400' feet Plugs:(measured) None feet true vertical 4150' feet Junk: (measured) None feet Effective depth: measured 9400' feet Packer: (measured) 6077' & 6286' feet true vertical 4150' feet Packer: (true vertical) 3979' & 4062' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34' - 112' 34' - 112' 1490 470 Surface 6473' 7" 35' - 6508' 35' - 4136' 7240 5410 Intermediate Production Liner 2849' 4 -1/2" 6499' - 9348' 4133' - 4150' 8430 7500 Perforation Perf6110'- 6270', Slotted 6570 - 9304' erforation Depth: Measured Depth: feet True Vertical Depth: Perf 3992' - 4056', Slotted 4149' - 415 feet Tubing (size, grade, measured and true vertical depth): 2 - 7/8 , 6.4# 13Cr80 5930' 3917' 4 - 1/2 ", 12.6# L - 80 6077' - 6331' 3979' - 4079' Packers and SSSV (type, measured and true vertical depth): 7" Halliburton 23 - 29# 'VTL' Versa - trieve Pkr 6077' & 6286' 3979' & 4062' & 7" Baker 'SLZXP' Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED APR 1 7 2013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 77 50 284 240 183 Subsequent to operation: 153 87 382 220 337 14. Attachm ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: i ® Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge . Sundry Number or N/A if C.O. Exempt: Contact: Noel Nocas, 564 -4667 N/A Email: Noel.Nocas @bp.com Printed Na . oe Lastu a Title: Drilling Technologist Signature: )1. 9- hone: 564 -4091 Date: 2./2:7 /1 Form 10 -404 Revi 0/20128 s+ MAR 01 - 4rVF / Submit Original Only • • • " x f� yea- , ^ F y , Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud DateTme: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/5/2013 02:00 - 04:00 2.00 MOB N PRE WAIT ON MPU ROADS AND PADS TO PREP MPG -14 - PREP RIG FOR MOVE AND PERFORM MAINTENANCE 04:00 - 09:00 5.00 MOB P PRE PJSM, FOR MOVE OFF MPG -15 - SPREAD HERCULITE AND PLACE MATS AROUND WELL NOTIFY PAD OPERATOR OF MOVE - BOTH TOOLPUSHERS AND WSL PRESENT TO PULL OFF WELL - PULL OFF MPG -15 AND SPOT AWAY FROM WELL TO ALLOW FOR RIG MAT PLACEMENT - MOVE OVER WELL MPG -14 - WSL TOOLPUSHER PRESENT. RIG ACCEPTED AT 0900 HRS 2/5/2013. 09:00 - 13:30 4.50 WHSUR P DECOMP PJSM, R/U KILL MANIFOLD IN CELLAR. - CIRCULATING LINE TO WELL HEAD. - TAKE ON 130• DEG F. SEAWATER (8.5PPG KWF) TO PITS. - CAN NOT BLOW THRU HARD LINE. - REMOVE 2" VALVE, PLUGGED 1MTH SNOW FROM THE FIRST BLOW DOWN ATTEMPT. HEAT HARD LINE WITH STEAM. AMBIENT TEMP -40 DEG. F. - FILL LINES WITH DIESEL - PRESSURE TEST KILL MANIFOLD AND HARD LINE. - 250 / 3500 PSI F/5 CHARTED MIN. PASSED. 13:30 - 14:30 1.00 WHSUR P DECOMP HELD RIG EVACUATION DRILL. - HEAD COUNT WAS 16 WORKERS. AAR - IT WOULD BE HELPFUL IF THE TYPE OF EVACUATION DRILL WAS ANNOUNCED, FIRE, GAS, KICK, ECT. - SCBA WAS NOT PLACED IN THE CASE IN THE READY POSITION TO DON THE FACE MASK IN ATIMELY MANNER. - EVAC SIRENS ON EACH SIDE OF THE RIG NOWARE FULLY FUNCTIONAL. - IMPLEMENTED A PLAN TO HAVE BOTH ENTRANCES TO THE PAD BLOCKED DURING EVAC. 14:30 - 16:30 2.00 WHSUR P DECOMP PJSM, PU DSM LUBRICATOR. RU TEST HOSES. TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. - PULL BPV WITH TESTED LUBRICATOR. SITP = 450 PSI. SICP = 650 PSI - LD LUBRICATOR PER DSM REPS. -CLOSE OUT VWVT ON MPG -15 Printed 2/18 /2013 3:01:21 PM k l ! r' T X f X z ,, " � , r s; C b �, d • § cx f ' : y y z' %' r a s a * , r fr t _ 'az s ;. ~z .,r. ,� =s3 s a .° az a'' ✓ e f ` r I $4 S i 5 e 3 ` s i � � s � � � $ � � � ,tff r` y'x,a ,fi ...<. .��.,:.e,a �r~zu,.w.. ..�.r.�kk.'� s- ��.._ Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 17:30 1.00 WHSUR P DECOMP PJSM ON DDI WELL KILL SOP. - SITP = 450 PSI. SICP = 650 PSI. - WSL & TOOL PUSHER VERIFY VALVE ALIGNMENT. - BLEED GAS FROM THE IA TO FLOW BACK TANK. - BLEED IA FROM 650 PSI IN 22 MINUTES SITP = 150 PSI. NO FLUID IN THE RETURNS. 17:30 - 19:30 2.00 WHSUR P DECOMP R/U TO BULLHEAD WELL VIA WELL KILL SKID IN CELLAR. - WSL & TOOL PUSHER VERIFY VALVE ALIGNMENT. - BULLHEAD DOWN 2 7/8" TBG AND IA SIMULTANEOUSLY. - BULLHEAD WITH 130 DEGREE 8.5 PPG SEAWATER. - PUMPED 585 BBLS KWF @ 7 BPM. - ICP TBG = 200 PSI. I/A = 200 PSI. - FCP @ TBG -@ 7 BPM = 525 PSI I/A = 550 PSI. - SLOW TO 1 BPM @ TBG = 300 PSI. I/A = 300 PSI. PUMPS OFF @ 18:45 HRS. - SITP = 200 PSI. SICP = 200 PSI. - 10 MINUTES 50 PSI BOTH. - 20 MINUTES TBG AND IA ON A VACUUM. - MONITOR WELL FOR THE FULL 30 MINUTES. 19:30 - 20:00 0.50 WHSUR P DECOMP BLOW DOWN & RIG DOWN CIRCULATING LINES & KILL MANIFOLD -R /U SECONDARY KILL LINE TO I/A -PUMP 70 BBLS TO TRYAND CATCH FLUID -BEGIN CONTINUOUS HOLE FILL@ 20 BPH - SENT SECOND E -MAIL NOTICE TO AOGCC, BECAUSE WE RECEIVED NO 12 HR REPLY TO FIRST E -MAIL. 20:00 - 21:00 1.00 WHSUR P DECOMP PJSM ON R/U LUBRICATOR AND SETTING TWC -R /U LUBRICATOR, CHART TEST 250 PSI LOW AND 3500 PSI HIGH 21:00 - 22:30 1.50 WHSUR P DECOMP PERFORM ROLLING TEST FROM BELOW TWC -PUMP 89 BBLS @ 7 BPM = 400 PSI. CHART FOR 10 MINS -TEST TWC FROM ABOVE 250 PSI LOWAND 3500 PSI HIGH, CHARTED. 22:30 - 23:30 1.00 WHSUR P DECOMP PJSM TO DRAIN AND NIPPLE DOWN TREE & N/U BOPE - NIPPLE DOWN TREE - -FMC REP CLEAN AND INSPECT EUE 8RD HANGER THREADS - CONFIRM 9 1/2 TURNS BY HAND 23:30 - 00:00 0.50 BOPSUR P DECOMP PJSM, NIPPLE UP BOPE - N/U 13 -5/8" BOPE STACK. -AOGCC , JEFF JONES WAIVED STATES RIGHT OF WITNESS BOP TEST - MAINTAIN HOLE FILL TO IA AT 20 BPH WITH 8.5 PPG SEAWATER. 2/6/2013 00:00 - 03:00 3.00 BOPSUR P DECOMP FINALIZE NIPPLE UP OF13 -5/8" BOPS -HOLD PJSM TO DISCUSS BOPE TEST Printed 2/18/2013 3:01:21 PM • � � Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9 /2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UW: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 03:30 0.50 BOPSUR P DECOMP PREPARE FOR BOP TEST -R /U TEST EQUIPMENT -FILL RISER, NOTICE RISER AIR BOOT IS NOT SEALING AROUND RISER -PULL RISER FOR EXTENSION 03:30 - 04:30 1.00 BOPSUR N DECOMP SEND RISER TO SHOP AND EXTEND 8 ". - REINSTALL RISER. - PERFORM DERRICK INSPECTION - SERVICE DRAWWORKS -MAKE SPCC CHECKS 04:30 - 14:30 10.00 BOPSUR P DECOMP PJSM, TEST THREE PREVENTER BOPE AND RELATED EQUIPMENT - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST 2 7/8" X 5" VARIABLE RAMS WITH 2 7/8" AND 4" TEST JOINT, 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, AND CHOKE MANIFOLD TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST. - NO FAILURES. - JEFF JONES OFAO GCC WAIVED STATES RIGHT TO WITNESS BOP TEST - MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST. 14:30 - 15:00 0.50 BOPSUR P DECOMP RD BOPE TEST EQUIPMENT AND ASSOCIATED HOSES. - BD SURFACE LINES AND RIG CHOKE MANIFOLD. 15:00 - 17:30 2.50 BOPSUR P DECOMP PJSM, FILL BOPE, P/U AND R/U DSM LUBRICATOR / OFFSET EXTENSION. CLOSE ANNULAR AND PRESSURE TEST T/ 250 / 3500 PSI AND CHART F/ 5 MINUTES EACH. PULL TWCAND R/D DSM LUBRICATOR AND EXTENSION. 17:30 - 19:30 2.00 PULL P DECOMP PJSM PRIOR TO PULLING HANGER - VERIFY THAT NO PRESSURE IS BELOW - HANGER, IA IS ON A VACUUM -MAKE UP TIW TO LANDING JOINT -MAKE UP TO FMC 11" X 2 7/8" TUBING, HANGER, 9 1/2 TURNS, FMC REP BOLDS -PULL HANGER @ 73K, PUW= 65K, SOW =75K - REMOVE ESP CABLE FROM HANGER -R /U CIRC LINES TO HANGER - CONTINUE HOLE FILL @ 20 BPH Printed 2/18/2013 3:01:21 PM w � Tfik T K i ,' r. .,... ..„ . . „ a r :. 3;,.. _, Wx,`:',,. ....,.. � ..< s �x-° � Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Daternme: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 21:00 1.50 PULL P DECOMP BULLHEAD DOWN TUBING -CLOSE ANNULAR - BULLHEAD 40 BBLS OF 8.5 PPG SEAWATER @ 5 BPM & 970 PSI DOWN TUBING - VERIFY NO TRAPPED PRESSURE AND OPEN ANNULAR, TUBING & IA ON VACUUM -BLOW DOWN AND RIG DOWN CIRC LINES -LAY DOWN TUBING HANGER AND LANDING JOINT -HANG ESP SHEAVE AND TRUNK 21:00 - 00:00 3.00 PULL P DECOMP PJSM, PULL ESP COMPLETION ASSEMBLY -POOH W/ 6.5 #, 2 7/8" EUE 8RD TUBING, STANDING BACK -POOH FROM 6004 MD. PUW =65K, SOW= 75K - CONTINUAL HOLE FILL @ 20 BPH W/ 8.5 PPG SEAWATER -301 BBLS LOST 2/7/2013 00:00 - 01:00 1.00 PULL P DECOMP POOH W/ 6.5 #, 2 7/8" EUE 8RD TUBING, STANDING BACK -AT 3040' MD. PUW =58K, SOW= 63K 01:00 - 01:30 0.50 PULL P DECOMP _ KICK WHILE TRIPPING DRILL AAR: .- QUICK TO ARRIVE TO ASSIGNED STATIONS AND COMMUNICATE STATUS - SAFETY VALVE -JOINT WAS EASILY ACCESABLE - DISCUSSED THE NEED TO P/U TOP DRIVE ENOUGH TO ALLOW CLEARANCE TO EASILY STAB SAFETY VALVE - DISCUSSED ISOLATION OF CEMENT LINE AND ANY LINES THAT MAY BE OPEN DURING SPECIFIC OPERATIONS - CLEAN AND CLEAR RIG FLOOR 01:30 - 04:00 2.50 PULL P DECOMP PJSM TO DISCUSS LAYING DOWN SPECIFIC JOINTS POOH W/ 6.5 #, 2 7/8 "EUE 8RD TUBING,.. STANDING BACK - LAY DOWN JOINTS 132,133,134 - JOINT 133 HAS 2 DIME SIZED HOLES. - 1ST HOLE IS -7FT FROM UPPER COLLAR, 2ND HOLE IS -16FT FROM UPPER COLLAR - CONTINUE POOH TO ESP PUMP MOTOR AND ASSEMBLY 04:00 - 05:30 1.50 PULL P DECOMP LAY DOWN ESP PUMP AND MOTOR ASSEMBLY - FEED ESP CABLE THROUGH SHEAVE AND SPOOL UP ON REEL IN SPOOLING UNIT 05:30 - 07:30 2.00 PULL P DECOMP RIG DOWN CENTRALIFT - R/D SHEAVE - ESP FAILURE TO BE DETERMINED AT SHOP - CLEAN AND CLEAR RIG FLOOR. - SET WEAR RING. - MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER AT 20 BPH. Printed 2/18/2013 3:01:21 PM k ss t .z., ,,. � . a `.J ..... ,_n r ' ,...... ..._u r., -r& w, ^ : ' .� � ,tr ' .� ' . k h ., " Yz x % ,fi r., _ . ,. r < Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud DateTme: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 11:30 4.00 EVAL P DECOMP PJSM, PU HES 7" CHAMP PACKER ON 2 7/8" L -80 EUE TBG FROM DERRICK - HES REP, WSL, TOOL PUSHER IN ATTENDANCE. - RIH WITH HES PACKER ON 2 7/8" TBG FROM DERRICK TO 5900' MD. 11:30 - 12:00 0.50 EVAL P DECOMP PJSM, SET AND TEST 7" CSG. - OBTAIN PARAMETERS. PU WT. = 65K INCLUDING 40K TOP DRIVE. WT. SO WT. = 63K. -SET CHAMP PACKER @ 5927' MD. PER HES REP. - DISCUSSED CHARACTERISTICS OF THE HOLE IN TBG @ 4158' MD, WITH TOWN RWO TEAM. - TEST PRESSURE WILL BE CHANGED ON 7" __MIT-IA TO 1,500`PSI. 12:00 - 14:00 2.00 EVAL P DECOMP P,1SM, MIT -IA, 7" L -80 26# CSG BY 2 -7/8" EUE ANNULUS. - - PUMPED 17 STKS ( 1.4 BBLS) TO / 1,500 PSI FOR 30 CHARTED MINUTES. - DISCUSS W/ TOWN RWO ENGINEER. MAINTAIN CONTINUOUS HOLE FILL WITH KWF DURING TEST. - MIT -IA TEST, MEETS BP STP CRT- AK -10 -45 CRITERIA. - RECEIVED PERMISSION TO PROCEED FROM WTL. - BLEED OFF PRESSURE. " 0 " READING. BLED BACK 1 BBLS. - WSL VERIFIED NO TRAPPED PRESSURE BELOW PACKER. - FILLED TBG WITH KWF. RELEASED CHAMP PACKER PER HES REP. - MONITOR WELL FOR 10 MIN. WITH CONTINUOUS HOLE FEED. - SEE ATTACHMENTS 14:00 - 14:30 0.50 EVAL P DECOMP PJSM, POH WITH CHAMP PACKER;, - WSL / DRILLER CONFIRM ANNULAR IS OPEN. - BLOW DOWN AND R/D ALL CIRC LINES AND HEAD PIN. - PREP FLOOR AND PIPE SHED TO LD 2 7/8" EUE TBG 1X1 TO PIPE SHED. COMPLETE 'WELL WORK TRANSFER PERMIT WITH PAD OPS FOR MPI -19. 14:30 - 19:30 5.00 CASING P DECOMP PJSM, POOH WITH HES CHAMP PACKER ON 2 7/8" EUE TBG. FROM 5927' MD. - PU WT.= 65K INCLUDING 40K TOP DRIVE WT. SO WT. = 63K. - LD 2 -7/8" TBG 1X1 TO PIPE SHED TO BE NORM TESTED AND SENT OUT. RWO AND CTD SUPERINTENDENT VISITED THE RIG. 19:30 - 20:00 0.50 CASING P DECOMP PJSM TO LAY DOWN CHAMP PACKER -UD 7" CHAMP PACKER PER HES -ALL ELEMENTS INTACT Printed 2/18 /2013 3:01:21 PM • Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date!me: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 21:30 1.50 WHSUR P DECOMP LAY DOWN RUNNING TOOL -SPOT SWS SLICK LINE UNIT -CLEAN AND CLEAR RIG FLOOR 21:30 - 00:00 2.50 EVAL P DECOMP PJSM W/ SLICKLINE AND RIG CREW ON RIG UP OF FULL PRESSURE CONTROLAND EQUIPMENT - INSTALL DUTCH RISER -BRING SLICKLINE BOPS, LUBRICATOR, ETC TO RIG FLOOR CONTINUE HOLE FILL AT 22 BPH W/ 8.5 PPG SEAWATER 783 BBL LOST FOR THE DAY - MAINTAIN HOLE FEED AT 20 -27 BPH WITH 8.5# SEAWATER. 2/8/2013 00:00 - 03:00 3.00 EVAL P DECOMP RIG UP SWS SLICKLINE WITH FULL PRESSURE CONTROL - RIG UP SLICKLINE PRESSURE CONTROL - M/U SLICKLINE EQUIPMENT - M/U PDS CALIPER - SURFACE TEST PDS 7" CALIPER - PRESSURE TEST LUBRICATOR 250 PSI LOW AND 1500 PSI HIGH FOR 5 MINS EACH TEST MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER AT 20 BPH. 03:00 - 03:30 0.50 EVAL P DECOMP_ RUN IN HOLE WITH PD S CALIPER - RIH W/ CALIPER ON SWS SLICKLINE TO 1100' MD 03:30 - 06:00 2.50 EVAL P DECOMP AT SURFACE WITH PDS CALIPER - WAIT 15 MINS TO ALLOW CALIPER ARMS TO CLOSE BEFORE PULLING TOOL TO FLOOR - PJSM WITH SWS, PDS, AND RIG TO DISCUSS BREAKING DOWN TOOLS AND PRESSURE CONTROL EQUIP. - R/D SLICK LINE EQUIPMENT. 06:00 - 07:00 1.00 EVAL P DECOMP PJSM, LD DUTCH RISER SYSTEM TO PIPE SHED. - PULL WEAR RING. CLEAN AND CLEAR FLOOR OF LOGGING EQUIPMENT. 07:00 - 09:00 2.00 RUNCOM P RUNCMP RU TO RIH WITH 2 7/8" CR 13 VAMTOP TBG ESP COMPLETION. - HANG ESP SHEAVE IN DERRICK PULL ESP CABLE THRU SHEAVE TO FLOOR. - RU TORQUE TURN HANDLING EQUIPMENT FOR CR 13 TBG. RUNCMP PJSM 09:00 12:00 3.00 RUNCOM P U PJSM, P/U ESP PUMP AND MOTOR ASSY - LOAD OIL AND SERVICE MOTOR - TIE IN ESP CABLE AND CHECK FOR CONDUCTIVITY - LOSSES TO WELL LAST 12 HOURS = 283 BBLS KWF. Printed 2/18/2013 3:01:21PM .., Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 15:00 3.00 RUNCOM P RUNCMP RUN 2 -7/8" 6.4 #, CR13 VAMTOP TBG ESP COMPLETION - P/U TUBING 1X1 FROM PIPE SHED - WITH DOYON CASING TORQUE TURN / COMPENSATOR SYSTEM. - USE JET LUBE SEAL GUARD PIPE DOPE - OPTIMUM M/U 1850 FT /LB TORQUE. DERRICK STABBING BOARD USED. - RUN PER PROGRAM. - WITH ESP CABLE AND CANON CLAMPS. - CHECK ESP CABLE CONDUCTIVITY EVERY 2000' - M/U FOSVAND FLUSH ESP PUMP EVERY 2000' MAINTAIN CONTINUOUS HOLE FILL 20 -27 BPH WITH KWF. 15:00 - 16:00 1.00 RUNCOM P RUNCMP PJSM, WEEKLY CREW CHANGE FROM TOWN - PERFORM PRE -TOUR CHECKS - INSPECT STABBING BOARD AND TOP DRIVE. - WSL DISCUSS WELL CONTROL WITH DRILLER, MOTOR MAN AND PIT WATCHER. DRILLER AND CREW CHECK PIPE COUNT AND FLAGS ON PIPE. RIH FROM SURFACE TO 950' MD. - CHECK ESP CABLE CONDUCTIVITY @ 950' MD. 16:00 - 00:00 8.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH 2_7/87 VAM TOP_CR 13 TBG FROM 950' MD. - CHECK ESP CABLE CONDUCTIVITY EVERY 1000' - M/U FOSVAND FLUSH ESP PUMP EVERY 2000' AT 1 BPM / 900 PSI. - FLUSHED PUMP WITH 5 BBLS SEAWATER AT 1 BPM AND 900 PSI AT 4000' MD CONTINUAL HOLE FILL OF 8.5 PPG SEWATER @ 24 BPH 24 HR FLUID LOSS = 524 BBLS 2/9/2013 00:00 - 03:30 3.50 RUNCOM P RUNCMP RUN IN HOLE WITH 2 7/8 13CR VAM TOP TUBING AND ESP ASSEMBLY - RIH FROM 4291' MD - WITH DOYON CASING TORQUE TURN / COMPENSATOR SYSTEM. - USING JET LUBE SEAL GUARD PIPE DOPE - OPTIMUM M/U 1850 FT /LB TORQUE. - DERRICK STABBING BOARD USED. - INSTALLING ESP CABLE AND CANON CLAMPS. - CHECK ESP CABLE CONDUCTIVITY EVERY 1000' - M/U FOSVAND FLUSH ESP PUMP' AT 1 BPM / 900 PSI. @ 5400' MD CLAMPS INSTALLED - CANNON CLAMPS= 102 - PROTECTOLIZERS= 6 -FLAT GUARDS= 5 Printed 2/18/2013 3:01:21 PM r� r'�' ' ' } r : ` '` %s '' s nr r'. ✓ .f #:. r`f �������w� �- .- „:.,,�,:�.?,F `��,..�.. ,' � , •���*'.,.,. �';�_ .<.,_ .'�.r, .r. f,^^'.✓ ....a. �.. _a�, .:.:. �. w,. r_.. ,�"s �':...���,��-�"a-„.�.� �,:e ac. �.:, ,a � -;`:� i�.��e<:,: oe. � .,,'... ....3 ..,. Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Daterme: 8/9/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 05:30 2.00 RUNCOM P RUNCMP MAKE UP FMC 2 7/8” x 1T" HANGER - M/U 2 7/8" EUE LANDING JOINT W/ FOSV TO HANGER - PUW= 75K , SOW= 67K - INSTALL PENETRATOR AND BLANK IN HANGER - TERMINATE ESP CABLE TO PENETRATOR 05:30 - 06:00 0.50 RUNCOM P RUNCMP PJSM, LANDING 11" TBG HANGER. FMC REP, WSL, CENTRALIFT REP IN ATTENDANCE. - LAND HANGER PER FMC REP. PU WT = 75K, SOW = 67K. - INCLUDING 40K TOPDRIVE WT. _ - RILDS PER FMC REP. LD LANDING JOINT. 06:00 - 07:30 1.50 WHSUR P RUNCMP PJSM, INSTALLAND TEST TWC. - FMC REP INSTALLED 2" Type "H "BPV. - PERFORM ROLLING TEST FROM BELOW TWC FOR 10 CHA' ' V V. • B. - 25 BBLS TO CATCH FLUID. - 9 BPM = 500 PSI, 92 BBLS PUMPED AWAY - TEST FROM ABOVE TWC, 250 / 3500 PSI, 5 CHARTED MIN. PASSED. 07:30 - 09:00 1.50 BOPSUR P RUNCMP PJSM, R/D LONG BAILS AND TORQUE -TURN EQUIPMENT & N/D BOPE. - LAY DOWN LONG BAILS TO PIPE SHED. - N/D 13 5/8" BOPE - REMOVE FLOW NIPPLE AND TURNBUCKLES. - LOTO KOOMY AND REMOVE HOSES. - SET BACK BOP STACK 09:00 - 12:00 3.00 WHSUR N WHDTRE ORIGINAL 11" FMC TBG HEAD ADAPTER NOT COMPATIBLE W(TF[NEWI SGBATEGERt P.ENETRATERS.. - ORIGINAL ADAPTER HAS SMALL STYLE HEAT TRACE PORT. - NEWADAPTER HAS LARGE STYLE HEAT TRACE PORT. - WAIT ON CORRECT ADAPTER FLANGE TO ARRIVE FROM PBU WAREHOUSE. WELL CONTROL DRILL: - WSLAND TOOLPUSHER HELD A SCENARIO BASED DRILL: - WITH THE BOP SET BACK FOR TRANSPORT WITHOUT TREE INSTALLED. AAR: - DRILLER SAID, PJSM ON THE SPOTAND ASSIGN ALL CREW MEMBERS A TASK - HAND PLACEMENT WHEN RESETTING BOP STACK - INSTALL NEW API RING GASKET. LOSSES TO WELL LAST 12 HOURS = 363 BBLS KWF. 12:00 - 14:00 2.00 WHSUR P WHDTRE PJSM, N/U 2- 9/16" CAMERON PRQ„„[ALTIQN,_ TREE /ADAPTER. - FMC REP CLEAN AND INSPECT TBG HANGER VOID. - M/U TREE AND ADAPTER PER FMC. - N/U ADAPTER TO TBG SPOOL. Printed 2/18/2013 3:01:21 PM • ...,, uf` .. t ,.. „... .. ,. =w . ,.... . Common Well Name: MPG -14 AFE No Event Type: WORKOVER (WO) Start Date: 2/5/2013 End Date: 2/9/2013 X4- 00X69 -E:RIG (1,560,000.00 ) Project Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 8/9/2001 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©63.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 15:00 1.00 WHSUR P WHDTRE - FMC REP PRESSURE TEST ADAPTER VOID - 250 PSI FOR 5 CHARTED MINUTES, PASSED. - 5000 PSI FOR 30 CHARTED MINUTES. PASSED. - WITNESSED BY WSL. 15:00 - 16:30 1.50 WHSUR P WHDTRE PRESSURE TEST TREE. - 2- 9/16" 5M CAMERON TREE TESTED TO 250 / 5000 PSI WITH DIESEL FOR 5 CHARTED MIN. EACH. PASSED. 16:30 - 17:00 0.50 WHSUR P WHDTRE HELD A "BP ONE TEAM" MEETING WITH MILNE POINT WELL SUPPORT, FMC REP, - WSL, TOOLPUSHER, PIPE FITTER AND RIG CREW. - DISCUSSED PRODUCTION TREE ORIENTATION TO ENSURE CORRECT ALIGNMENT FOR FLOW LINE TIE -IN. - REDUNDANT SYSTEMS TO BE USED FOR TREE ORIENTATION PRE AND POST RWO. 17:00 - 21:30 4.50 WHSUR P WHDTRE PJSM,.P /U DSM LUBRICATOR. R/U TEST HOSES. - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 -- CHARTED MIN. EACH. - PULL TWC --LUBRICATOR ICED UP, LAY DOWN LUBRICATOR - STEAM LUBRICATOR AND WELL HEAD - TEST LUBRICATOR TO 250 / 3500 PSI FOR 5 CHARTED MIN. EACH. - INSTALL 2" TYPE 'H' BPV. LD LUBRICATOR PERl6SM REPS. 21:30 - 22:00 0.50 WHSUR P WHDTRE PERFORM ROLLING TEST FROM BELOW BPV - LINE UP SECONDARY KILL LINE - PUMP 7 BPM AT 300 PSI. 0 PRESSURE ON TREE, CHART FOR 10 MINS 22:00 - 00:00 2.00 WHSUR P WHDTRE SECURE TREE AND CELLAR - BLOW DOWN & RIG DOWN LINES - INSTALL FLANGE AND PRESSURE GAUGE ON ANNULUS - CLEAN PITS - RIG DOWN MUD MANIFOLD, PREP FOR RIG MOVE, BRIDLE UP - RELEASE RIG AT 2400 HRS FOR MOVE TO MPI -19. LOSSES TO WELL LAST 24 HOURS = 562 BBLS KWF Printed 2/18 /2013 3:01:21 PM Tree; 2- 9/16" - 5M FMC MPG -14 KB - SL = 63' (NABOBS 27E) Wellhead: 11" 5M Gen 6 w • KB - GL = 30' ( NABOBS 27E) EUE 8rd top and btm.thread Tubing Hanger with C L I W "H" BPV profile NOTE: 4ES Can Not work on this well w/o p G-16`s well house being moved back 24" or 20 ", 92 #/ft H -40 Welded 112' completely removed, Camco 2 -7/8" x 1" 139' sidepocket KBMM -2 GLM Tam Ported Collar 1011' Q 2 7/8" 6.4 ppf., Cr13 Vam Top Tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) Camco 2 -7/8" x 1" 7" 26 ppf, L -80, Btc -mod production casing sidepocket KBMM -2 GLM 5,688' ( drift ID = 6.151", cap. = 0.0383 bpf) 2 -7/8" XN nipple 5,831' (ID 2.205 ") Tandem Pump 79 -P17 Model PMSXD 1:1 5,875' KOP @ 300' 18 -P75 Model PMSXD 1:1 Max wellbore Angle: 63° @ 3500' MD Gas Separator 5,894' 60 degrees + past 2800' MD GRSFTX AR H6 Hole angle trough perfs = 90 deg. Tandem Seal Section GSB3DBUT / GSB3DBLT 5,899' Model KMH Motor 5,912' 114hp / 2330v / 30 amp mos PumpMate XTO O w/6 fin Centralizer 5,923' SacrificialAnode 7" Halliburton 23 -29# "VTL" Versa - trieve Packer 6077' 5 1/2" LTC x 4 1/5" BTRS " X -O „ • „• , • ,• = 30 of 4 -1/2” LLP Screen (6097'- 6127`) — 12/10 Resin Coated 0.020 Gauge N SAND PERFORATION SUMMARY Size SPF Interval (TVD) — 30' of 4 -1/2" LLP Screen (6178' - 6208') 3 3/8" 6 6110' - 6130' 3988' - 3996' = ,. — 12/10 Resin Coated 0.020 Gauge 3 3/8" 6 6190' - 6210' 4020' -4028' 3 3/8" 6 6250' - 6270' 4045' - 4053' 30` of 4 -1/2" LLP Screen (6237' - 6267`) All shots fired, perf jets at 60 deg phasing = � ,.? = 12/10 Resin Coated 0.020 Gauge ■ 7" Baker "SLZXP" Packer (4.5" ID) 6286' 4 -1/2" Halliburton XN Nipple (3.725" ID) @ 6318' WLEG 6329' Baker Hook Wall Hanger above 7" 6499' 6 1/8" Hole td t 9430' Window in 7" Casing @ 6508` - 6520' Well inclination @ window = 74 deg. OA Horizontal 70 jts. of Pre Drilled 4 1/2" Slotted Liner 12.6# L -80 IBT (6,570' - 9,304') Baker Hook Wall Baker 4 1/2" Packoff Bushing 9304' Baker Tie Back Sleeve 7028' Hanger below 7" 6520' 4 1/2" Guide Shoe 9348' Baker ZXP Liner Top Packer 7037' Baker Down Swivel -up lock sub 6522' Baker 5x7" HMC Liner Hanger 7042' Halliburton Float Collar 7046' 61/8'° Hole td ® 9419' Halliburton Float Shoe 7132' OB Horizontal 57 jts of pre - drilled 4 1/2" slotted liner 12.6# L -80 IBT (7137' - 9362') Baker 4 1/2" Packoff Bushing 9362' 4 1/2" Guide Shoe 9405' DATE REV. BY COMMENTS MILNE POINT UNIT 8/14/01 B. Hasebe Nabors 27E Drill Multilateral WELL G -1 4 9/25/01 B. Hasebe Nabors 4ES ESP Completion 7/24/08 REH Nabors 3S ESP changeout API NO: 50- 029 - 23031 -00 6/24/08 MOM Nabors 4 -es ESP RWO G -14L1 API NO: 50- 029 - 23031 -60 2/10/13 B. Bixby Doyton 16 ESP and Tbg. Changeout BP EXPLORATION (AK) ` STATE OF ALASKA -~~~~, AKA OIL AND GAS CONSERVATION COICA~IISSION REPORT OF SUNDRY WELL OPERATIQNS 1. Operations Performed: ^ Abandon ®Repair Well , ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-134' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23031-60-00 ' 7. KB Elevation (ft): 62 93' 9. Well Name and Number: MPG-14L1, 8. Property Designation: 10. Field /Pool(s): ADL 315848 ~ .Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9400 - feet true vertical 4150 _ feet Plugs (measured) None Effective depth: measured 9400 feet Junk (measured) None true vertical 4150 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 6473' 7" 6508' 4136' 7240 5410 Intermediate Production Liner 2849' 4-1/2" 6499' - 9348' 4133' - 4150' 8430 7500 ~;~~~ s~~ ~ ~- Zoos Perforation Depth MD (tt): Perfsllo'-sz~a,sioKeds57a-sso4' Perforation Depth TVD (tt): Perf sss2' - 4056', SloKed 4149' - 4151' 2-7/8", 6.5# L-80 5919' Tubing Size (size, grade, and measured depth): 4-1 /2"_ 126# - ' Packers and SSSV (type and measured depth): 7" Halliburton 23 - 29# 'VTL' Versa-trieve Packer and a 6077' 7" Baker'SLZXP' Packer 6286' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 280 0 Subsequent to operation: 272 72 419 240 217 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared ey Name/Number: e - l~ Sig ure Phone 564-4750 Dat . Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~"~~ ~~~°~ j ~ Submit Original Only ~ ~~~ Tree: 2-9/16" - 5M FMC Wellhead: 11" 5M Gen 6 w/•8" EUE 8rd top and btm.thread Tubing Hanger with CIW "H" BPV profile 20", 92 #/ft H-40 Welded 112' M P G ~ ~ `t\~1 ~B - GL = 30' (NABORS 2 E) NOTE: 465 Can Not work on this well w/o G-16'5 well housa being moved back 24' or completely removed. Camco 2-7/8" x 1" 140' sidepocket KBMM-2 GLM Tam Ported Collar 1011 ` 2 7/8" 6.5 ppf, L-80, 8rd, EUE production tubing Camco 2-7/8" x 1" 74' ( drift ID = 2.347", cap. = 0.00592 bpf) sidepocket KBMM-2 GLM 5,6 7" 26 ppf, L-80, Btc-mod production casing 0383 b f) ift ID = 6 151' ca = 0 d i - 2-7/8" XN nipple 825` 5 p , p. . r . ( - (ID 2.205") , Tandem Pump ` 79-P17 Model PMSXD 1:1 5,867 ' 18-P75 Model PMSXD 1:1 KOP ~ 300 Gas Separator 5,885' Max wellbore Angle: 63° ~ 3500' MD 0024043887 60 degrees + past 2800` MD Hole angle trough perfs = 90 deg. Tandem Seal Section GSB3DB UT/LT SB/SB PFSA 5,891 Model KMH-A Motor 5,904' 114hp / 2330v / 30 amp PumpMate XTO 5,919` w/6 fin Centralizer 7" Halliburton 23-29# "VTL" Versa-trieve Packer 6077' 5 1/2" LTC x 4 1/5" BTRS " X-O 30' of 4-1/2" LLP Screen (6097'-6127`) 12/10 Resin Coated 0.020 Gauge N SAND PERFORATION SUMMARY Size SPF Interval (TVD) 33/8" 6 6110' - 6130' 3988' - 3996' 3 3/8" 6 6190' - 6210' 4020' -4028' 3 3/8" 6 6250' - 6270' 4045' -4053' All shots fired, perfjets at 60 deg phasing Window in 7" Casing @ 6508` - 6520' Well inclination @ window = 74 deg. Baker Tie Back Sleeve 7028' Baker ZXP Liner Top Packer 7037' Baker 5x7" HMC Liner Hanger 7042` Halliburton Float Collar 7046` Halliburton Float Shoe 7132' DATE REV. BY COMMENTS 8/14/01 B. Hasebe Nabors 27E Drill Multilateral 9/25/01 B. Hasebe Nabors 4ES ESP Completion 7/24/08 REH Nabors 3S ESP changeout 8/24/08 MOM Nabors 4-es ESP RWO 30' of 4-1/2" LLP Screen (6178' - 6208') 12/10 Resin Coated 0.020 Gauge 30' of 4-1/2" LLP Screen (6237' - 6267') 12/10 Resin Coated 0.020 Gauge 7" Baker "SLZXP" Packer (4.5" ID) 6286' 4-1/2" Halliburton XN Nipple (3.725" ID) ~ 6318' WLEG 6329' Baker Hook Wall Hanger above 7" 6499' OA Horizontal 70 jts. of Pre-Drilled 4 1!2" Slotted Liner 12.6# L-80 IBT (6,570' - 9,304') Baker Hook Wall Baker 4 1/2" Packoff Bushing 9304' Hanger below 7" 6520' 4 1/2" Guide Shce 9348' Baker Down Swivel-up lock sub 6522' OB Horizontal 57 jts of pre-drilled 4 1/2" slotted liner 12.6# L-80 IBT (7137` - 9362') Baker 4 1/2` Packoff Bushing 9362' 4 1/2" Guide Shce 9405' MILNE POINT UNIT WELL G-14 API NO: 50-029-23031-00 BP EXPLORATION (AKL Page 1 of, l . • Well: MPG-14 Well History Well Date Summary MPG-14 7/23/2008 INSTALL DPSOV IN GLM #2 IN PIPE SHED MPG-14 7/24/2008 (Post Rig Freeze Protect TBG and IA) T/1/0=0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. Awgers continued on 07-25-08 ~I MPG-14 7/25/2008 (Freeze Protect TBG and IA) T/I/0= 0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP= 0/0/0 swab=closed/ wing=closed/ ssv=closed/ master=closed/ IA open to gauge. MPG-14 7/25/2008 The Well Support Techs rigged up and set the foundation, installed the flowlines and set the wellhouse. They then removed the back pressure valve and leak tested the flowlines to 1150 psi. NOTE: The leak test was GOOD and the BPV was left OUT... MPG-14 7/31/2008 ***ARRIV ON LOC WELL S/I *** DRIFT TUBING*** PULLED 1"BEK-DPSOV FROM 172' MD, SET NEW 1"BEK-DPSOV DRIFTED TO RESTRICTION AT 5275' SLM W/ 2.31" GAUGE. ***JOB CANCEL FOR HIGH WIND `** MPG-14 8/1/2008 *** WELL SI ON ARRIVAL *** RWO RAN 2.15" CENT, 2" BAILER TO 5,943' SLM. RECOVERED 1 TBS. SCALE RAN 2.5" HOLE FINDER TO RESTRICTION AT 5300' SLM. ATTEMPTED TO PT TUBING AT 5300, 3000', AND FINALLY HAD TEST AT 2000' 4300' , RE-RUNNING HOLE FINDER TO NARROW DOWN LEAK AT REPORT TIME ***CONTINUE ON 8/1/08 *** MPG-14 8/1/2008 Assist S-line Job Postponed. MPG-14 8/1/2008 Assist Slickline T/I/0=100/140 Continued on 08-02-08 AWGRS. Pumped 19 bbls of 50/50 Diesel and crude mixture down tubing to assist in finding leak. MPG-14 8/2/2008 ***CONTINUE FROM 8/1/08*** DRIFT TUBING RAN HOLE FINDER, NARROWED LEAK DOWN TO BETWEEN 2137' AND 2000' SLM. DRIFTED W/ 2.15" CENT, S-BAILER TO ESP AT 5,945' SLM RAN PDS CALIPER TUBING FROM 5,935' TO SURFACE ~ 50FPM ***TURN WELL OVER TO DSO *** , MPG-14 8/2/2008 Assist Slickline Continued from 08-01-08 AWGRS. Pumped 29 bbls of 50/50 Dead Crude and Diesel mixture down tubing while slickline ran D&D hole finder. FWHP=100/140 Left while slickline still on well. MPG-14 8/10/2008 *** WELL S/I ON ARRIVAL *** (rwo prep) PULLED 1" BK-DGLV FROM STA# 1 ~ 5769' MD, POCKET LEFT OPEN PULLED 1"BEK-DPSOV FROM STA# 2 ~ 172' MD, SET 1" BK-DGLV SET BPV ***WELL S/I ON DEPART*** MPG-14 8/16/2008 Well Techs said BPV was set, then demobe well house flow lines and foundation .All blinds are TO spec. MPG-14 8/21/2008 Standby for rig to move off well. Job postponed. MPG-14 8/21/2008 (Post RWO Freeze protect TBG and IA) T/1= 0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP= 0/0 Valve position =swab-closed /wing-closed / ssv-closed /master-closed / IA and OA open to gauges. MPG-14 9/2/2008 ASRC Unit #5, 6 hour test **job complete** - 2 200 14 9/ / 8 MPG ASRC Unit #5 divert well, stabilize **job in progress** , Note: tried to test MPG-02, pump failure, tried to test MPG-16, divert wilt not open. 2nd WSR on MPG-14 for 9/2/08. MPG-14 9/3/2008 ASRC Unit #5, 6 hour test **job complete`* Print Date: 9/18/2008 Page 1 of 1 BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: WORKOVER Start: 8/17/2008 End: 8/21/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/18/2008 03:00 - 06:30 3.50 RIGD P PRE R/D rig & suppoert equip. Scope down & Lower derrick. 06:30 - 08:00 1.50 MOB P PRE Move Rig sub & pits From NPI-15 to MPG -14. 08:00 - 09:00 1.00 RIGU P PRE Lay out herculite & matting boards. Attempt to spot in rig sub. no success. 09:00 - 10:30 1.50 MOB P PRE Move camp pipe shed from MPI-15 to MPG-14. spot camp& level camp. 10:30 - 12:30 2.00 RIGU N WAIT PRE Unable to spot in rig. Re-drilled well is on 25' center. Nedd to remove adjacent well house. Wait on wellhouse removal. skid well house back - 18" to allow Rig to spot over wellhead. 12:30 - 14:00 1.50 RIGD P PRE Spot in rig sub, pipe shed & pit modules. Begin R/U same. 14:00 - 15:00 1.00 RIGU P PRE Raise & scope up derrick. 15:00 - 16:30 1.50 RIGU P DECOMP R/U lines to tree & tiger tank. Install 2nd annulus valve. Begin taking on seawater. Accepted rig ®15:00 hrs. 16:30 - 17:30 1.00 WHSUR P DECOMP P/U lubricator & test to 500 psi. Pull BPV. UD lubricator & BPV. AOGCC rep John Crisp waived witness ~ 17:15 hrs. 17:30 - 19:00 1.50 KILL P DECOMP RU lines to tree & tiger tank. P!T lines to 3500 psi. Test lines to tiger tank to 500 psi. 19:00 - 00:00 0.00 KILL P DECOMP Initial SIP's = 110 psi on tubing, 130 psi on IA. Bleed pressures to 0 psi thru choke to tiger tank, bled all gas. Circulate 50 bbls down tubing ~ 5 BPM / 680 psi, taking gas returns thru choke. Crude returns started ~ 40 bbls into circulation. Shut choke and bullhead 30 bbls down tubing ~ 4 BPM / 560 psi. Open choke & circulate taking returns thru choke to tiger tank ~ 5 BPM / 800 psi returned crude & gas to tank. Reduce rate to 3 BPM / 300 psi 2 + annulus volumes and well did not clean up (mix of thick crude, gas & SW). Shut down and monitor well for 30 min. Tubing & IA building gas 1 psi /min. Circulated 452 bbls and lost 259 bbls to formation. Fluid weight off truck 8.42 ppg / 110 degree. 8/19/2008 00:00 - 02:00 2.00 KILL P DECOMP Take on more fluid to pits of 115 degree - 8.43 ppg produced water. Bullhead 20 bbls down tubing ~ 5 BPM / 250 psi. Bullhead 300 bbls down IA ~ 6 BPM / 530 psi. Monitor well for 20 min. Tubing & IA on vacuum. -Total fluid bullheaded: 350 bbls 02:00 - 02:30 0.50 WHSUR P DECOMP Dry rod in TWC. P/T from above to 3500 psi for 10 min - charted. P!T rolling test to 500 psi from below for 10 min - charted. 02:30 - 04:00 1.50 WHSUR P DECOMP ND tree. 04:00 - 06:00 2.00 BOPSU P DECOMP NU BOPE. RU test lines. 06:00 - 08:00 2.00 BOPSU P DECOMP Finish N/U BOPE. 08:00 -12:00 4.00 BOPSU P DECOMP R/U test equip. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Used 2 7/8" test jt. No failures. BOP test witnessing waived by John Crisp w/ AOGCC. 12:00 - 13:00 1.00 WHSUR P DECOMP P/U lubricator & test to 500 psi. Pull TWC. UD TWC & lubricator. 13:00 - 14:00 1.00 PULL P DECOMP Circulate bottoms up. Pump 5 BPM ~ 800 psi. Lost 65 bbls during circulation. Pumped total of 221 bbls. 14:00 - 15:00 1.00 PULL P DECOMP M/U landing jt. BOLDS. Pull hanger to floor. Disconnect ESP cable. UD hanger & landing jt. 15:00 - 16:30 1.50 PULL P DECOMP POH UD 2-7/8"tubing to 1st 2-7/8" x 1" GLM while stringing ESP cable over sheave wheel and through elephant trunk to cable spooler. Secure ESP cable to empty spool in spooler. 16:30 - 18:00 1.50 PULL P DECOMP POH laying down 2-7/8" tubing 1 x 1 through pipe shed and Printed: 9/8/2008 11:11:53 AM BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: WORKOVER Start: 8/17/2008 End: 8/21/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2008 Rig Name: NABOBS 4ES Rig Number: Date From- To Hours. Task Code NPT Phase Description of Operations 8/19/2008 16:30 - 18:00 1.50 PULL P DECOMP spooling ESP cable. OOH w/ 56 jts. 18:00 - 18:30 0.50 PULL P DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 00:00 5.50 PULL P DECOMP Finish to POOH & UD 2 7/8" ESP completion. Spool up ESP cable. Use double displacement method while POOH. Recovered 178 jts of 2 7/8" tubing, 2 GLM assys, "XN" nipple & 2 -10' pups. No holes were noted in tubing. 8/20/2008 00:00 - 02:30 2.50 PULL P DECOMP Break down & inspect ESP. Had -5' of sand in 10' pup above pump. Top of pump had was sand packed. No damage to pump was noted. Plan is to Change out pump section & seal seaction of ESP. New cable will also be used. Notified town engineer & Milne Pt Well ops suprv of sand in tubing. Elected not to make clean out run. 02:30 - 03:30 1.00 PULL P DECOMP Hold weekly safety meeting w/ all hands. 03:30 - 05:00 1.50 PULL DECOMP Clear & Clean rig floor. Change out reels in spooling unit. 05:00 - 08:30 3.50 BUNCO RUNCMP Re-dress & service ESP. Connect cable & meg same. Install flat guards and protectorlisers on motor lead cable. 08:30 - 09:30 1.00 BUNCO RUNCMP RIH with 2-7/8" ESP completion picking up pipe 1 x 1 from pipe shed and attaching Lasalle cable clamps every other tubing coupling. Meggered ESP cable and filled tubing every 2000'. Filling hole while RIH with 1 %KCI at double steel displacement plus 1-Bbl. per every 1000' of ESP cable ran. 09:30 - 10:30 1.00 BUNCO RUNCMP Close in well and hold safety standdown with all crew members. Verified review of all safety incidents detailed in recent "Safety Focus" dated 8/19/2008. Reviewed 8 Golden Rules with emphasis on Vehicle Safety. Reviewed rig scorecard with all crew. 10:30 - 17:30 7.00 BUNCO RUNCMP Monitor and open well. Commence RIH with 2-7/8" ESP completion picking up pipe 1 x 1 from pipe shed and attaching Lasalle cable clamps every other tubing coupling. Meggered ESP cable and filled tubing every 2000'. Filling hole while RIH with 1 %KCI at double steel displacement plus 1-Bbl. per every 1000' of ESP cable ran. Ran total of 185 jts. Bottom of centralizer G~ 5917'. Discharge head ~ 5867'. XN Nipple ~ 5825'. GLM w/ Dummy ~ 5674'. GLM w/ DOSV ~ 140'. Used 5 Protectolizers, 3 Flat Guards & 90 LaSalle clamps. 17:30 - 18:00 0.50 BUNCO RUNCMP M/U landing jt & hanger. 18:00 - 21:00 3.00 BUNCO RUNCMP Make field splice. Install penetrator & attach to ESP. Pump thru ESP 1 BPM 4~ 1000 psi. 21:00 - 21:30 0.50 BUNCO RUNCMP Land ESP completion. UD landing jt. P/U Wt = 43K, S/O Wt = 35K. 21:30 - 23:00 1.50 WHSUR P RUNCMP Dry rod TWC into hanger. Pressure test from top w/ 3500 psi for 10 min. Test from below 4 BPM G~ 100 psi. for 10 min. Charted test. Tighten 2 leaky lock down screws. Blow down & R/D lines. 23:00 - 00:00 1.00 BUNCO RUNCMP Hold 1 hr safety stand down. Revied latest incidents, & 8 Golden Rules. 8/21/2008 00:00 - 02:30 2.50 BOPSU P RUNCMP Drain stack. N/D BOPE. 02:30 - 04:30 2.00 WHSUR P RUNCMP WU tree & adapter flange. Test hanger void & tree to 5000 psi, Ok. Made final check on ESP. 04:30 - 06:00 1.50 WHSUR P RUNCMP P/U lubricator & test to 500 psi, Ok. Pull TWC. Install BPV. Pressure test BPV, 4 BPM ~ 100 psi for 10 min. charted same. Secured rtree & cellar. RELEASE RIG ~ 0600 hrs. Punted: 9/8/2008 11:11:53 AM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc Permit to Drill 2011340 MD 9400 J TVD DATA SUBMITTAL COMPLIANCE REPORT '10/312003 Well Name/No. MILNE PT UNIT SB G-14L1 Operator BP EXPLORATION (ALASKA) INC 4147 ~ Completion Date 9/18/2001 f Completion Status 1-OIL Current Status 1-OIL AP) No. 50-029-23031-60-00 UIC N REQUIRED INFORMATION Mud Log N._9o Samples N._g_o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset TiI~D~ Med/Frmt N~naber Name C ,,/10418 iD~ ....... ............... Log Log Run Scale Media No (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments Rpt 1-6 ..... Directional Survey FINAL ~~`~~~~`~`~~~~~~~~~~`~~~~~~~~~~~~~~~~~~~~~~~~`~~~~~`~~~~~`~~~~~~~~~~~~~~~~~~~~~~~~~~~`~~~`~`~ Directional Survey FINAL 114 940O Open 11/2/2001 Open 9/21/2001 Directional Survey Open 9/21/2001 Directional Survey Well Cores/Samples Information: Name Start Interval Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Daily History Received? Formation Tops YfN YIN Compliance Reviewed By: Date: --~'~-~ ~ ' ~ ~Er5 ~ 10/30/2001 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 1580 Company Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Loc) Description Date CD Sepia BL ~.~-~ ~,~153 ~ cD.,~, oo/~o/o~ ~ MPG-14 21423 MD VISION RESISTIVITY 09/20/01 1 1 MPG-14 21423 TVD VISION RESISTIVITY 09/20/01 1 1 MPG-14LIc-~0J- I~"~f 21424 CDR,IMP 09/25/01 1 MPG-14 L1 21424 MD VISION RESISTIVITY 09/25/01 1 1 MPG-14 L1 21424 TVD VISION RESISTIVITY 09/25/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Cent Petrotectnical Data I _CEIVED 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 NOV 0 ?_ 2001 Date Delivered: Alaska Oil & Gas ~s. Comm~°n ~omge Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al-tN: Sherrie Received by~~,~ ~~.f~~/ STATE OF ALASKAt,.' ALASKA OIL AND GAS CONSERVATION COMMISSION 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. 201-134 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23031-60 4. Location of well at surface 'i" 't';':!!,?..:~':T?]~"'~ 'LOCA'~iONE,i~"- 9. Unit or Lease Name 2015' NSL, 3446' WEL, SEC. 27, T13N, R10E, UM i L:/-' F~--- Milne Point Unit At top of productive interval i --~:/?'_~/ $~_ _ _ .',~ 4605'At totalNSL'depth1618' WEL, SEC. 28, T13N, R10E, UM !,.i :.,' ;: --,,_~., .~.."";:" ' i ~-'~ 10. Well Number 2114' NSL, 1129' WEL, SEC. 21, T13N, R10E, UM .... : MPG-14L1 ........................ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 62.93' ADL 315848 12. Date Spudded8.23.2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'o-25-2001 9-10-2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 9400 4147 FTI 9400 4147 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, PWD, ABGR, 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" 92# H-40 34' 112' 30" 260 SX Arctic Set (Approx.) 7" 26# L-80 35' 6508' 9-7/8" 860 sx PF 'L', 512 sx Class 'G' 4-1/2" 12.6# L-80 6499' 9348' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 SPF 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 6014' 6077' MD TVD MD TVD 4-1/2", 12.6#, L-80 6077' - 6331' 6286' 6110' - 6130' 3988' - 3997' 6570' - 9304' 4146' - 4147' 6190' - 6210' 4021' - 4029' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6250' - 6270' 4045' - 4052' DEPTH INTERVAL IUD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 bbls Dead Crude 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 29, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL'BBL GAS-MCF WATER'BBL CHOKE SIZE ~ GAS-OIL RATIO 10-1-2001 12 TEST PERIOD 1710 619 56 100I 362 'Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS'MCF WATER-BBL OIL GRAVITY-APl (CORR) F:'ress. 24-HOUR RATE ..28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or w~bm~l c~o,~e c~:::)b OCT 0 5 Z001 Alaska 0il & Gas Cons. Commissio~ ~ r-,,, ~ ~ L~ I A I Anchorage Form 10-407 Rev. 07-01-80 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. Top Schrader OA 6500' 4131' RECEIVED A~aska 0i~ & Gas Cons. C0mn~issi0~ Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fore~e~going is tru,e an~ c_orr_ect to the best of my knowledge Signed Terrie Hubble d~'~- -- ~ Title Technical Assistant Date I 0"~:~ 'O/ MPG-14L1 201-134 Prepared By Name/Number: Sondra Stewman, 564-4750 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 interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. 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'. Form 10-407 Rev. 07-01-80 ORIGINAL BP EXPLORATION Page 1 'of 9 Operations.Summa Report ; Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 'Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: Date From - To Hours ActivityCode NPT .Phase Description of Operations · . 8/6/2001 16:30 - 00:00 7.50 RIGU P PRE Moving to rig G- pad, pipe sheds and welding shop on pad 8/7/2001 '00:00 - 02:00 2.00 MOB P PRE Moved sub from F pad to L pad. :02:00 - 02:30 0.50 MOB P PRE Checked tires on motor room and sub '02:30 - 05:30 3.00 MOB P PRE Moved from L pad to Milne Point Y to turn around. Check tire and let cool on sub. 05:30 - 06:30 1.00 MOB P PRE Moved pits and motor room to G pad. 06:30 - 10:00 3.50 MOB P PRE Return for sub and broke tongue. Repair sub and lay mats. 10:00 - 12:00 2.00 MOB P PRE Move sub from Milne Point Y turn-a-round to G-pad. 12:00 - 15:30 3.50 MOB P PRE Move tires on sub and spot over well. 15:30 - 18:30 3.00 MOB P PRE Set mats and spot pipe shed and drilling line spool. 18:30 - 20:30 2.00 MOB P PRE Set mats and spot pits. 20:30 - 23:00 2.50 MOB P PRE Set mats and spot motor room. 23:00 - 00:00 1.00 MOB P PRE Spot pumps. 8/8/2001 00:00 - 05:00 5.00 MOB P PRE Accepted rig at 0001 hrs 0810812001. Nipple up 21" diverter with 16" knife valve. Rigged up skate. 05:00 - 12:00 7.00 MOB P PRE Take on water to pits - build spud mud - load pipe shed wi5" drill pipe - clean and pick up rig for spud - take down drlg nipple to modify 12:00 - 15:00 3.00 MOB P PRE Con't loading 5" drill pipe in pipe shed - set in mouse hole 15:00 - 16:00 1.00 MOB P PRE Service top drive - check all bolts, safety keepers 16:00 - 17:30 1.50 MOB P PRE P/U 3 joints of 5" drill pipe and function test annular and knife valve. 17:30 - 00:00 6.50 MOB P PRE P/U 5" drill pipe in mouse hole and rack in derrick 8/9/2001 00:00 - 00:30 0.50 MOB P PRE Rig service 00:30 - 04:30 4.00 MOB P PRE P/U 5" drill pipe 04:30 - 07:30 3.00 MOB P PRE P/U 5" hwdp and bha - stand in derrick 07:30 - 12:00 4.50 MOB P PRE Install drilling nipple - hook up flow line riser - Install stiff arms on drilling nipple 12:00 - 13:00 1.00 MOB P PRE Weld 4" collar on divertor line. 13:00 - 14:00 1.00 MOB P PRE P/U motor, bit, XO and one stand dp. 14:00 - 14:30 0.50 MOB P PRE Pre Spud meeting 14:30 - 15:30 1.00 MOB P PRE Break circ and repair leak in riser 15:30 - 16:30 1.00 DRILL P SURF Spud in at 112' - 75 spm 450 psi - 60 rpm @ 2700 ft lbs - drill ice plug @ 43' - clean out to 112' - drill to 150' 16:30 - 18:00 1.50 DRILL N SFAL SURF Flow line plugged - clean out gravel, sand 18:00 - 18:30 0.50 DRILL P SURF Drlg from 150' to 211' - 80 spm 700 psi - 50 rpm @ 2500 ft lbs 18:30 - 19:00 0.50 DRILL P SURF POH 2 stands of hwdp 19:00 - 20:30 1.50 DRILL P SURF P/U bha and make up same 20:30 - 22:00 1.50 DRILL N SFAL SURF Flow line plugged - gravel, sand 22:00-00:00 2.00 DRILL P SURF Drlg from 211'to378'- 100spm 1300psi-51 rpm @2500ft lbs - P/U 70k - S/O 70K 8/10/2001 00:00 - 14:30 14.50 DRILL P SURF Directional drill 9 7/8" surface hole from 378' to 1966' 14:30 - 16:30 2.00 DRILL N FLUD SURF Circ mud - thick mud, due to addition of Lecitin for gas hydrates Printed: 9/24/2001 4:58:07 PM · Bp EXPLORATION Page 2 of 9 Operations'Summa Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: . . · , Date From - To Hours' Activity~ Code NPT Phase DesCription of Operations 8/10/2001 14:30 - 16:30 2.00 DRILL N FLUD SURF - gas hydrates belching in drlg nipple - only able to pump 2 bpm to keep mud from over flowing drilling nipple 16:30 - 17:30 1.00 DRILL . P SURF Directional Drilling from 1966' to 2146'- 420 gpm 1300 psi- 25k web - 50 rpm - 6k torque 17:30 - 19:30 2.00 DRILL 'N FLUD SURF gas hydrate problem - gas belching in drlg nipple over flowing nipple - causing celler to over fill spilling drilling mud onto pad from under rig sub - flow line not handling thick mud - pumping at 4 bpm 19:30 - 21:00 1.50 DRILL P SURF Directional drill from 2146' to 2393' - web 15/20 - rpm 50 - 435 gpm 1400 psi - torqe 5k to 6k 21:00 - 21:30 0.50 DRILL P SURF Circ for short trip - 435 gpm 1400 psi - 85 rpm - torque 5k 21:30 - 23:00 1.50! DRILL P SURF Pull 10 stands pumping out - string weight 120k to 110k - pull stand 11 w/o/p string weight 110k to 120k - stand 12 @ 1320' pulled tight to 160k work twice no go - top drive up - pump out string weight 110k to 115k - pump out stand 13 string weight 100k to 105k - pull stands 14, 15, 16 with out pump string weight 100k to 110k pull to 904' - Hole in good condition 23:00- 23:30 0.50 DRILL P SURF Rig service 23:30 - 00:00 0.50 DRILL P SURF RIH from 904' to 2230' - break circ - precautionary wash from 2330' to 2393' - hole in excellent shape - no problems on trip in - no hydrates seen on trip out or in - 8/11/2001 00:00 - 13:00 13.00 DRILL P SURF Directional Drilling from 2393' to 4000' - 525 gpm 2000 psi- 20-30k web - 125 rpm - 9-1 Ok torque 13:00 - 13:30 0.50 DRILL P SURF Circulate bottoms up before short trip. 13:30 - 17:00 3.50 DRILL P SURF Pumped out of hole 4000' to 1579'. POH to 1296' without pumping. No problems hole in excellent shape 17:00 - 17:30 0.50 DRILL P SURF Service top drive. 17:30 - 18:30 1.00 DRILL P SURF RIH to 4000' - No tight spots 18:30 - 00:00 5.50 DRILL P SURF Precautionary wash from 3920' to 4000' - Directional drilled from 4000' to 4678'. - 500 gpm 2200 psi - 20-30k web - 100 rpm 9-10k torque - P/U 135 - S/O 110 - Rotating 120 8/12/2001 00:00 - 10:00 10.00 DRILL P SURF Directional drill from 4678' to 5772'. Torque 11-12k, WeB 25-30, 100rpm, 545gpm, 2250psi, PU 165, SO 115, ROT 135. 10:00 - 12:00 2.00 DRILL P SURF Pumped out of hole and backream from 5772' to 5143'. Pulled out of hole to 3930' without pumping. No problems hole in excellent shape. 12:00 - 12:30 0.50 DRILL P SURF Service top drive. 12:30 - 13:00 0.50 DRILL P SURF RIH to 5710'. Precautionary wash from 5710' - 5772'. No problems hole in good shape. 13:00 - 17:30 4.50 DRILL P SURF Directional drill from 5772' to 6093'. Torque 11-13k, WeB 20-25, 80rpm, 545gpm, 2300psi, PU 175, SO 125, ROT 135 17:30 - 19:30 2.00 DRILL P SURF CBU for bit change - mix dry job - pump dry job 19:30 - 00:00 4.50 DRILL P SURF Trip for bit due to trouble sliding and no reaction on slide - POH to 1689' - one tight spot at 2357' - work once with out pump or rotary ok 8/13/2001 00:00 - 00:30 0.50 DRILL P SURF Con't poh to hwdp at 920' 00:30 - 03:00 2.50 DRILL P SURF Pull bha - break off bit - service motor - rih down load CDR - change out MWD - stand back 03:00 - 04:30 1.50 DRILL P SURF Pick up 3 1/2" dp in mouse hole - stand back in derrick 04:30 - 10:00 5.50 DRILL P SURF Make up bit #2 - rih - filling every 25 stands - tight hole at 2630 to 2850 / 4115 to 4396 - no other tight spots were noted Printed: 9124/2001 4:58:07 PM BP EXPLORATION Page3 of 9 Operations Summary Report , Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: .Date From - To Hours Activity Code NPT Phase Description of Operations,~' ' 8/13/2001 10:00 - 00:00 14.00 DRILL :) SURF :Directional; drill from 6093' to 6742'. Torque 13-14k, WOB 20-30k, 80rpm, 545gpm, 2350psi, PU 170, SO 125, ROT 140. 8/14/2001 00:00 - 10:00 10.00 DRILL P SURF Directional drill from 6742 to 7138' - T.D. 9 7/8" hole -wob 40 to 50k - 513 pm 2150 psi - P/U 175 S/O 110 ROT 125 10:00 - 13:00 3.00 DRILL P SURF Pump sweep - circ / cond hole for short trip - ream from 7138 to 6931 - pump dry job 13:00 - 20:00 7.00 DRILL P ~SURF POH w/o pump from 7138' to 3078' - ratty from 6800' to 6450' - 10 to 30k over - pump out from 3078' to 1573' - tight at 2670 to 2430 work through tight spots - pull from 1573' to 920' 20:00 - 21:00 1.00 DRILL P !SURF Rig Service 21:00 - 00:00 3.00 DRILL N RREP SURF Rig repair - tilt link system would not release to neutrel - Solenoid worn out - Replace solenoid - no power from switch to solenoid to release valve letting tilt float. 8/15/2001 00:00 - 00:30 0.50 DRILL N RREP SURF Replacing solenoid on tilt link system 00:30 - 03:00 2.50 DRILL P SURF RIH from 920' to 2428' work through tight spot w/o/pump - rih from 2450' to 6450' - filling pipe every 25 stands 03:00 - 04:30 1.50 DRILL P SURF wash and ream ratty hole from 6450' to 7138' - hole in good shape no tight spots washing in from 6450' 04:30 - 07:00 2.50 DRILL P SURF Pump hi-vis sweep - circ / cond hole for running 7" casing - build dry job - pump dry job 07:00 - 10:30 3.50 DRILL P SURF POH to BHA - hole in good shape no tight spots noted 10:30 - 14:00 3.50 DRILL ~P SURF Stand back hwdp in derrick - Lay down flex collars - mwd - cdr - motor - service motor 14:00 - 17:00 3.00 CASE P SURF Rig up casing equipment - hold safetry meeting on 7" casing job. 17:00 - 19:00 2.00 CASE I P SURF Rig service - lubricate top drive, rig 19:00 - 00:00 5.00 CASE P SURF Run 7" casing - Break circ pump casing vol Joint # 100 @ 4100'- 120 joints in hole @ 00:00 hrs 8/16/2001 00:00 - 03:00 3.00 CASE I p SURF Finish Running 7" 26~ L-80 Btc-Mod casing - Total 174 jts 7,087', Landed on mandrell casing hanger- shoe at 7,132' 03:00 - 04:00 1.00 CEMT P SURF Circulate and condition mud - slowly increase pump rate 2 bpm to 8 bpm 650 psi - Mud wt. 9.5 ppg 04:00 - 05:00 1.00 CEMT !P SURF Rig down Frank's fill up tool - Make up Halliburton double plug cement head 05:00 - 06:30 1.50 CEMT , P SURF Continue Circulating casing 8 bpm 650 psi - full returns - did not reciprocate pipe 06:30 - 10:00 3.50 CEMT !P SURF Pre-Job safety meeting - pump 5 bbls water-Test lines to 4000 psi, Pump 20 bbl water + 50 bbls Alpha spacer mixed at 10.2 ppg, Followed by 860 sx Class 'L' cement, Yield 4.15 cf/sx, 635 bbls slurry mixed at 10.7 ppg Tailed with 515 sx 'Premium' w/ .2% Halid 344 +.2% CFR-3 + 1% cacl- Yield 1.15 cf/sx, 105 bbls slurry mixed at 15.8 ppg - Drop top plug with 20 bbls water & Displaced with rig pump 247 bbls mud, 8 bbl / min 1200 psi - Bump to 2000 psi - full returns - 300 bbls cement to surface - ClP 10:00 hrs 8/16/01 10:00 - 12:00 2.00 CEMT P SURF Check floats, ok - Rig down cement head, Back out landing jt and lay down - Rig down casing tools 12:00 - 15:00 3.00 BOPSUF~P SURF Nipple down 20" diverter system 15:00 - 16:00 1.00 WHSUR P PROD1 Nipple up FMC Gen 6 SO x 11" 5000~ wellhead - Test seal to 1000 psi ok 16:00 - 20:00 4.00 BOPSUF P PROD1 Nipple up 11" x 13 5~8" 5000# adapter spool and 13 5/8" 5000# Bop stack - Nabors Rental 3 1/2" pipe rams top and Bottom, Blind rams middle Printed: 9/24/2001 4:58:07 PM "'~'BP:EXPLORATION page 4 of 9 Operations :Summa Report , ,., Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 , Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 ~Contractor Name: NABORS Rig Release: 9/3/2001 ~Rig Name: Nabors 27E Rig Number: · Date · From -To Hours Activity: Code~ NPT Phase· ,Description of Operations 8/16/2001 20:00 - 23:00 3.00 DRILL P PROD1 Slip and cut drlg line - adjust brake linkage 23:00 - 00:00 1.00 DRILL P PROD1 Changing 5" saver sub to 3 1/2" on top drive 8/17/2001 00:00 - 01:30 1.50 DRILL P PROD1 Finish changing top drive saver sub from 5" to 3 1/2"- Install bails - elevators 01:30 - 03:00 1.50 DRILL P PROD1 Install drilling nipple, drip pan ,03:00 - 16:00 13.00 DRILL P PROD1 Lay down 5" HWDP - 5" drill pipe in mouse hole 16:00 - 18:30 2.50 DRILL N RREP PROD1 Work on top drive - lub/oil - Rig down time 18:30 - 20:00 1.50 DRILL P PROD1 Rig up to test bop's 20:00 - 00:00 4.00 DRILL P PROD1 Test Bop's - Annular 250 Iow 3000 high - Top / Btm 3 1/2" pipe rams 250 Iow 3500 high - Manifold valves 250 Iow 3500 high accumulator test 3000 psi - shut pipe rams, annular, hydralic choke, hydralic kill valve psi 1850 - 200 psi increase 23 sec - full pressure 1 min 10 sec 3000 psi - 8 bottles avg 2350 - con't testing bop's 8/18/2001 00:00 - 02:00 2.00 DRILL P PROD1 Test bop's - blind rams 250 Iow 3500 high - upper, lower, TIW, IBOP 250 Iow 3500 high - finish choke valves 02:00 - 03:30 1.50 DRILL P PROD1 Pull test plug - install wear ring - rig down testing equipment - blow down choke manifold - cementing line - top drive 03:30 - 07:30 4.00 DRILL P PROD1 P/U 3 1/2" dp - stand back 14 stands in derrick 07:30 - 10:00 2.50 DRILL P PROD1 P/U bha # 3 - - flow test motor / mwd - 60 spm 800 psi 10:00 - 17:30 7.50 DRILL P PROD1 P/U 3 1/2" dp - rabbit each joint on skate - rih to 6980' 17:30 - 18:30 1.00 DRILL P PROD1 wash cement stringers from 6980' to 7043' 18:30 - 19:30 1.00 DRILL P PROD1 CBU for casing test 19:30 - 20:00 0.50 DRILL P PROD1 Test casing to 3500 psi - hold for 30 mins - ok 20:00 - 22:00 2.00 DRILL P PROD1 Drill float equipment - 30' new hole to 7168' - wob 5k - rpm 50 - spm 60 - 2050 psi 22:00 - 22:30 0.50 DRILL P PROD1 CBU for FIT test 22:30 - 23:00 0.50 DRILL P PROD1 Run FIT test to equiv 11.26 - 450 psi surface pressure with 9.2 mud wt in hole TVD 4205' 23:00 - 00:00 1.00 DRILL P PROD1 Displace spud mud with - 9.2 FIo-Pro 8/19/2001 00:00 - 01:00 1.00 DRILL P PROD1 Displace to 9.2 FIo-Pro mud 01:00 - 07:00 6.00 DRILL P PROD1 PJSM with Schlumberger on rigging up to run gyro - rig up Schlumberger - Run Gyro to 7000' - Log up - Rig down Schlumberger 07:00 - 00:00 17.00 DRILL P PROD1 Directional drill from 7168' to 8230' - WOB 5k - SPM 60, 1650 psi- GPM 250 - RPM 115 - P/U 130k - S/O 90k - Rot 95k 8/20/2001 00:00 - 14:00 14.00 DRILL P PROD1 Directional drill from 8230' to 9405' T.D. well - 120 rpm - wob 2/5k - 1950 psi - 250 gpm - P/U 125k - S/O 80k - Rot 90k - 7k tq 14:00 - 17:00 3.00 DRILL P PROD1 CBU - 3 times 7400 stks - 66 spm - 120 rpm - 2150psi 17:00 - 19:30 2.50 DRILL P PROD1 Trip to shoe @ 7132' - trip out pumping 24 stds at 60 spm - string wt 125k - hole in good condition. 19:30 - 20:00 0.50 DRILL P PROD1 Rig service - top drive / drawworks - monitor well - well static 20:00 - 22:00 2.00 DRILL P PROD1 RIH to 9405' - no problems on trip in - hole in good condition - string wt 60k to 80k 22:00 - 00:00 2.00 DRILL P PROD1 CBU - three times @ 66spm - 2150 psi - 120 rpm - string wt 125k up - 80k s/o - 90k rot - oil show in mud - gas cut mud back 9.2+ with pressurized scale - 8.7 with regular scale - no flow / no gain on btms up. 8/21/2001 00:00 - 00:30 0.50 DRILL P PROD1 Finish spotting new mud in open hole, 00:30 - 04:00 3.50 DRILL P PROD1 Pumping up into csg.@7132, pumping out with 10spm and 400 psi, no problems 04:00 - 09:00 5.00 DRILL P , PROD1 Monitor well, trip out to BHA Printed: 9/24/2001 4:58:07 PM BP EXPLORATION, Page 5 of 9 OPerations Summary Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 'Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: Date From,-To Hours ActivityCode NPT Phase Description of Operations : 8/21/2001 09:00 - 11:00 2.00 DRILL ~ PROD1 Monitor well, lay down BHA !11:00 - 11:30 0.50 CASE ~ COMP Clear floor, rig up to pick up liner 11:30 - 15:00 3.50 CASE ~ COMP Picking up 57 its Slotted 3 Blank Jts 4 1/2 12.6~ L-80 And Baker 5x7 HMC liner hanger with baker ZXP liner top packer total talley 2368 ft. ( no inter string) 15:00 - 17:00 2.00 CASE 3 COMP Trip in with liner to 9405, liner top 7029 ( no problems) Pick up wt 138,000 slack off wt. 80,000 17:00 - 18:00 1.00 CASE P COMP circ volume of pipe, drop ball and set packer ball sheared out with 3800# 18:00 - 19:00 1.00 CASE P COMP Circ bottoms up from 7000 ft and pump slug 19:00 - 22:00 3.00 CASE P COMP Strapping out with drill pipe, pipe strap OK 22:00 - 00:00 2.00 BOPSUF.P PROD1 Rig up, pull wear ring, testing BOPS 250-3500 8/22/2001 00:00- 04:00 4.00 BOPSUF,P PROD2 Testing BOPS 250-3500~ (OK) 04:00 - 05:00 1.00 BOPSUF,P PROD2 Install wear ring and blow down 05:00 - 07:00 2.00 STWHIP P PROD2 Pick up 15 jts of 3.5 and seal ass. for space out of whip stock 07:00 - 10:30 3.50 STVVHIP P PROD1 Pick up whip stock and MWD 10:30 - 15:00 4.50 STVVHIP P PROD1 Trip in with whip stock to 6450 15:00 - 16:00 1.00 STVVHIP P PROD1 Orient whip stock and sting in to OB liner @ 7028- set whip stock anchor w/15,000, tool face 5 Dregees left highside, pull test 10,000 over and shear off whip stock w/35,000 16:00 - 19:00 3.00 STWHIP P PROD1 M. ill window in 7" csg 6508-6520 pilot hole to 6530 19:00 - 20:30 1.50 STWHIP P PROD1 Circ 3 bottoms up 5100 pump st. 20:30 - 00:00 3.50 STWHIP:P PROD1 Trip out with mill 8/23/2001 00:00 - 02:00 2.00 STWHIP P PROD2 Finish trip out with Mills 02:00 - 02:30 0.50 STWHIP:P PROD2 Flush out BOPS 02:30 - 03:00 0.50 STWHIP P PROD2 Pick up 12 jts of 3.5 and stand in derrick 03:00 - 05:30 2.50 DRILL P PROD2 Pick up BHA #2 adjust motor to 1.15 test mwd tool, rerun sec. pdc bit 05:30 - 08:30 3.00 DRILL I P PROD2 -Trip in hole fill pipe every 25 sds. 08:30 - 09:00 0.50 DRILL P PROD2 Orient and slide tru window @ 6508 09:00 - 12:00 3.00 DRILL P PROD2 Drlg from 6532 to 6607 (MWD failed) 12:00- 15:00 3.00 DRILL N DFAL PROD2 Tripping out for MWD tool 15:00 - 17:30 2.50 DRILL N DFAL PROD2 Lay down motor and mwd tools., pick up new motor and mwd and test same-- bit FM2643 w/3/13 jets, motor XP AIM w/ 1.50, nm flex, nm stab, mwd, pwd,3 nm flex, jars 17:30- 18:30 1.00 DRILL N DFAL PROD2 Trip in to 2500 18:30- 19:00 0.50 DRILL N DFAL PROD2 Service rig and topdrive 19:00 - 21:00 2.00' DRILL N DFAL PROD2 Tripping in from 2500 to 6532 21:00 - 22:00 1.001 DRILL N DFAL PROD2 logging hole from 6508 to 6607 22:00 - 00:00 2.00 DRILL P PROD2 Drilling from 6607 to 6698 with 1600~ PP, 250 gals min, 5/10,000 bit wt. sliding 2 hrs 8/24/2001 00:00 - 00:00 24.00 DRILL P PROD2 Directional drill from 6698-8247 with 5/10,000# 1800 # PP 251 gals min 120 rpms AST 9.75 ART 8, control drlg 180 ft per hr. 8/25/2001 00:00 - 16:00 16.00 DRILL P PROD2 Directional drill from 8247-9400 TD with 5/10,000~ 1800 # PP 251 gals min 120 rpms AST 2.5 ART 9.25, control drlg 180 ft per hr. 16:00 - 17:00 1.00 DRILL P PROD2 Circ with 66 ps 3500# (Motor failed) jets plug, down to 17 spm 4000# 17:00 - 19:30 2.50 DRILL P PROD2 Pumping out to window 6508, no problems, no overpull, pumping with 25 spm pump press drop to 1000~ 19:30 - 23:30 4.00 DRILL P PROD2 Monitor well, tripping out to BHA, wet 23:30 - 00:00 0.50 DRILL P PROD2 Laying down BHA 8/26/2001 00:00 - 01:30 1.50 DRILL P PROD2 Laying down BHA Printed: 9124/2001 4:58:07 PM BP EXPLORATION . Page 6 of 9 · Operations,$umma Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: · Date:: From Tel Hours Activity Code .NPT Phase '. Description of Operations · 8/26/2001 01:30 - 03:00 1.50 DRILL P PROD2 Making up BHA #7-6 1/8 hole opener,feat sub, 4 3/4 dc, 6" stab, 4 3/4 dc, 6" stab, 4 3/4 dc, 3 jts hw, jars 03:00 - 05:30 2.50 DRILL P PROD2 Tripping in w/hole opener to 6428 05:30 - 07:30 2.00 DRILL P PROD2 Slip and cut drilling line 07:30 - 08:00 0.50 DRILL P PROD2 Tripping in to 6654 08:00 - 15:00 7.00 DRILL P PROD2 Reaming hole wih hole opener from 6654 to 9400 0~4,000 on hole opener, 300 gpm, 1600 psi, 120 rpm 5,000 torque 15:00 - 17:00 2.00 DRILL P PROD2 Circ, three bottoms up and spot new mud 17:00 - 19:30 2.50 DRILL P PROD2 Pumping to window @ 6508, no problems, no over pull pumped with 10 spm 150~ 19:30 - 20:00 0.50 DRILL P PROD2 monitor well, pump slug 20:00 - 22:00 2.00 DRILL P PROD2 Trip out 22:00 - 23:00 1.00 DRILL P PROD2 Lay down BHA #7 23:00 - 00:00 1.00 DRILL P PROD2 Pick up BHA #8--Whipstock ret. tool, 1 hwdp, MWD, Bumper ~sub, oil jars, 9 dc 8/27/2001 00:00 - 00:30 0.50 DRILL P PROD2 !Finish picking up BHA#8mWhipstock ret. tool, 1 hwdp, MWD, Bumper sub, oil jars, 9 dc 00:30 - 03:00 2.50 DRILL P PROD2 Tripping in to 6450 03:00 - 04:00 1.00 DRILL P PROD2 Orient tools and lach on to whip stock at 6,511' - pulled free w/ 175,000 - 50,000 over string wt. 04:00 - 04:30 0.50 DRILL P PROD2 Monitor well, pump slug 04:30 - 08:00 3.50 DRILL P PROD2 Trip out w/whipstock 08:00 - 10:00 2.00 DRILL P PROD2 lay down BHA, whipstock and stringer 10:00 - 11:00 1.00 CASE P PROD2 Clear floor, rig up casers 11:00 - 14:00 3.00 CASE P PROD2 Picking up 'OA' slotted liner, 70 jts 4.5 slotted 12.6# 1-80 IBT, 2 jts 4.5 blank 12.6~ 1-80 IBT, Baker wall hook hangerwith Swivel 14:00 - 14:30 0.50 CASE P PROD2 Rig service 14:30 - 16:30 2.00' CASE P PROD2 Tripping in with liner to 6550, 30' below window, with drill pipe in tension, rotare 1.5 turns to the right & pick up to top of window- RIH set down on 'OB' liner top @ 7,028' - POOH to 20 ft above window- 1 turn to the right- RIH set down @ 7,028' - Pooh to middle of window rotate until rotating torque broke over - TIH, exit window no problem 16:30 - 19:00 2.50 CASE P PROD2 Trip in hole with slotted liner to 9348 Pick up wt 125,000 slack off 80,000 19:00 - 20:00 1.00 CASE P PROD2 Latch wall hook hanger on bottom of window @ 6,520' - latch window by rotating sring in compression 1/4 turn to the right and slacking off - latch window on the seventh attempt, circ the pipe vol. with 40spin 850#-- drop ball pump down with 40 spm shear ball with 3600 #, string wt picking up 115,000~ 20:00 - 20:30 0.50 CASE P PROD2 Monitor well, pump slug 20:30 - 00:00 3.50 CASE P PROD2 Trip out, lay down excess drlg pipe 8/28/2001 00:00 - 01:30 1.50 CASE P PROD2 lay down excess drlg pipe 01:30 - 05:00 3.50 CASE P PROD2 Pickup Baker Bridge plug trip into 6454 05:00 - 06:00 1.00 CASE P PROD2 Circ and set bridge plug with 2500~ pump pressure @ 6450 06:00 - 06:30 0.50 CASE P PROD2 Attempt to test bridge plug 35 spm 350# would pump away 06:30 - 09:30 3.00 CASE P PROD2 Tripping out with running tool 09:30 - 12:00 2.50 CASE P PROD2 Tripping in with baker plug retrieving tool latch on to plug @ 6450 12:00 - 17:00 5.00 CASE P PROD2 Tripping out with plug (wet retrieving tool pluged with small chunks of rubber and steel shavings) bottom rubber looked new top rubber was in poor shape, had one piece missing Printed: 912412001 4:58:07 PM ' ~1 BP EXPLORATION Page 7 of 9 , · . ,Operations Summary Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: .!:':'Date From ,.:To' HoUrs Activity Code NPT Phase DeScription of operations. 8/28/2001 12:00 - 17:00 5.00 CASE P PROD2 about 1 in wide and 3 in long rubber was still together should have tested 17:00 - 21:00 4.00 CASE P PROD2 Pick up new baker plug and trip in to 6445 21:00 - 22:30 1.50 CASE P PROD2 Attempt to set plug @ 6445, circ pipe vol., drop ball pressure up to 2500~ no set, repressure to 2500~ still didn't set, bleeded off pressure, start to pull plug out of the hole, picked up to 6430 and plug was hanging up, pulled 20,000 over string iwt. attempt to set plug again with pressure went up to 2500~ with no overpull on plug and it shear off and went down hole. should be on hook wall hanger top @ 6498 22:30 - 23:00 0.50 CASE ~ PROD2 circ bottom up 23:00 - 00:00 1.00 CASE ~ PROD2 Tripping out for retrieving tool 8/29/2001 00:00 - 02:00 2.00 CASE N DPRB PROD2 Trip out for retrieving tool 02:00 - 05:00 3.00 CASE N DPRB 'PROD2 Tripping in w/Baker retrieving tool to 6400 05:00 - 05:30 0.50 CASE N DPRB PROD2 Circ bottoms up 50 Spm 750~ 05:30 - 06:30 1.00 CASE N DPRB PROD2 Engage Plug @ 6499 the top of hook wall hanger, pull 2 stands fish hung up at 6460, came free 06:30 - 07:00 0.50 CASE N DPRB PROD2 Monitor well, pump Slug 07:00 - 10:30 3.50 CASE N DPRB PROD2 Trip out with Bridge plug, Lay down same 10:30 - 11:30 1.00 CASE N DPRB PROD2 Breaking down plug, Body lock ring was in backward was why this plug didn't set, wait on orders ' 11:30 - 16:00 4.50 CASE N DPRB PROD2 Mu 7" Baker Lock Set Bridge plug Trip in to 6300 16:00 - 17:00 1.00 CASE N DPRB PROD2 Set bridge plug @ 6300, r/u up to test, pump away 2 bbls min 600#, tested surface lines to 1500# 17:00 - 00:00 7.00 CASE N DPRB PROD2 Tripping out setting and testing csg @5277, 4323,3365 2410, 1080 no test pumping away, pulled to 890 csg tested 2500 # for 10 min. tripping out for tam shifing tool, tam port collar set @ 1011 to 1013 8/30/2001 00:00- 00:30 0.50 CASE :N DPRB PROD2 Clean rig floor. 00:30 - 01:30 1.00 CASE ~N DPRB PROD2 Make up Tam combo tool and run in hole to 1011'. 01:30 - 02:00 0.50 CASE N DPRB PROD2 Latched into Tam Port Collar. Pressure tested collar and was able to establish injection at 3 bbl/min at 300 psi. Shifted collar 3-3/4" (full stroke is 7") to close tool. Pressure tested collar to 1100 psi for 10 minutes. Good test. 02:00 - 03:00 1.00 CASE N DPRB PROD2 Pulled out of hole and laid down Tam combo tool. 03:00 - 07:30 4.50 CASE N DPRB PROD2 Made up Baker 7" bridge plug and ran in hole with 3-1/2" drill pipe to 6400'. 07:30 - 08:00 0.50 CASE N DPRB PROD2 Circulated drill pipe volume, 08:00 - 09:00 1.00 CASE N DPRB PROD2 Dropped setting ball and pumped down and set bridge plug at 6400'. Sheared off setting tool. Pulled 30' and pressure tested plug and casing to 2500 psi for 30 minutes. Good test. 09:00 - 09:30 0.50 CASE P PROD2 Dropped ball and rod to open circulating sub and pumped down hole and opened circ sub. 09:30 - 11:00 1.50 CASE P PROD2 Flushed all lines with seawater. Displaced hole with 300 bbls of seawater at 6 bpm at 1200 psi. Rotated 50 RPM and Printed: 9/2412001 4:58:07 PM ,, · Bp EXPLORATION Page 8of 9 · - OperatiOns'Summary Report ., Legal Well Name: MPG-14 'Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: '.Date~ ~ From-To Hours Activity Code NPT Phase DescriPtion of Operations 8/30/2001 09:30 - 11:00 1.50 CASE P PROD2 reciprocated pipe during displacement. Displace seawater in hole with 250 bbls of 9.2 ppg KCL at 6 bpm at 1200 psi. 11:00 - 17:00 6.00 CASE P .PROD2 Laying down 3.5 pipe 17:00 - 17:30 0.50 CASE P PROD2 Clear floor 17:30 - 18:00 0.50 CASE P PROD2 ;Service rig 18:00 - 20:00 2.00 CASE P PROD2 Slip and cut drilling line '20:00 - 20:30 0.50 CASE P PROD2 Pull wear ring !20:30 - 00:00 3.50 CASE P PROD2 Rig up, and picking up Baker bridge plug retieving tool and 2 7/8 6.5 1-80 Eue 8rd tubing 9/1/2001 00:00 - 01:30 1.50 CASE X DPRB PROD2 Wait on brine. 01:30 - 02:00 0.50 CASE X DPRB PROD2 Take on 9.5 ppg brine and cut to 9.2ppg. 02:00 - 03:30 1.50 CASE X DPRB PROD2 Displace diesel with 9.2ppg brine. Total displacement 32bbl. Set two way check valve and test to 1000psi. 03:30 - 09:30 6.00: CASE X DPRB PROD2 ND tree and NU BOP. Change BOP bottom rams to 3 1/2". 09:30 - 12:00 2.50 CASE X DPRB PROD2 Wait on 2 7/8" rams. 12:00 - 14:30 2.50 CASE X DPRB PROD2 change rams to 2 7/8 in top 14:30 - 20:00 5.50 CASE X DPRB PROD2 Test Bops to 250-3500 repair one leak in coke manifold replace seal ring 20:00 - 21:30 1.50 CASE X DPRB PROD2 Pull two way check and pull hanger 21:30 - 22:30 1.00 CASE X 'DPRB PROD2 Circ Bottoms up with 500# 4bbls rain, lost 2.5 bbls into cellar tru leak in csg. 22:30 - 23:00 0.50 CASE X DPRB PROD2 Monitor well, pump slug 23:00 - 00:00 1.00 CASE X DPRB PROD2 laying down 2 7/8 tubing 9/2/2001 00:00 - 06:30 6.50 CASE X DPRB PROD2 POH. LD 2 7~8" tubing. 06:30 - 07:00 0.50 CASE X DPRB PROD2 Clear rig floor 07:00 - 08:30 1.50 CASE X DPRB PROD2 Hold PJSM on testing. RU test equipment and test bottom 3 1/2" pipe rams. RD testing equipment. 08:30- 09:00 0.50 CASE X DPRB PROD2 Land wear bushing. 09:00 - 12:00 3.00 CASE X DPRB PROD2 PU TAM Port Collar combo tool. PU 3 1/2" DP to 1012'. Sting tool into port collar and RU to circulate. 12:00 - 14:00 2.00 CASE X DPRB PROD2 Closed port collar. Pressure tested collar to 1000 psi. Good test. Slacked off and opened port collar. Established injection rate 1 bpm at 240 psi, 1.5 bpm at 320 psi and 2 bpm at 340 psi. Pumped a total of 21 bbls of 9.2 brine. Had partial returns to cellar. Closed port collar and retested collar to 1000 psi. Slacked of and opened port collar. Established injection at 1 bpm at 240 psi, 1.5 bpm at 275 psi and 2 bpm at 310 psi. Returns stopped in cellar with an additional 20 bbls of 9.2 ppg brine pumped. Decided not to pump lead slurry since returns had been lost. 14:00 - 15:30 1.50 CASE X DPRB PROD2 Held PJSM. Pumped 2 bbls water and tested lines to 2000 psi. Pumped additional 3 bbls of water. Followed water with 16.8 bbls of Class C cement weighted to 15.8 ppg. Displaced cement with fresh water and left one bbl of cement in drill pipe. Closed tool and pessure tested collar to 1000 psi. Bleed off pressure and released Tam combo tool from Tam port collar. Pulled above port collar. 15:30 - 16:30 1.00 CASE X DPRB PROD2 Pressured up to 2200 psi and sheared Tam combo tool. Printed: 9/24/2001 4:58:07 PM BP EXPLORATION" Page 9 of 9 Operations summa Report Legal Well Name: MPG-14 ;Common Well Name: MPG-14 Spud Date: 8/9/2001 Event Name: DRILL+COMPLETE Start: 8/6/2001 End: 9/3/2001 Contractor Name: NABORS Rig Release: 9/3/2001 Rig Name: Nabors 27E Rig Number: 'Date From - To HOurs ACtivity Code NPT Phase Description of OperationS 9/2/2001 15:30 - 16:30 1.00 CASE X DPRB PROD2 Circulated hole clean. Did not see any cement to surface. Pressure tested casing string to 1000 psi for 5 minutes. Good test. 16:30 - 17:30 1.00 CASE X DPRB PROD2 :Pulled out of hole laying down 3-1/2" drill pipe and Tam combo 17:30 - 18:30 1.00 CASE PROD2 Pull wear ring, rig to run tubing 18:30 - 00:00 5.50 CASE X DPRB PROD2 Pick up baker retieving tool and 201 its of 2 7/8 tubing total tally 6330 Pu 27,000 So 16,000 (no block wt.) 9/3/2001 00:00 - 02:00 2.00 CASE X DPRB PROD2 Land hangar. Test two way check valve to 1000psi. Test annulus to 1000psi. 02:00 - 02:30 0.50 CASE X DPRB PROD2 Clear rig floor of tubing equipment. 02:30 - 04:00 1.50 CASE X DPRB PROD2 Change top and bottom BOP rams to 4". 04:00 - 05:00 1.00 CASE iX DPRB PROD2 ND BOP stack. 05:00 - 06:30 1.50 CASE X DPRB PROD2 NU Tree. 06:30 - 07:30 1.00 CASE X DPRB PROD2 Test hangar void and tree to 5000psi. 07:30 - 08:00 0.50 CASE X DPRB PROD2 RU lubricator and pull two way check valve. 08:00 - 11:30 3.50: CASE X DPRB PROD2 RU HB&R test line and pump 80bbl diesel. Suck back 3bbl and allow to u-tube. 11:30 - 12:00 0.50 CASE P PROD2 Set back pressure valve. Release rig at 1200hrs. Printed: 9/24/2001 4:5~:07 PM ...... BP EXPLORATION Page 1 of 1 Operations Summary Report Legal Well Name: MPG-14 Common Well Name: MPG-14 Spud Date: 8/9/2001 i Event Name: COMPLETION Start: 9/16/2001 End: 9/20/2001 IContractor Name: NABORS Rig Release: 9/20/2001 Rig Name: NABOP, S 4ES Rig Number: 4ES , Datei~'?~ 'From- TO~ Hours ACtivity Code NPT Phase Description of Operations 9/16/2001 17:00 - 23:00 6.00: RIGU COMP MIRU. RAISE & SCOPE DERRICK. SPOT ,BERM & RU TIGER TANK. ACCEPTED RIG @ 23:00 HRS. 23:00 - 00:00 1.00 REST COMP PJU TO CIRC. SEAWATER & DIESEL FROM WELLBORE. 9/17/2001 00:00 - 00:30 0.50 REST COMP RU TO CIRC. SEAWATER & DIESEL FROM WELLBORE. 00:30 - 01:00 0.50 REST COMP PULL BPV. 01:00 - 02:30 1.50 REST COMP CIRC. SEAWATER & DIESEL FROM WELLBORE W/9.2 BRINE. 02:30 - 04:00 1.50 REST COMP SET & TEST TWC. ND TREE. 04:00 - 06:00 2.00 REST COMP NU BOPE. 06:00 - 06:30 0.50 REST COMP SERVICE RIG. 06:30- 10:30 4.00 REST COMP NU BOPE. 10:30 - 14:00 3.50 REST COMP PRESS. TEST BOPE 250/2500 PER BP/AOGCC REGS. WITNESSING WAIVERED BY CHUCK SCHEVE @ 3:00AM 9-17-01. 14:00- 15:30 1.50 REST COMP PULL TWC. PU LANDING JT. MU HANGER. BOLDS. PULL HANGER TO FLOOR. LJD HANGER. PU WT. 37K. SO WT. 25K. 15:30 - 17:30 2.00 REST COMP RIH TO 6428'. LATCH & RELEASE BP. CIRC. MONITOR WELL. 20 PSI ON TBG. 40 PSI ON CSG. 17:30 - 19:30 2.00 REST COMP CIRC. & WT. UP BRINE TO 9.4. MONITOR WELL. 19:30 - 23:00 3.50 REST COMP POOH W/2 7~8" TBG. & BP. 23:00 - 23:30 0.50 REST COMP OOH. L/D BP. CLEAR FLOOR. 23:30 - 00:00 0.50 REST COMP RU SWS TO PERF. "N" SAND. 9/18/2001 00:00 - 07:30 7.50 REST COMP PERF. "N" SAND. 6250'-6270. 6190'-6210'. 6110'-6130'. 3 3/8" PJ 6 SPF 60 DEGREE PHASING. ALL SHOTS FIRE. RD SWS. 07:30 - 08:00 0.50 REST COMP SERVICE RIG. 08:00 - 09:00 1.00 REST COMP MU BAKER 7' SLZXP PACKER W/XN NIPPLE & RE ENTRY GUIDE. 09:00 - 16:00 7.00 REST COMP PU 3 1/2" DP & TIH. 16:00 - 16:30 0.50 REST COMP SET BAKER 7" SLZXP PACKER @ 6,286'. RKBM. 16:30 - 19:30 3.00 REST COMP POOH W/3 1/2" DP. 19:30 - 20:30 1.00 REST COMP LD SETTING TOOLS. CLEAR FLOOR. 120:30 - 22:30 2.00 REST COMP MU HALCO SCREEN ASSM & PACKER. 22:30 - 00:00 1.50 REST COMP RIH W/HALCO PACKER & SCREEN ASSM. ON 3 1/2" DP. 9/19/2001 !00:00 - 02:30 2.50 REST COMP CONT. RIH W/HALCO PACKER & SCREEN ASSM. 02:30 - 03:30 1.00 REST COMP STING IN & SPACE OUT. SET PACKER. TEST PACKER TO 2500 PSI. PU WT. 67K. SO WT. 54K. 03:30 - 06:00 2.50 REST COMP POOH LD 3 1/2" DP. 06:00 - 06:30 0.50 REST COMP SERVICE RIG. 06:30 - 09:00 2.50 REST COMP CONT. POOH LD 3 1/2" DP. 09:00 - 11:00 2.00 REST COMP LD HLCO SETTING TOOL & 18 JTS. 2 7/8" TBG. 11:00 - 12:30 1.50 REST COMP CLEAR FLOOR. RU TO RUN ESP. 12:30 - 16:00 3.50 REST COMP PU PUMP & MOTOR. SERVICE & TEST. 16:00 - 20:00 4.00 REST COMP RIH W/2 7/8" TBG. & ESP. 20:00 - 23:00 3.00 REST COMP MU HANGER & LANDING JT. INSTALL PENETRATOR. SPLICE EFT & TEST. LAND HANGER.RILDS. PU WT. 45K. SO WT. 32K. SET & TEST TWC. 23:00 - 00:00 1.00 REST COMP ND BOPE. 9/20/2001 00:00 - 01:00 1.00 REST COMP NIPPLE DOWN BOP 01:00 - 02:30 1.50 REST COMP NIPPLE UP TREE & TEST SAME. 02:30 - 04:00 1.50 REST COMP PULL TWC & INSTALL BPV & SECURE WELL HEAD & CELLAR AREA (RIG RELEASED @ 0400 HRS. 9/20/2001 Printed: 9124/2001 4:58:49 PM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska), Inc. Field .................... : Milne Point Well ..................... : MPG-14 L1 API number ............... : 50-029-23031-60 Engineer ................. : R.Harmer COUNTY: .................. : Nabors 27E STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 29.50 ft KB above permanent ....... : -999.25 ft DF above permanent ....... : 62.93 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 10.31 degrees 27-Aug-2001 15:39:23 Page 1 of 5 Spud date ................ : 09-Aug-01 Last survey date ......... : 27-Aug-01 Total accepted surveys...: 115 MD of first survey ....... : 0.00 ft MD of last survey ........ : 9400.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 06-Aug-2001 Magnetic field strength..: 1148.91 HCNT Magnetic dec (+E/W-) ..... : 26.21 degrees Magnetic dip ............. : 80.79 degrees MWD survey Reference Criteria Reference G .............. : 1002.69 mGal Reference H .............. : 1148.91 HCNT Reference Dip ............ : 80.79 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 26.22 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.22 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6 lC 10] A/qADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 113.54 0.30 255.15 3 199.15 0.61 228.26 4 295.07 1.11 285.11 5 383.93 2.62 308.41 6 475.91 4.05 309.07 7 565.27 4,86 307.52 8 654.39 5.85 308.09 9 745.34 7.29 302.45 10 837.47 9.33 300.98 0.00 113.54 85.61 95.92 88.86 91.98 89.36 89.12 90.95 92.13 11 931.51 11.38 304.29 94,04 12 1023.61 13.64 305.26 92.10 13 1119.18 16.09 304.64 95.57 14 1212.56 18.90 305.48 93.38 15 1306.25 21.01 303.77 93.69 16 1400.84 23.72 303.72 17 1496.30 25.29 305.98 18 1587.90 27.29 305.07 19 1683.18 29.02 304.41 20 1776.01 31.43 302.92 94.59 95.46 91.60 95.28 92.83 21 1869.22 33.77 301.80 93.21 22 1964.67 33,73 301.70 95.45 23 2059.72 36.09 299.93 95.05 24 2152.25 39.54 300.97 92.53 25 2242.56 42.82 301.62 90.31 26 2339.84 45.89 303.50 27 2434.94 49.99 305.10 28 2529.15 53.15 305.88 29 2622.35 55.87 306.58 30 2716.28 58.36 306.28 97.28 95.10 94.21 93.20 93.93 27-Aug-2001 15:39:23 TVD Vertical Displ Displ depth section +N/S - +E/W- (ft) (ft) (ft) (ft) 0.00 113.54 199.15 295.06 383.87 475.69 564.78 653.51 743.86 835.02 927.52 1017.43 1109.80 1198.85 1286.91 1374.37 1461.24 1543.36 1627.36 1707.56 1786.09 1865.45 1943.39 2016.48 2084.44 2153.99 2217.69 2276.24 2330.34 2381.34 Total displ (ft) 0.00 0.00 0.00 0.00 -0.13 -0.08 -0.29 0.30 -0.58 -0.44 -0.84 0.95 -0.91 -0.53 -2.12 2.19 0.12 0.95 -4.54 4.64 Page 2.68 4,30 -8.71 9.72 5.93 8.60 -14.17 16.57 9.77 13.70 -20.74 24.85 14.10 19.66 -29.25 35.24 18.94 26.64 -40.59 48.55 At Azim (deg) 0.00 255.15 242.63 255.86 281.83 296.29 301.26 303.45 303.90 303.28 25.41 35.79 -54.79 65.44 303.15 33.68 47.18 -71.17 85.39 303.54 43.89 61.21 -91.27 109.90 303.85 55.66 77.35 -114.24 137.96 304.10 68.80 95.50 -140.56 169.93 304.19 83.11 115.49 -170.48 205.92 304.11 99.57 138.13 -202.96 245.50 304.24 116.85 161.69 -235.98 286.06 304.42 135.43 187.30 -272.93 331.01 304.46 153.93 213.19 -311.83 377.73 304.36 172.77 240.05 -354.25 427.92 304.12 192.15 267.95 -399.34 480.91 303.86 211.18 295.79 -446.06 535.23 303.55 230.73 324.55 -494.95 591.87 303.25 252.03 355.45 -545.75 651.29 303.08 277.81 392.07 -603.04 719.29 303.03 306.54 431.87 -661.33 789.86 303.15 337.94 474.72 -721.41 863.59 303.35 371,11 519,57 -782.61 939,38 303.58 405.84 566.41 -846.07 1018.16 303.80 2 of 5 DLS (deg/ 100f) 0.00 0.26 0.43 0.97 1.87 1.56 0.92 1.11 1.73 2.23 2.27 2.46 2.57 3.02 2.34 2.87 1.92 2.23 1.84 2.72 2.59 0.07 2.70 3.79 3.66 3.43 4.49 3.42 2.98 2.66 Srvy tool type TIP IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR Tool qual type [(c)2001 Anadrill .IDEAL ID6 lC 10] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 27-Aug-2001 15:39:23 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 31 2808.59 60.24 305.09 92.31 2428.47 32 2904.21 60.98 304.95 95.62 2475.39 33 .3001.87 60.77 305.38 97.66 2522.93 34 3095.69 62.13 305.38 ~93.82 2567.76 35 3185.88 62.07 306.06 90.19 2609.97 94.91 96.03 95.86 92.66 93.39 36 3280.79 62.08 305.95 37 3376.82 62.77 306.50 38 3472.68 63.01 306.64 39 3565.34 63.29 304.92 40 3658.73 62.58 304.47 2654.41 2698.87 2742.55 2784.40 2826.90 2871.02 2915.76 2960.17 3005.50 3051.30 93.50 92.33 91.87 94.80 94.46 41 3752.23 61.10 303.34 42 3844.56 60.93 303.11 43 3936.43 61.26 303.14 44 4031.23 61.61 302.07 45 4125.69 60.39 301.10 439.84 474.67 510.53 545.44 579.65 616.01 653.21 690.96 726.51 760.84 793.84 825.29 856.48 888.06 918.04 946.33 973.20 1001.47 1030.14 1059.51 46 4219.41 59.66 300.30 93.72 3098.12 47 4310.05 60.22 300.39 90.64 3143.52 48 4403.92 60.06 300.86 93.87 3190.26 49 4498.62 60.31 300.61 94.70 3237.34 50 4594.71 60.81 301.10 96.09 3284.57 612.70 -910.54 660.51 -978.77 709.64 -1048.51 757.36 -1115.70 803.89 -1180.42 51 4688.47 60.51 301.03 93.76 3330.51 1088.47 52 4778.62 60.48 300.92 90.15 3374.91 1116.16 53 4873.73 60.88 300.71 95.11 3421.49 1145.21 54 4964.90 61.38 301.28 91.17 3465.51 1173.41 55 5059.29 61.32 302.29 94.39 3510.76 1203.73 853.19 -1248.26 903.49 -1316.92 954.33 -1385.45 1002.66 -1452.52 1050.00 -1520.89 95.62 94.66 92.60 92.73 95.23 1095.98 -1589.30 1140.24 -1656.86 1184.19 -1724.22 1229.05 -1794.35 1272.32 -1864.73 56 5154.91 61.75 302.73 57 5249.57 61.69 302.91 58 5342.17 61.85 303.21 59 5434.90 62.18 303.24 60 5530.13 62.26 305.05 1313.77 -1934.53 1353.40 -2002.23 1394.87 -2072.29 1436.87 -2142.91 1479.78 -2214.75 1521.96 -2284.76 1562.34 -2352.03 1604.82 -2423.25 1645.93 -2491.69 1689.56 -2562.10 1235.50 1267.41 1298.96 1330.85 1364.89 1734.74 -2632.98 1779.92 -2703.04 1824.43 -2771.41 1869.30 -2839.92 1916.59 -2909.64 3556.34 3601.19 3644.99 3688.50 3732.89 1097.49 1180.79 1266.08 1348.47 1428.15 1511.98 1597.05 1682.33 1764.97 1848.14 1930.56 2011.30 2091.70 2174.92 2257.44 2338.46 2416.74 2498.01 2580.05 2663.62 2745.27 2823.64 2906.47 2986.23 3069.03 3153.08 3236.44 3318.02 3399.91 3484.15 303.94 304.01 304.09 304.17 304.26 304.35 304.45 304.56 304.62 304.62 304.59 304.54 304.48 304.41 304.31 304.18 304.06 303.94 303 . 84 303.75 303.67 303.59 303.51 303.45 303.40 303.38 303.36 303.36 303.35 303.37 3 of 5 DLS (deg/ i00f) 2.32 0.78 0.44 1.45 0.67 0.10 0.88 0.28 1.68 0.87 1.91 0.29 0.36 1.06 1.57 1.07 0.62 0.47 0.35 0.68 0.33 0.11 0.46 0.77 0.94 0.60 0.18 0.33 0.36 1.68 Srvy tool type IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR Tool qual type [(c)2001 Anadrill IDEAL ID6 lC 10] ANADRILL SCHLL/MBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5623.32 62.62 306.21 62 5717.89 63.07 308.84 63 5812.05 63.50 312.68 64 5908.24 64.22 316.50 65 6002.59 65.20 319.56 93.19 94.57 94.16 96.19 94.35 66 6095.75 66.12 323.90 67 6187.71 66.14 327.85 68 6279.47 67.26 330.40 69 6372.21 69.77 334.12 70 6468.59 72.19 338.42 93.16 91.96 91.76 92.74 96.38 71 6545.77 77.83 338.42 72 6582.46 81.45 338.42 73 6614.74 84.50 338.42 74 6645.77 87.19 338.42 75 6676.55 88.66 338.42 TVD depth (ft) 76 6709.54 90.79 340.42 77 6739.68 91.54 343.25 78 6771.33 91.45 345.70 79 6805.89 90.93 348.89 80 6835.19 90.66 349.46 3776.00 3819.17 3861.51 3903.91 3944.22 81 6867.52 90.35 350.82 82 6901.12 89.87 353.16 83 6930.71 89.63 355.87 84 6961.42 89.63 358.50 85 6993.12 88.70 359.92 3982.63 4019.85 4056.15 4090.13 4121.55 86 7025.03 88.12 0.27 87 7056.20 88.39 1.69 88 7089.63 87.98 2.59 89 7120.63 89.66 3.84 90 7152.06 91.89 5.79 27-Aug-2001 15:39:23 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) Page 4 of 5 At DLS Sr~y Tool Azim (deg/ tool qual (deg) 100f) type type --- 1400.22 1964.71 -2976.79 3566.70 303.43 1438.71 2015.96 -3043.51 3650.63 303.52 1481.32 2070.87 -3107.20 3734.06 303.68 1529.96 2131.48 -3168.67 3818.86 303.93 1582.14 2194.90 -3225.71 3901.64 304.23 1638.29 2261.52 -3278.25 3982.64 304.60 1698.32 2331.12 -3325.41 4061.10 305.03 1761.74 2403.45 -3368.65 4138.16 305.51 1829.69 2479.82 -3408.78 4215.36 306.04 1905.18 2563.21 -3445.42 4294.29 306.65 77.18 4141.50 1968.46 2632.51 -3472.83 4357.82 307.16 36.69 4148.10 1999.10 2666.07 -3486.10 4388.71 307.41 32.28 4152.05 2026.30 2695.86 -3497.88 4416.20 307.62 31.03 4154.30 2052.57 2724.63 -3509.26 4442.81 307.83 30.78 4155.41 2078.69 2753.23 -3520.58 4469.31 308.03 32.99 4155.57 2107.00 2784.12 -3532.17 4497.50 308.25 30.14 4154.96 2133.48 2812.74 -3541.56 4522.63 308.46 31.65 4154.13 2161.96 2843.23 -3550.03 4548.26 308.69 34.56 4153.41 2193.75 2876.93 -3557.63 4575.31 308.96 29.30 4153.01 2221.08 2905.70 -3563.13 4597.72 309.20 4152.72 4152.66 4152.79 4152.98 4153.45 2251.43 2937.56 -3568.67 4622.19 309.46 2283.32 2970.82 -3573.35 4647.00 309.74 2311.79 3000.28 -3576.18 4668.05 310.00 2341.70 3030.95 -3577.69 4688.97 310.27 2372.80 3062.64 -3578.12 4709.85 310.56 2404.19 3094.54 -3578.07 4730.62 310.86 2434.93 3125.69 -3577.54 4750.65 311.14 2468.01 3159.08 -3576.29 4771.75 311.46 2498.76 3190.02 -3574.55 4791.00 311.75 2530.04 3221.33 -3571.91 4809.94 312.05 32.33 33.60 29.59 30.71 31.70 31.91 31.17 33.43 31.00 31.43 4154.33 4155.28 4156.34 4156.98 4156.55 1.17 2.52 3.67 3.64 3.11 4.36 3.93 2.83 4.61 4.91 7.31 9.87 9.45 8.67 4.78 8.86 9.71 7.74 9.35 2.15 4.31 7.11 9.19 8.56 5.35 2.12 4.64 2.96 6.75 9.42 IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - Interpolation Interpolation Interpolation Interpolation Interpolation Interpolation Interpolation IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - IFR - [(c)2001 Anadrill IDE/kL ID6 lC 10] -- -- ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 91 7217.10 91.31 5.26 65.04 92 7311.07 90.76 4.90 93.97 93 7406.56 89.45 4.49 95.49 94 7502.22 88.84 7.85 95.66 95 7596.53 91.79 14.37 94.31 4154.74 4153.04 4152.86 4154.29 4153.77 27-Aug-2001 15:39:23 Page 5 of 5 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 2594.83 2688.39 2783.42 2878.81 2973.04 96 7690.21 92.34 20.00 93.68 4150.39 3065.95 97 7786.31 91.10 20.03 96.10 4147.51 3160.63 98 7881.65 89.21 18.95 95.34 4147.25 3254.74 99 7977.83 90.14 18.82 96.18 4147.80 3349.85 100 8073.71 91.27 17.78 95.88 4146.62 3444.79 101 8165.69 89.52 17.84 91.98 4145.98 3535.97 102 8265.22 89.35 18.35 99.53 4146.96 3634.58 103 8359.50 90.35 18.36 94.28 4147.21 3727.93 104 8457.78 91.24 17.56 98.28 4145.85 3825.33 105 8554.63 89.93 16.51 96.85 4144.86 3921.50 106 8651.12 88.91 16.38 96.49 4145.84 4017.43 107 8743.57 88.15 16.13 92.45 4148.21 4109.35 108 8840.26 88.67 16.34 96.69 4150.89 4205.49 109 8936.77 90.96 17.12 96.51 4151.20 4301.39 110 9031.59 90.14 17.31 94.82 4150.29 4395.51 111 9128.26 90.28 17.54 96.67 4149.94 4491.44 112 9219.43 91.20 17.55 91.17 4148.76 4581.87 113 9313.60 90.79 18.02 94.17 4147.12 4675.23 114 9346.89 90.07 17.40 33.29 4146.87 4708.24 3286.04 -3565.65 3379.63 -3557.33 3474.80 -3549.52 3569.88 -3539.24 3662.36 -3521.08 3751.76 -3493.43 3842.01 -3460.56 3931.89 -3428.75 4022.89 -3397.62 4113.91 -3367.52 4201.47 -3339.38 4296.08 -3308.47 4385.56 -3278.78 4479.04 -3248.48 4571.63 -3220.11 4664.17 -3192.80 4752.89 -3166.93 4845.69 -3139.91 4938.11 -3112.13 5028.68 -3084.07 5120.91 -3055.12 5207.83 -3027.64 5297.48 -2998.88 5329.20 -2988.75 4760.94 5379.88 -2972.87 4146.81 4848.91 312.66 4906.78 313.53 4967.22 314.39 5026.95 315.25 5080.44 316.13 5126.38 317.04 5170.74 317.99 5216.90 318.91 5265.68 319.82 5316.43 320.70 5366.92 321.52 5422.39 322.40 5475.72 323.22 5533.03 324.05 5591.86 324.84 5652.29 325.61 5711.34 326.32 5774.06 327.06 5836.97 327.78 5899.07 328.48 5963.01 329.18 6023.96 329.83 6087.41 330.49 6110.07 330.72 6146.63 331.08 Final survey projected to total depth: 115 9400.00 90.07 17.40 53.11 1.21 0.70 1.44 3.57 7.59 6.03 1.29 2.28 0.98 1.60 1.90 O.54 1.06 1.22 1.73 1.07 0.87 O.58 2.51 0.89 0.28 1.01 0.66 2.85 0.00 IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR IFR proj [(c)2001 Anadrill IDEAL ID6 lC 10] bp Date: 09-17-2001 Transmittal Number:9224~.~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth LogType MPG-14 08-22-2001 ANADRILL 1 0 9405 lVlWD SURVEY; MPG-14L1 08-27-2001 ANADRILL 1 0 9400 MWD SURVEY; ign and Retur~ one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Lisa Weepie (AOGCC) RECEIVED SEP ?_ 1 2.001 Alaska Oil & Gas Cons. ~r: Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ALASKA OIL AND GAS CONSERYA~ION COPl~vlISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPG-14L1 BP.Exploration (Alaska) Permit No: 201-134 Sur Loc: 2015' NSL, 3446' WEL, SEC. 27, T13N, R10E, UM Btmhole Loc. 2108' NSL, 1098' WEL, SEC. 21, T13N, R10E, UM Dear Mr. Archey: Enclosed is the 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 MPG-14, Permit No, 201-133, AP1 029-23031-00. Production should continue to be reported as a function of the original API number stated above. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit MPG-14L1. Blowout prevention equipment' (BOPE) must be tested in accordance with 20AAC 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, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this '~'¢ day of July, 2001 jjc/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALA ,,-, OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [~Sirj~le Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB)' 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 61' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 315848 '¢¢¢-$-2b¢= ,,.~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2015' NSL, 3446' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 5161' NSL, 1745' WEL, SEC. 28, T13N, R10E, UM MPG-14L1 Number 2S100302630-277 At total depth 9. Approximate spud date 2108' NSL, 1098' WEL, SEC. 21, T13N, R10E, UM 07/27/01 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 025516, 1098' MDI No Close Approach 1280 9430' MD / 4136' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6496' MD Maximum Hole Angle 90 ° Maximum surface 1407 psig, At total depth (TVD) 4201'/1890 psig 18. Casing Program Specifications Setting Depth O' ,,IZ~ Tr,~ Pot om Quantitv of Cement HQle Casino WeiGht Grade CouDlina LenGth MD TVD MD TVD (include staoe data) 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 2934' 6496' 4092' 9430' 4136' LJncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor 30" 20" 260 sx Arctic Set (Approx.) 110' 110' Surface 9-7/8" 7" 762 sx PF 'L', 566 sx Class 'G' 7177' 4197' Intermediate Production LinerRECEIVED Perforation depth: measuredJUL 0 Z,001 true vertical Alaska 0il & Gas Cons. Commission Anchorage ,, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Franks, 564-4468 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foj;egoing is true and correct to the best of my knowledge ., , ' "' Signed . ..~...¢.~ ~ ¢,.~,¢~ Title Senior Drilling ~ngineer Date : ...... Permit'; .... "="Number ......... "'"" '. _ '/' "'""" :'"'1 APl' '"'"Number'"""':": ..... : .... " '""'": ' ""'" ' ,...,, ,..,;...,,;,,ii,.. ,'Ih "1" i "",;I/ ',""""',',' A~ro~vaJ"':":"'"" "' "'" "'aat~"~ '"'"'"'", ' I'"""See ........ cover'""' ' '"'"'it'"le er Z~'Y- /Z~ 150-¢;~% ,Z-_"~C%..~/'~ ~' ~::5 I '~/.~'~./L'~,' / I forotherrequirements Conditions of Approval: Samples Required [] Yes ii, No Mud Log ¢l~quir~'d [] Yes Hydrogen Sulfide Measures [] Yes ,,~No Directional Survey Required EYes [] No Required Working Pressure for POPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi,f~r CTU/ / / Other: ~O ~... T'¢¢'(" = ~ ~,'"oO ~ ~'~ by order of ~/,/~, ..~/.-~./ Approved By ORIGINAL SIGNED BY Commissioner the commission Date Form 10-401 Rev; i G l NAL , , 'replicate 1. Well Plan Summary MPG-14L1 Drillin~l Permit IWell Name: I MPG-14L1 I Type of Well (producer or iniector): I Schrader Bluff Multilateral producer- Upper leg Surface Location: G-14L1 Target: G-14L1 Target (BottOm Hole Location): 2015' FSL, 3446' FEL, SEC. 27, T13N, R10E X = 557156.65 Y = 6014450.44 5161' i:SL, 1745' FEL, SEC. 28, T13N, R10E X = 553547.67 Y = 6017570.62 Z = 4142 TVDrkb 2108' FSL, 1098' FEL, SEC. 21, T13N, R10E X = 554173.44 Y = 6019800.69 Z = 4136 TVDrkb ~ Nabors 27E J Estimated Start Date: I July 27, 2001 [MDrkb ~ 9430' ~ [ TVDrkb(TD) Operatin~l days to complete: I 12 I Max. Inc. ~ 90° ~ ~ Well Design (conventional, slim hole, etc.): I Multilateral Producer Scope: I Drill and Complete a Multilateral Producer in the Schrader Bluff OA and OB sands. Version #1,6/26/2001 MPG-14L1 Drillin~l Permit 2. Current Well Information 2.1 General 2,2 2.3 Well Name: MPG-14L1 APl Number: Well Type: Current Status: BHP: BHT: Current Mechanical MPG-14: Nabors 27E: Conductor: Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: MPG-14L1 Development- Schrader Bluff Multilateral Producer- upper leg Conductor Set 1890 psi @ 4201' TVDrkb Top of Schrader Bluff OB Sands. 80°F @ 4000' TVDss Estimated (SOR) Condition Cellar Box above MSL = 29.5' KB / MSL = 31.5' 20", 92 Ib/ft, H-40 Welded set at 80' MD 1.4MMBBL 2860 BOPD 84O BOPD MPG-14L1 Drillin~l Permit 3. Drilling Hazards and Contingencies 3.1. Well Control 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. 3.2. Kick Tolerance 3.2.1. The Kick Tolerance for the production casing based on the 8.65 expected pore pressure is infinite. 3.3. Lost Circulation 3.3.1. Lost circulation has occurred in the pre-1997 wells drilled on G-pad when displacing the cement. Surface casings for these occurrences were set at just below the base of the permafrost indicating a week shoe. Since 1997, no signs of lost circulation have been encountered. 3.3.2. 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 Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be 1890 psi (8.65 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.2-ppg mud. 3.5. Stuck Pipe 3.5.1. Sticky clays have been seen when drilling from the base of the permafrost down to the Schrader Bluff. Along with the sticky clays is the possibility of tight hole in the interval from the permafrost to TD of the well. Frequent wiper trips may be required while drilling the interval. In all the wells drilled after 1997 on G-pad, no instances of stuck pipe have been seen. 3.5.2. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the M-I mud program must be closely followed. 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. Pad Data Sheet 3.6.1. Please Read the G-Pad Data Sheet thoroughly. MPG-14L1 Drilling Permit 3.7, 3.11 Hydrocarbons 3.7.1. Hydrocarbons will be encountered in the Schrader Bluff intervals. Hydrogen Sulfide 3.11.1. MPG Pad is not designated as an H=S Pad. Below is a summary of the most recent readings: Well G- Well Type H2S Status Date taken li SBF Inj Injector Feb 2000 2 SBF Prod <2.00 June 2001 3i SBF Inj <2.00 Apr 2000 4 SBF Prod <2.00 June 2001 5i SBF Inj Injector Feb 2000 6 SBF Prod <2.00 June 2001 7i SBF Inj Shut in Feb 2000 8 SBF Prod <2.00 June 2001 9i SBF Inj Injector Feb 2000 10 Long Term Shut in Feb 2000 11 SBF Prod <2.00 June 2001 12 SBF Prod <2.00 June 2001 13i SBF Inj Injector Feb 2000 15 SBF Prod <2.00 June 2001 4. Drilling Program Overview MPG-14L1 Drillin~l Permit 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 MPG-14 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 Max Exp Surface Pressure BOPE Ratin~l Planned BOPE Test Pres. 1890 psi @ 4201' 1407 psi 13 5/8" 5M Rams & Valves: 3500 psi/250 psi TVDrkb (estimated) (0.115 psi/ft ~las ~lradient) Annular: 2500 psi/250 psi 4.3. Mud Program 6-1/8" Production Hole Mud Properties: OA/OB Densit¥(pp~l) I Funnelvisc I YP HTHP 9.2 40 - 55 22 - 27 < 10 KCI-CaCO3 FIoPro pH APl Filtrate I LG Solids 8.0-8.5 4-6I < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. 4.4. Formation Markers Formation Tops ft MD ft TVDrkb Pore (psi) EMW (ppg) Base Permafrost 1861 1800 Top U[~nu 5033 3475 1563 8.65 Top Ugnu M 5839 3850 1732 8.65 Schrader-NA 6081 3952 1778 8.65 Schrader-NB 6162 3983 1792 8.65 Schrader-NC 6247 4014 1805 8.65 Schrader-NE 6309 4035 1815 8.65 Sch rader-N F 6450 4079 1835 8.65 TSBD-OA 6576 4113 1850 8.65 TSBC - Base OA 6714 4144 1864 8.65 TSBB-OB 6966 4183 1882 8.65 TD 9430 4136 1860 8.65 MPG-14L1 Drilling Permit 4.5. Casing/Tubing Program Hole Size Csg! Wt/Ft Grade Conn Length Top Bottom Tb~ O.D. MD ! TVDrkb MD / TVDrkb 30" 20" 92# H-40 Welded 80' 30' / 30' 110' / 110' 9-7/8" 7" 26# L-80 BTC 6466' 30' / 30' 6496'/4092' 6-1/8" 4-1/2" Slotted 12.6# L-80 IBT-Mod +/- 2934' 6496' / 4092' 9430'/4136' Tubin~l 2-7/8" 6.3# L-80 EUE-Mod +/- 6081' 30' / 30' 6081' / 3952' 4.6. Cement Calculations None Required 4.7. Survey and Logging Program 6-1/8" Hole Section: Open Hole: Cased Hole: MWD / DIR(IFR) / ABGR / Res ! PWD / ABI Res placed as close to bit as possible. None 5. MPG-14L1 Operations Summary MPG-14L1 Drilling Permit 5.1. Pre-Rig Operations 1. Drill and run casing in the lower OB lateral. 5.2. Procedure . . 3. 4. 5. 6. 7. 8. 9. 1 1 1 1 1 1 1 1 1 O. 1. 2. 3. 4. 5. 6. 7. 8. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7" casing. RIH. Displace hole to clean Bara Drill mud Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain FIoPro mud properties. POOH. Reamer trip with Hole Opener to TD. Displace OA lateral with clean FIoPro mud MU whipstock retrieving tool and pull whipstock Run 4 Y2" slotted liner with 2 N" inner string, Baker Hook Hanger and hang off in 7" casing POOH laying down 3 Y2" 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 MPG-14L1 Drillin~l Permit 6. MPG-14L1 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 %" tubing. 5. Make up the ESP completion and run in on the 2 %" 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. C~)MI'ANY DETAILS REFERENCI': INFORMATION SURVEY PR(X~RAM Plan: MPG-Jc4hrt~ Li v~ll (MPG-141MI'(i-Jc{hr,, '" BP Am~n.~.~ Co-~nlirale (N/E) RercTence: WeB Cm~: M~-14, T~ No~ ~ ~?~ T~ Sg'~bn Tm~l Crc-alc~ By: Ken AIIc~ I)alc: 6~2. Vcflkal ~} Reft: Pbn M~-Je~ 61.~ 61.~ C~l~ ~M~: Min~C~ ~Re~ Sk~- 14 (0_~N.O.~ ~ ~ 9430~0 Pb~ M~JL~I,I ~l VI MWI}~IF~MS Chc~k~: Dale: Em,r S~m: ISCWSA M~s~ ~ Ref~ Pbn M~-J~, 61.~ 61.~ ~n Mc~: T~v Cyl~No~ CalciUm Me~ M~C~ Rcvicwt~: Dalg: F~r S~: Ell~l + C~ Wami~ M~: Ru~ B~ ~OTATIONS FOX, ON TOP D~LS W~LL DE~AILS NO. TVD MD A~otation No. TVDPath MDPath Fo~ation ~-I~ ~.~  0~ 092.14 6496.00 Sta~ Dir 8~/100': 6496' MD, 4092.14'TVD I 4113.00 6596.78 TSBD-OA 116.59 6627.50 End Dir: 6627.5' MD, 4116.59' TVD 3 120.47 6668.15 Sta~ Dir 6°/100': 6668.15' MD, 4120.47~ 4 142.00 7110.53 Sta~ Dir 4~/100': 7110.53' MD, 4142~D CAS~G D~LS ~ARGETDE~AID~ 5 140.53 7485.82 End Dir: 7485.82' MD, 4140.53'TVD ~ ~D +n'-s ~t~.w n,~i,s ~ s~ 6 13S.ll 8181.79 Sta~Dir4°/100':8181.79'MD, 4135.11~VD No. ~ MD N~e Size 7 135.00 8209.28 Sta~ Dir 3~/100': 8209.28' MD, 4135'TVD M~-)~,L~ ~4~.~ ~ .~.7~ ~t~70.~ ~.~,~ ~,,~ M~-)~LI 4135.~ 4199.~ .~]75.76 ~186Z~.65 553~9.5fi P~,inl 8 135.03 8284.11 End Dir : 8284.11' MD, 4135.03'TVD I 4136.00 9430.19 4 1/2" 4.500 9 136.00 9430.19 Total Depth: 9430.2' MD, 4136' TVD 250~ SE~ION D~AILS ec MD lnc Azi TVD +N/-S +~-W DLeg TFace VSec Target All TVD depths are 4 +.00 74.0 ~ 6627.50 84.52 337.99 4116.59 2678.16 -3502.27 8.00 -4.64 4030.64 n, 0.47 0.00 0.00 no o. 4 · z 7110.53 90.00 4.00 4142.00 3148.22 -3585.75 6.00 78.92 4483.07 MPG-JelhroLI ti 7485.82 90.45 19.01 4140.53 3514.92 -3511.13 4.00 88.28 4768.94 8181.79 90.45 19.01 4135.11 4172.93 -3284.49 0.00 0.00 5237.38 300~ 8209.28 90.00 18.00 4135.00 4199.00 -3275.76 4.00 -113.94 5256.06 MPG-Jethro LI t2 8284.11 89.95 15.76 4135.03 4270.60 -3254.04 3.00 -91.24 5308.45 ~ 9430.20 89.95 15.76 4136.00 5373.63 -2942.84 0.00 0.00 6126.68 MPG-Jelhro LI t3 ~ ~0~ " · ~ St~ Dir 8°/I00': 6496' MD, 4092.14~VD ~ ~ ~ ~ St~ Dir 4°/100': 8181.79' MI),:.4135.11'TVD ~ / ~ EndDir ~6627.5'MD 4116.59'~D ~ ~ St~nDir3o/lOO':8209.28'Ml),4135~VD ::/ ~ ~ : ~ ~ ~ / ~/ - ' / / StaiDlY6°/100' 6068 '5'MD 4120.47~VD / / EddDir :8284.,1~MD, 4135:03'TVD 400~ '" ' "'"'" ~'~ :'/-- 7"~'-'""-; ~: : ~ [ C/ / ~ ~ ........... ~ ....... ~['~"~ ~'~0.2' MD, 4136' TVD - '. ": ...... ~:' :::'. ?~-~Z~..._~.~;:~::-'-'. '.'-~-::.- :: ~ ·:-': ' ' ::::::::::::::::::::::::::::::: ":~ ~ . i~' .;g~.:..;.~.'.':ZL...L._.....:_._:..;ZL:L~:L~..Z..;.... ~:.-..~ '~ ' ~ ~ 450~ ~ ~ ~ '....._~ ~ rind D}r: 7485.82' MI), 41~0.53' ~VD :. ~ ~ ~ Stad Dir 4°/106': 71h0.53' MD, 4142'TV6 : ~ ~ : ~ ~ , I , , I ' I , , I i , .... i .... i ~ ...... i , i 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Ve~ical Section at 331.31° [500~in] 5500- .................................................. 5000- · 4500- - 4000- /. !. .,, : 3500- 300O- 2500 -4000 REFERENCE I~FORMATION Coqmlinale OWE) Ref~x-nc~ Well C~: MPG-14, True Noflh Veflical O'VD) Refinenc~: Plan MPG-lelhm 61.ff 61.00 S~lion (VS) Re.~'in:rsce: Sh'~ - 14 (0.00N,0.O0E) Mcas~xl D~l~h Re re~..nck-: Plan MPG-b.ahto 61.0' 61.00 Calculation Me~h~d: Minim,.nnCtr~atum ..~!_l~epth: 9430.2' MD, 4136' TVD .'.......i MPG-1'ethro LI,; i / ........ ~... / / / : / .......... J ..... · xye I.I I' MD, 4135.03' TVD !-'¢ I?t?: 8209.28' MD, 4135'TVD MPG-Icftu,, l.i 12 I':ld Dir:: 7485.8~.i V IL ,I i tc.53' TVD MPG}JChro L] ii $1 :'t Dir 6'/100': 66¢,q . q M I '~, 4120.47'TVD ...... O~ Start Dir 8°/101~': ~ 4:;t.' MI), 4092.14'TVD t i t i { i t i SURVEY PROGRAM Deplh To Sum'y/Plan Ttn,I 943020 Planned: MP(;-Jethn} I.I v.?OI VI MWI)+IF'RsMS Plan: Ml'O-Jethm I.I wl~ll (MI'O-I4/MPG-Jclhm '" Cn:atc~l By: Ken Allm I)alc: 612 C~ckc~: Dale: ~ Rcvic~c~: Dale: ~ Wlil.I. I)ETAIL"; ~ +N/-S *B-W N,,~8 I~ir~ taljtUdl/ l,on~it.d,2 .qk,[ MPG-14 2718.16 780.58 6014450_t0 55715'/.11 70"2TO0.417N 149°~2'01.238W 14 ] ARGET I)ETAII2.; ~ 1¥D ' N/-.';; q-Y.W N,,~thinff Ea~ing MPG-Juthn, I.I 11 4142.O0 314822 -3585.75 6017570.62 553547.67 Psfinl ~dP(J-Jethm LI 12 4135.00 4199.00 -3275.76 6Ol8623.65 553M9.56 I't,int MpG-Je~hm LI O 4136.00 5373.63 .2942.84 6O1986O.69 554173.44 I',,inl MPG-Iclhm Pol)'glna 4198.00 5596.64 -3204.D1 6o20021.66 553910.41 I'oly8~m SECTION DETAILS cc MD lnc Azi TVD +N/-S +E/-W DLcg TFace VSec Target 6496.00 74.03 338.84 4092.14 2558.19 -3454.79 0.00 0.00 3902.62 6627.50 84.52 337.99 4116.59 2678.16 -3502.27 8.00 -4.64 4030.64 6668.15 84.52 337.99 4120.47 2715.68 -3517.44 0.00 0.00 4070.84 7110.53 90.00 4.00 4142.00 3148.22 -3585.75 6.00 78.92 4483.07 MPG-Jelhro LI ti 7485.82 90.45 19.01 4140.53 3514.92 -3511.13 4.00 88.28 4768.94 8181.79 90.45 19.01 4135.11 4172.93 -3284.49 0.00 0.00 5237.38 8209.28 90.00 18.00 4135.00 4199.00 -3275.76 4.00 -113.94 5256.06 MPG-Jethro LI 12 8284.11 89.95 15.76 4135.03 4270.60 -3254.04 3.00 -91.24 5308.45 9430.20 89.95 15.76 4136.00 5373.63 -2942.84 0.00 0.00 6126.68 MPG-Jelhro LI 13 All TVD depths are ssTVD plus 61' for RKBE. ANNOTATIONS No. TVD MD Annotation I 4092.14 6496.00 Start Dir 8°/100': 6496' MD, 4092.14'TVD 2 4116.59 6627.50 End Dir: 6627.5' MD, 4116.59' TVD 3 4120.47 6668.15 Start Dir 6~/100': 6668.15' MD, 4120.47'TVD 4 4142.00 7110.53 Start Dir 4'7100': 7110.5Y MD, 4142'TVD 5 4140.53 7485.82 End Dir : 7485.82' MD, 4140.53'TVD 6 4135.11 8181.79 Start Dir 40/100': 8181.79' MD, 4135.11'TVD 7 4135.00 8209.28 Start Dir 3°/100': 8209.28' MD, 4135'TVD 8 4135.03 8284.11 EndDir : 8284.11' MD, 4135.03'TVD 9 4136.00 9430.19 Total Depth: 9430.2' MD, 4136'TVD CASING DETAILS No. TVD MD Name I 4136.00 9430.19 4 I/2" FORMATION TOP DETAILS No. TVDPath MDPath Formation 4113.00 6596.78 TSBD-OA Size 4.500 -2500 -2000 -1500 -1000 -500 0 500 West(-)/East(+) [500ti/in] BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt (3 Pad Well: MP(3-14 Wellpath: MPG-Jethro L1 Date: 6/26/2001 Time: 11:11:40 Co-ordinate(NE) Reference: Well: MPG-14, True North Vertical (TVD) Reference: Plan MPG-Jethro 61.0' 61.0 Section (VS) Reference: Well (0.00N,0.00E,331.31Azi) Plan: MPG-Jethro L1 wp01 Page: 1 Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2001 Site: M Pt G Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6011726.58 ft Latitude: 70 26 33.685 N 556397.19 ft Longitude: 149 32 24.162 W North Reference: True Grid Convergence: 0.43 deg Well: MPG-14 MPG-14 Surface Position: +N/-S 2718.16 ft +E/-W 780.58 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 2718.16 ft +E/-W 780.58 ft Slot Name: 14 Northing: 6014450.30 ft Latitude: 70 27 0.417 N Easting: 557157.11 ft Longitude: 149 32 1.238 W Northing: 6014450.30 ft Latitude: 70 27 0,417 N Easting: 557157.11 ft Longitude: 149 32 1.238 W Measured Depth: 31.50 ft Inclination: 0.00 deg Vertical Depth: 31.50 ft Azimuth: 0.00 deg Wellpath: MPG-Jethro L1 Drilled From: MPG-Jethro Tie-on Depth: 6496.00 ft Current Datum: Plan MPG-Jethro 61.0' Height 61.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/26/2001 Declination: 26.25 deg Field Strength: 57457 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 331.31 Plan: MPG-Jethro L1 wp01 Date Composed: 6/26/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information : '::MD' 'lncl .'Azim' :: '" 'TVD:. ' +N/S' ' '+E/-W ::: ..:.DES. ' .. Build · '" Turn '. : '.TFO. ' '.·Target ' ' "' ..:.:~' '..;ft · :.deg · .deg :' ".ft' . :'" '.ft.. · 'ft..... deg/100ft'deg/i00ft deg/!00ft..deg: ~.'..." ":' : ~': . .. .' 6496.00 74.03 338.84 4092.14 2558.19 -3454,79 0.00 0.00 0.00 0.00 6627.50 84.52 337.99 4116.59 2678.16 -3502.27 8.00 7.97 -0.65 -4.64 6668,15 84.52 337.99 4120.47 2715.68 -3517.44 0.00 0.00 0.00 0.00 7110.53 90.00 4.00 4142,00 3148.22 -3585.75 6.00 1.24 5.88 78.92 7485.82 90.45 19.01 4140.53 3514.92 -3511.13 4,00 0.12 4.00 88.28 8181.79 90.45 19.01 4135.11 4172.93 -3284.49 0.00 0.00 0.00 0.00 8209.28 90.00 18.00 4135.00 4199.00 -3275.76 4.00 -1.62 -3.66 -113.94 8284.11 89.95 15.76 4135.03 4270.60 -3254.04 3.00 -0.06 -3,00 -91.24 9430.20 89.95 15.76 4136.00 5373.63 -2942.84 0.00 0.00 0.00 0.00 MPG-Jethro L1 tl MP(3-Jethro L1 t2 MPG-Jethro L1 t3 Section I: Start "'.MD' · Incl . Azim · '. ..TvD. · ': ~N/-S' '. '" +E/-w . ' iVS'" ":DLS ' · .Build ':~::TUrn'' :.'" .:TFO' .: :... : .ft deg 'deg' .. ::ft :.. ft . ....ft . ~: :ft deg/!.0Oft.deg/lOOft..deg!!OOft· ':deg. ... .. 6496.00 74.03 338.84 4092.14 2558.19 -3454.79 3902.61 0.00 0.00 0.00 0.00 6500.00 74.35 338.81 4093.23 2561.78 -3456.18 3906.43 8.00 7.97 -0.67 -4.64 6550.00 78.34 338.48 4105.03 2607.02 -3473.87 3954.61 8.00 7.97 -0.66 -4.63 6600.00 82.32 338.16 4113.43 2652.82 -3492.07 4003.52 8.00 7.98 -0.64 -4.55 6627.50 84.52 337.99 4116.59 2678.16 -3502.27 4030.65 8.01 7.99 -0.63 -4.49 BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt G Pad Well: MPG-14 ,_~_e_ I/_p aj~!..___ .M_. _P_G -J__e_t~ r ~o_ _L?_ ..... Date: 6/26/2001 Time: 11:11:40 Co-ordinate(NE) Reference: Well: MPG-14, True North Vertical (TVD) Reference: Plan MPG-Jethro 61.0' 61.0 Section CVS) Reference: Well (0.00N,0.00E,331.31Azi) Plan: MPG-Jethro L1 wp01 Page: 2 Section 2: Start MD Azim I ft ~ TVD +N/-S +E/-W VS DLS Build T,rn TFO .................................... d_e_g~ ...... ~ ............ ~ ........ ft ft deg/100ft deg/100ft deg/100ft dog 16668.15 84.52 337.99 4120.47 2715.68 -3517.44 4070.84 0.00 0.00 0.00 0.00 Section 3: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft fl ft deg/100ft deg/100ft deg/100ft deg 6700,00 84.89 339,87 4123,41 2745,27 -3528,84 4102.28 6.00 1.16 5,91 78.92 6750,00 85,48 342,82 4127,61 2792,47 -3544,77 4151,33 6,00 1,18 5,90 78,75 6800,00 86,09 345,77 4131,28 2840,47 -3558,27 4199,91 6,00 1,21 5,89 78,50 6850,00 86,70 348.71 4134,43 2889,14 -3569.28 4247,89 6,00 1,23 5.88 78.28 6900,00 87,32 351,65 4137,04 2938,33 -3577,80 4295,14 6,00 1,25 5,88 78,10 6950,00 87,95 354,59 4139,10 2987,92 -3583,78 4341,51 6,00 1,26 5,87 77,94 7000,00 88,59 357,52 4140,61 3037,78 -3587,22 4386,90 6,00 1,27 5.87 77,82 7050,00 89,23 0,45 4141,56 3087,75 -3588,10 4431,16 6,00 1,28 5,86 77,73 7100,00 89,87 3,38 4141,96 3137,72 -3586,43 4474,19 6,00 1,28 5,86 77,68 7110,53 90,00 4,00 4142,00 3148.22 -3585,75 4483.08 5,99 1,25 5.86 77,91 Section 4: Start ;: == D: lnC/degAZim T¥D:ft +N/-Sft +E/-Wft ¥Sft : deg!100ft deg/100fl deg/100ft d:eg ..................................... 7200.00 ~'~)'.11 7.58 414i;92 3237.22 -3576.73 4556.82 4.00 0.12 4.00 88.28 7300.00 90.23 11.58 4141.62 3335.81 -3560.10 4635.32 4.00 0.12 4.00 88.28 7400.00 90.35 15.57 4141.13 3432.99 -3536.63 4709.31 4.00 0.12 4.00 88.30 7485.82 90.45 19.01 4140.53 3514.92 -3511.13 4768.94 4.01 0.12 4.00 88.24 Section 5: Start MD Incl Azim TVD. ' +N/-S +E/-W VS DLS ..' ~B.u'ild. Turn ~"TFO .~ · ft.. deg deg ft ft ft. ft deg/100ft .deg!100ft deg/!00ft 'deg 7500,00 90,45 19,01 4140,42 3528,33 -3506,51 4778,49 0,00 0,00 0,00 0,00 7600,00 90,45 19,01 4139,63 3622,87 -3473,94 4845,79 0,00 0,00 0,00 0,00 7700,00 90,45 19,01 4138,85 3717,41 -3441,37 4913,09 0,00 0,00 0,00 0,00 7800,00 90,45 19,01 4138,06 3811,96 -3408,79 4980,39 0,00 0,00 0,00 0,00 7900.00 90.45 19,01 4137,28 3906,50 -3376,22 5047,69 0,00 0,00 0,00 0,00 8000,00 90,45 19,01 4136,49 4001,04 -3343,65 5114,99 0,00 0,00 0,00 0,00 8100,00 90,45 19,01 4135,71 4095,59 -3311,08 5182,29 0,00 0,00 0,00 0,00 8181,79 90.45 19,01 4135,11 4172,93 -3284,49 5237,38 0,00 0,00 0,00 0,00 Section 6: Start MD .Incl Azim TVD '+N/-S +E/~W VS DLS.. ::.BUild ··Turn· · .TFO ..... .: ';' ft' deg deg .: 'ft · ft ft ft 'deg/100ft:.deg/!00ft deg/100ft .deg .... '. 8209.28 90.00 18.00 4135.00 4199.00 -3275.76 5256.06 4.02 -1.64 -3.67 -114.01 Section 7: Start ~; MD ;::: Incli~::: : :: Azim: :;;:: :: :TvD ; :-t-N/,S: ;+E/~W VS: :;:;:DES ::; :;TFO:: ;: ;: :;;:: =~ ft deg. deg ft ft · ft ft deg/100ft deg/100ft deg/100ft . deg. 8284.11 89.95 15.76 4135.03 4270.60 -3254.04 5308.44 2.99 -0.07 -2.99 -91.28 Section 8: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg .deg ft . ft ft ft deg/100ft deg/;100ft d.eg/100ft deg .... ~ .................. ,.; ..................... ~ ............................. ~ ............ ~ .................... ~ ................ ~ ............ ; ...... ~ ....... ..;......._~ ....... .;._.~._,,.~ ....... ~ .............................................. ~ 8300,00 89,95 15,76 4135,04 4285,89 -3249,72 5319,79 0,00 0,00 0,00 0,00 8400,00 89,95 15,76 4135,13 4382,13 -3222,56 5391,18 0,00 0,00 0,00 0,00 8500,00 89,95 15.76 4135,22 4478,37 -3195,40 5462,56 0,00 0,00 0,00 0,00 8600,00 89,95 15,76 4135,31 4574,61 -3168,24 5533,95 0,00 0,00 0,00 0,00 8700,00 89.95 15,76 4135,39 4670,86 -3141,08 5605,34 0,00 0,00 0,00 0,00 8800,00 89,95 15,76 4135,48 4767,10 -3113,92 5676,73 0,00 0,00 0,00 0,00 8900 00 89 95 15,76 4135,57 4863,34 -3086,76 5748,12 0,00 0,00 0,00 0,00 9000,00 89.95 15.76 4135,65 4959.58 -3059.60 5819.50 0.00 0,00 0,00 0,00 I_.... 91___0_?._0.0 ......... ..8_9._.9_5_ .............. !.5:_7..6 ......... _4_1_.3_5.._7.4.. ............ 75__5_:8__2. .... .-__3__0..32._4_~ ...... 5870:.8._9 ............ _0_._0_..0. ........... _0.0__0_ ..... _0_._0.._0. ............. 0_:__0_0_ ................................... BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt G Pad Well: MPG-14 Wellpath: MPG-Jethro L1 Section 8: Start Date: 6/26/2001 Time: 11:11:40 Page: 3 Co-ordinate(NE) Reference: Well: MPG-14, True North Vertical (TVD) Reference: Plan MPG-Jethro 61.0' 61.0 Section (VS) Reference: Well (0.00N,0.00E,331.31Azi) Plan: MPG-Jethro L1 wp01 MD incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 9200.00 89.95 15.76 4135.83 5152.06 -3005.28 5962.28 0.00 0.00 0.00 0.00 ' 9300.00 89.95 15.76 4135.92 5248.30 -2978.12 6033.67 0.00 0.00 0.00 0.00 9400.00 89.95 15.76 4136.00 5344.54 -2950.95 6105.06 0.00 0.00 0.00 0.00 9430.20 89.95 15.76 4136.00 5373.63 -2942.84 6126.68 0.00 0.00 0.00 0.00 Survey Map Map <-- Latitude ---> <-- Longitude MD lncl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg ~deg ft ft ft ft ft 6496.00 74.03 338.84 4092.14 2558.19 -3454.79 6016981.67 553683.14 70 27 25.569 N 149 33 42.732 W 6500,00 74.35 338.81 4093.23 2561.78 -3456.18 6016985.25 553681.72 70 27 25.604 N 149 33 42,773 W 6550.00 78.34 338.48 4105.03 2607.02 -3473.87 6017030,35 553663.69 70 27 26.049 N 149 33 43,294 W 6600.00 82.32 338.16 4113.43 2652.82 -3492.07 6017076.00 553645.14 70 27 26.499 N 149 33 43.829 W 6627.50 84.52 337.99 4116.59 2678.16 -3502.27 6017101.26 553634.75 70 27 26.749 N 149 33 44.129 W 6668.15 84.52 337.99 4120.47 2715.68 -3517.44 6017138.66 553619.29 70 27 27.117 N 149 33 44.575 W 6700.00 84.89 339.87 4123.41 2745.27 -3528.84 6017168.17 553607.66 70 27 27.408 N 149 33 44.910 W 6750.00 85.48 342.82 4127.61 2792.47 -3544.77 6017215,24 553591.37 70 27 27.873 N 149 33 45.379 W 6800.00 86.09 345,77 4131.28 2840.47 -3558.27 6017263.13 553577.51 70 27 28.345 N 149 33 45.776 W 6850.00 86.70 348.71 4134.43 2889.14 -3569.28 6017311.70 553566.12 70 27 28.823 N 149 33 46.101 W 6900.00 87.32 351.65 4137.04 2938.33 -3577.80 6017360.82 553557.23 70 27 29.307 N 149 33 46,351W 6950.00 87.95 354.59 4139.10 2987.92 -3583.78 6017410.36 553550.87 70 27 29.795 N 149 33 46.528W 7000.00 88.59 357,52 4140.61 3037.78 -3587.22 6017460.18 553547.05 70 27 30.285 N 149 33 46.630W 7050.00 89.23 0.45 4141.56 3087.75 -3588.10 6017510.15 553545.78 70 27 30.776 N 149 33 46.656W 7100.00 89.87 3.38 4141.96 3137.72 -3586.43 6017560.12 553547.07 70 27 31.268 N 149 33 46,608W 7110,53 90.00 4.00 4142.00 3148.22 -3585.75 6017570.63 553547.67 70 27 31.371 N 149 33 46.588W 7200.00 90.11 7.58 4141,92 3237.22 -3576.73 6017659.68 553556.01 70 27 32.246 N 149 33 46.324W 7300.00 90.23 11.58 4141.62 3335.81 -3560.10 6017758.38 553571.88 70 27 33.216 N 149 33 45.837W 7400.00 90.35 15.57 4141.13 3432.99 -3536.63 6017855.74 553594.60 70 27 34.172 N 149 33 45.149W 7485.82 90.45 19.01 4140.53 3514.92 -3511.13 6017937.85 553619.47 70 27 34.978 N 149 33 44,401W 7500.00 90.45 19.01 4140.42 3528.33 -3506.51 6017951.29 553623.98 70 27 35.110 N 149 33 44.265W 7600.00 90.45 19.01 4139.63 3622.87 -3473.94 6018046.07 553655.83 70 27 36.040 N 149 33 43.310W 7700.00 90.45 19.01 4138.85 3717.41 -3441.37 6018140.85 553687.67 70 27 36.970 N 149 33 42.354W 7800.00 90.45 19.01 4138.06 3811.96 -3408.79 6018235.63 553719.51 70 27 37.900 N 149 33 41.398W 7900,00 90.45 19.01 4137.28 3906.50 -3376.22 6018330.42 553751.36 70 27 38.830 N 149 3340.442W 8000.00 90.45 19.01 4136.49 4001.04 -3343.65 6018425.20 553783.20 70 27 39.759 N 149 33 39.486W 8100.00 90.45 19.01 4135.71 4095.59 -3311.08 6018519.98 553815.04 70 27 40.689 N 149 33 38.531W 8181.79 90.45 19.01 4135.11 4172.93 -3284.49 6018597.52 553841.03 70 27 41.450 N 149 33 37.750W 8209.28 90.00 18.00 4135.00 4199.00 -3275.76 6018623.65 553849.56 70 27 41.707 N 149 33 37.494W 8284.11 89.95 15.76 4135.03 4270.60 -3254.04 6018695.41 553870.73 70 27 42.411N 149 33 36.857W 8300.00 89.95 15.76 4135.04 4285,89 -3249.72 6018710.73 553874.93 70 27 42.561N 149 33 36.730W 8400.00 89.95 15.76 4135.13 4382.13 -3222.56 6018807.17 553901.35 70 27 43.508 N 149 33 35.933W 8500.00 89.95 15,76 4135.22 4478.37 -3195.40 6018903,61 553927.77 70 27 44.455 N 149 33 35.136W 8600.00 89.95 15.76 4135.31 4574.61 -3168.24 6019000.04 553954.19 70 27 45.401N 149 33 34.339W 8700.00 89.95 15.76 4135.39 4670.86 -3141.08 6019096.48 553980.61 70 27 46.348 N 149 33 33.542W 8800.00 89.95 15.76 4135.48 4767.10 -3113.92 6019192.92 554007.03 70 27 47.294 N 149 33 32.746W 8900.00 89.95 15.76 4135.57 4863.34 -3086.76 6019289.35 554033.45 70 27 48.241 N 149 33 31.949W 9000.00 89.95 15.76 4135.65 4959.58 -3059.60 6019385.79 554059.87 70 27 49.188 N 149 33 31.152W 9100.00 89.95 15.76 4135.74 5055.82 -3032.44 6019482.23 554086.28 70 27 50.134 N 149 33 30.354W 9200.00 89.95 15.76 4135.83 5152.06 -3005.28 6019578.66 554112.70 70 27 51.081N 149 33 29.557W 9300.00 89.95 15.76 4135.92 5248.30 -2978.12 6019675.10 554139.12 70 27 52.027 N 149 33 28.760W 9400.00 89.95 15.76 4136.00 5344.54 -2950.95 6019771.54 554165.54 70 27 52.974 N 149 33 27.963W 9430.20 89.95 15.76 4136.00 5373.63 -2942.84 6019800.69 554173.43 70 27 53.260 N 149 33 27.725W BP Amoco Anticoilision Report Company: BP Amoc. o Date: 6126/2001 Time: 10:53:29 Page: I Field: Milne Point Reference Site: M Pt G Pad Co-ordinate(NE) Reference: Well: MPG-14, True North Reference Well: MPG-14 Vertical (TVD) Reference: Plan MPG-Jethro 61.0' 61.0 .~_e_f~.r.e_n~e___.W_.e._Hp_.a_~:__..M__P_..G_:J_e_~ro._L_?' ........... Db: Oracle 'G'L~i~-~L-S'~'~--~'~-~-E~- ~'l~-~i-~-t~'~-~v~-i~"~-+ ~-0--~-0~-~)-~-~e~'~n~e .......... ~'~-t~'~-~:-~-.· ....................... Principal ~i~ &"~L~NI~E-D-~R6~RAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 6496.00 to 9430.20 ft Scan Method: Trav Cylinder North Maximum Radius: 1139.87 ft Error Surface: Ellipse + Casing Date: 612612001 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name 31.50 500.00 Planned: MPG-Jethro kl wp01 V1 CB-GYRO-SS Camera based gyro single shots 500.00 64~.00 Planned: MPG-Jethro L1 wp01 V1 MWD+IFR+MS MWD + IFR + Multi Station 6496.00 0430.20 Planned: MPG-Jethro kl wp01 V1 MWD+IFR+MS MWD + IFR + Multi Station .................................................................................................................................................................................................. Casing Points MD TVD Diameter Hole Size Name .... ! 9 4 ? ........ .................. ............ Summary -'~. ......................................................... Offset Weilpath -2~:--'i-i:'~--'-~'-----~ ............................ --~efere~ ...... O---~s-~ ...... Site Well Wellpath MD MD Distance Area Deviation Warning ff ft ft ff ft M Pt G Pad MPG-04 MPG-04 Vl Out of range M Pt G Pad MPG-05 MPG-05 Vl Out of range M Pt G Pad MPG-06 MPG-06 V1 Out of range M Pt G Pad MPG-07 MPG-07 Vl Out of range M Pt G Pad MPG-08A MPG-08A V1 Out of range M Pt G Pad MPG-08 MPG-08 V1 Out of range M Pt G Pad MPG-10 MPG-10 V4 Out of range M Pt G Pad MPG-12 MPG-12 V5 Out of range M Pt G Pad MPG-13 MPG-13 V3 Out of range M Pt G Pad MPG-14 MPG-Jethro V9 Plan: MP 6574.73 6575.00 4.12 189.46 -117.72 FAIL: Major Risk M Pt G Pad MPG-15 MPG-15 V4 Out of range M Pt J Pad MPJ-02 MPJ-02 Vl Out of range M Pt J Pad MPJ-05 MPJ-05 V1 Out of range M Pt J Pad MPJ-10 MPJ-10 V1 Out of range M Pt J Pad MPJ-13 MPJ-13 V1 6918.26 5375.00 318.70 191.83 133.15 Pass: Major Risk M Pt J Pad Plan MPJ-Jethro Plan MPJ-Jethro L1 V1 9398.25 8200.00 15.84 0.00 15.84 Pass: NOERRORS M Pt J Pad Plan MPJ-Jethro Plan MPJ-Jethro V5 Pla 9385.94 8200.00 68.72 0.00 68.72 Pass: NOERRORS Site: M Pt G Pad Well: MPG-14 Rule Assigned: Major Risk Wellpath: MPG-Jethro V9 Plan: MPG-Jethro wp02 Vl Inter-Site Error: 0.00 ft ............... -~;~;;:;;;;; ............................... ~'~;;7:1 ~ ........ ~T~;-;~;,'i;-~ ............. --,:"~'~----~;.-~¥'~-~-~;T'-';~ii;;;i;i;i ..................................................... MD TVD MD · 'TVD Ref Offset TFO+AZI TFO~HS Casing Distance Area Deviation Warning ............ .f.t: ................. :._fl.... _.: ............... _~ ...... ::.~___::_ft_!_:__,__f!__:_,~i.ff__ ~______d _eg ~ eg. ~._i_n .... ___~ R_R__ ....... ._ft_ .................. ._ft.. ................................ : 6500.00 4093.23 6500.0o 4093.24 25.88 26.01 338.81 0.00 8.750 o.01 189.05 -85.27 FA~ 6574.73 4109.62 6575.00 4112.85 25.87 26.21 121.05 142.73 8.750 4.12 189.46 -117.72 FAIL 6599.39 4113.35 6600.00 4118.97 25.89 26.30 120.85 142.69 8.750 7.13 189.56 -117.37 FAIL 6623.83 4116.23 6625.00 4124.88 25.93 26.41 120.64 142.63 8.750 10.95 190.06 -116.26 FAIL 6648.40 4118.58 6650.00 4130.57 25.98 26.51 119.91 141.92 8.750 15.30 190.56 -113.91 FAIL 6673.04 4120.93 6675.00 4t36.04 25.94 26.54 118.47 140.19 8.750 19.76 190.52 -112.83 FAIL 6697.93 4123.22 6700.00 4141.30 25.55 26.21 118.51 138.76 8.750 24.14 188.41 -110.12 FAIL 6722.93 4125.39 6725.00 4146.33 25.15 25.86 119.15 137.92 8.750 28.31 186.17 -106.41 FAIL 6748.02 4127.45 6750.00 4151.14 24.73 25.50 120.14 137.43 8.750 32.27 183.88 -102.19 FAIL 6773.20 4129.37 6775.00 4155.73 24.29 25.12 121.37 137.18 8.750 36.03 181.45 -97.73 FAIL 6798.47 4131.17 6800.00 4160.09 23.85 24.73 122.77 137.09 8.750 39.56 178.96 -93.16 FAIL 6823.81 4132.84 6825.00 4164.22 23.38 24.31 124.31 137.14 8.750 42.88 176.34 -88.56 FAIL 6849.23 4134.38 6850.00 4168.12 22.91 23.88 125.97 137,30 8.750 45.98 173.67 -84.00 FAIL 07/24/01~ TUE 05'31 FAX 907 5id,,,,r 4441 lIP AUi~IL& IIlMI,I, INI~ & ~l[i,l~ ~ uol/uu3 TO: Jane Williamson DATE: 7/20/01 COMPANY: Alaska Oil and Gas Conservation Commission FAX: 276-7542 PHONE: FROM: James Franks FAX: (907)564-4441 PHONE: i~ _(907)564- 4468 Atta:ehed to: this cover sheet, are dr,'awlngs for,, the MPG.i:4~and.' MP I'~1'1 Multilateral w~l,is wi~':tplan:. :th, com~l",e, te theim.,,,,,,. ,, : .. , , as i,, ', :' ,Thanks! ' -. : . JUL 2 4 2001 ,,,, ~ was Cons. Ganulik~ Anchorage Number of attachments not including! fax cover: TREE: ,F~'vlC Horizontal 3-1/8" 5M ,4 .... W, ELLHEAD: FMC Horizontal 11", 5M tbg. he 11" x 3-1/2", EUE (btm) FMC tbg. hanger, 'H' BPV profile I 1 1 0' I 20" 92 lb/fi, H-40 Welded 7", 26#, L-80, BTC-M Casing Drift: 6.151" Casing ID: 6.276" Baker Hughes Hook Hanger system IWindow in 7" casing @ 6496' Well Inclination @ Window = 74 Degrees Baker Hughes Conventional Hanger 7" Casing Shoe @ 7177' Well Inclination @ Shoe = 90 Degrees PROPOSED COMPLETION MPG-14 & G-14 L KB. ELEV = 61' Cellar Box ELEV = 29.5' 2-7/8", 6.3 Ib/ft, L-80, EUE-M Coupling OD: 3.5" Drift/ID' 2.347"/2.441"  6496' ction I ____ I OA Horizontal 6-1/8" OA Lateral TD I 9430' 4-1/2" Slotted Liner and Hook Hanger ~ ~ Z OB Horizontal 6-1/8" OB Lateral TD 4-1/2" Slotted Liner & Hanger 9419' I DATE REV. BY COMMENTS 6/2612001 James Franks Level 3 Multi-Lateral, 2-718" ESP Completion Milne Point Unit WELL: MPG-14 APl NO: BP Exploration (Alaska) TREE: FMC HoHZ0ntal 3-1/8' 5M PROPOSED COMPLETION WE.L.E^D,.C. ...... ,a.,,'.,..b,.h~a, MPG'14 & (3--14 L1 ~ 11' x 3-112'.EUE (btm) i~~,~ Cellafeox ELEV : 295' F M C tbg hanger, 'H' BPV prohle ~ I 110' I 20' 92 IbSft. H.40 W oJcled ~..~ · 2-7/8", 63 Ib/ft, I_-80. I I Coupling OD: 3.5" Drift/ID · 2347"/2 441" II2-7/8" x 1" Gas Lift Mandrel I I X Nipple 2.315"1D Centrilifl Electric Submersible Pump I 7", 26#, L-80,BTC-M Casing Drift: 6,151" Casing ID: 6,276" Centrilift Pressure Gauge I 5700' M ulti-Late ral J un ction I 6496' I Baker Hughes Hook Hanger system I Window in 7" casing @ 6496' Well Inclination @ Window = 74 Degrees 6-1/8"OA LateralTD I 9430' 4-1/2" Slotted Liner and Hook Hanger I7"BakerHughesC°nventi°nalHangercasingShoe@ 7018' ,'~,~_; Welltnclination @ Shoe = 90 Degrees ,, i i i i i ii i i i i ! % 0 B H oriz ontal 6-1/8" OB LateraITD I .4,.. 4-1/2" Slotled Liner & Hanger DATE REV, BY C0M bi ENTS Milna Point Unit WELL: MPG-14 7/20/2001 James Franks Level 3 Multi-Lateral, 2-7/8" ESP Completlen APl NO: BP Exploration (Alaska) RECEIVED JUL o' Z001 Alaska Oil & Gas Cons~ Commission Anchorage ORIGINAL TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER "CLUE" DEVELOPMENT il//' DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number las~.t~wo (2) digits are betweer~O~9) PILOT HOLE (PH) ANNULAR. D~POSAL ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION The permit is for a new .~ellbore segment o_f e_xis.ting well , Permit No, '~OI~i.-~API No. cYan- Production should continue to be reported as a function of the original APl number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be Clearly differentiated in both name (name on permit plus PH) and APl number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested ... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates VENDOR ALASKAOILA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 060101 CKO&O 1011 100. O0 100. OO PYMT COMMENTS: PER~IT TO DRILL FEE HANDLINO INST: S/H - TERRIE NUBBLE X4628 , tE A3'rACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. II it) J_~ I I lOO. 00. 100. O0 ~..(A~SKA) :INC. .. '0'RDI~R OiL'AND~AS;: "' COMM i sS'I,Oi{,i' '"';' 333 ;iIiI~EST 7TH AVENUE ;K OFASHLAND: '=:,. : :; OHIO :. · . · 5~:~3~ ::. :i : ' ii}i'.?~.:. , NOT VALID AFTER 120 DAY. S · .,.,. .. :.. I1' )-c~ 3. 3.53,11m I'-01~ ~m ~30 3,,o,~51: _ ... WELL PERMIT CHECKLIST -'IELD & POOL LS~_~_.~.~ ~'-~/z_~.~ WELL NAME'.~ -'/,~/PROGRAM: exp ~,DMINISTRATION Ap~ DATE ENGINEERING INIT CLASS ~.~/'~/~/,/ '~' ~ 1. Permit fee attached ............... : ........ 2. Lease number appropdate.:~.~. ~.~/,'~ ./'.D: ~/ 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 ddlling 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 canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string 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 weilbore separation proposed ....... ; ..... dev J redrll serv wellbore seg ann. disposal para req GEOL AREA ~:~(~", UNIT# ~//.-~ ~' ON/OFF SHORE 23. If diverter required, does it meet regulations ........... 24. Drilling .fluid program schematic & equip list adequate..... ~ N · 25. BOPEs, do they meet regulation ............. '... ~i! N II APPJ~ , DATE,-~ ,~ ~. 26. BOPE press rating appropriate; test to ~,~:"~; ~ psig. ~ N ' 11"7~ b/~ U)27. Choke manifold complieS w/APl RP-53 (May 84) ......... ~,~'N Il! ~ ^ ,). ' 28. Work will occur without operation shutdown ........ . . . (~: N J~z.7'~ ( !~.~. 29. Is presence of H2S gas probable ................. ' Y ~ '~JJ GEOLOGY . 30. Permit ca~ be issued wlo hydrogen sulfide measures ...... (~ N A/~'/~.~' //~ 5'../~d..~ /~c-~--7, ¢ (..,~-~-=V/ ,~ ~L ~ ~ C/ II- ' 31. Data presented on potential Overpressure zones ....... "-Y ~1 ~'~..c./--c~/..-~ ~/o~ ~- ~ ~;~,~_ ~, ' <:~, ~'-~,o>~, ~-"~/;~ jj ' 32 Seismic analysis of shallow gas zones ....... ...... ~ N A~_.~ .._~.A~E~.) / ,~i (~eoant~ectd nC°a~;l~o~Ueg~rYw(ifee°k~;hpYor;~;s;~ ;e~c;rt;~ '[e~~y] '~ I~ ,. A/~NULAR DISPOSAL35. With proper cementing recOrds, this plan . ' (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for diSposal; Y. N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: ' UlClAnnular COMMISSION: Comments/Instructions: O Z O c:~nsoffice\wordian~liana\checklist (rev. 11101//00) ,